Azure Midstream Partners (AZUR) 10-K/A 28 Mar 14 2013 FY Annual report (amended) Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Feb. 27, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'MARLIN MIDSTREAM PARTNERS, LP	'
Entity Central Index Key	'0001575599	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Document Type	'10-K/A	'
Document Period End Date	31-Dec-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus (Q1,Q2,Q3,FY)	'FY	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	17,805,194
Entity Well-known Seasoned Issuer	'No	'
Entity Voluntary Filers	'No	'
Entity Current Reporting Status	'Yes	'
Entity Public Float	$115,500,000	'

CONSOLIDATED_AND_COMBINED_BALA

CONSOLIDATED AND COMBINED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
CURRENT ASSETS	'	'
Cash and cash equivalents	$3,157	$5,555
Accounts receivable	2,969	6,722
Accounts receivable—affiliates	3,632	96
Inventory	321	294
Prepaid assets	330	95
Other current assets	285	836
Total current assets	10,694	13,598
PROPERTY, PLANT AND EQUIPMENT, NET	162,548	165,139
OTHER ASSETS	900	2,059
TOTAL ASSETS	174,142	180,796
CURRENT LIABILITIES	'	'
Accounts payable	2,791	1,900
Accrued liabilities	2,131	1,319
Accounts payable—affiliates	1,552	4,034
Long-term incentive plan payable - affiliates	2,752	0
Fair value of derivative liabilities	0	72
Current portion of long-term debt	0	6,250
Total current liabilities	9,226	13,575
LONG-TERM LIABILITIES	'	'
Accounts payable—affiliates	0	14,692
Long-term incentive plan payable - affiliates	291	0
Deferred Texas margin tax	75	0
Long-term debt	4,000	120,250
Total liabilities	13,592	148,517
PARTNERS' CAPITAL AND MEMBER'S EQUITY	'	'
Partners' Capital	160,550	32,279
TOTAL LIABILITIES AND PARTNERS' CAPITAL AND MEMBER'S EQUITY	174,142	180,796
Member's equity	'	'
PARTNERS' CAPITAL AND MEMBER'S EQUITY	'	'
Partners' Capital	0	32,279
General Partner	'	'
PARTNERS' CAPITAL AND MEMBER'S EQUITY	'	'
Partners' Capital	705	0
Common Units | Limited Partner	'	'
PARTNERS' CAPITAL AND MEMBER'S EQUITY	'	'
Partners' Capital	142,587	0
Subordinate Units | Limited Partner	'	'
PARTNERS' CAPITAL AND MEMBER'S EQUITY	'	'
Partners' Capital	$17,258	$0

CONSOLIDATED_AND_COMBINED_BALA1

CONSOLIDATED AND COMBINED BALANCE SHEETS (PARENTHETICAL)	Dec. 31, 2013
General partners' capital account, units issued	356,104
General partner units, outstanding	356,104
Common Units	'
Limited partners' capital account, units issued	8,724,545
Limited partner's capital, units outstanding	8,724,545
Subordinate Units	'
Limited partners' capital account, units issued	8,724,545
Limited partner's capital, units outstanding	8,724,545

CONSOLIDATED_AND_COMBINED_STAT

CONSOLIDATED AND COMBINED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES:	'	'	'
Natural gas, NGLs and condensate revenue	$15,792	$34,708	$55,558
Gathering, processing, transloading and other revenue	24,053	16,087	10,006
Gathering, processing, transloading and other revenue—affiliates	13,015	254	254
Total Revenues	52,860	51,049	65,818
OPERATING EXPENSES:	'	'	'
Cost of natural gas, NGLs and condensate revenue	8,484	13,355	11,449
Cost of natural gas, NGLs and condensate revenue—affiliates	5,515	7,668	17,407
Operation and maintenance	12,401	15,035	12,031
Operation and maintenance—affiliates	3,490	793	327
General and administrative	3,699	3,045	3,260
General and administrative—affiliates	4,187	1,021	907
Property tax expense	1,216	893	490
Depreciation expense	8,197	7,689	5,365
Loss on disposals of equipment	0	0	217
Total operating expenses	47,189	49,499	51,453
Operating income	5,671	1,550	14,365
Interest expense, net of amounts capitalized	-4,349	-4,927	-3,733
Interest and other income	0	23	20
Loss on interest rate swap	-48	-851	-2,176
Net income (loss) before tax	1,274	-4,205	8,476
Texas margin tax expense	88	101	-65
Net income (loss)	1,186	-4,306	8,541
Other comprehensive income (loss)	'	'	'
Deferred gain from cash flow hedges	0	689	122
Reclassification of deferred gain from cash flow hedges into net income	0	-752	-59
Comprehensive income (loss)	1,186	-4,369	8,604
Limited partner interest in net income	7,046	'	'
Net income per limited partner unit - basic (in dollars per share)	$0.40	'	'
Net income per limited partner unit - diluted (in dollars per share)	$0.40	'	'
Common Units	'	'	'
Other comprehensive income (loss)	'	'	'
Limited partner interest in net income	3,523	'	'
Net income per limited partner unit - basic (in dollars per share)	$0.40	'	'
Net income per limited partner unit - diluted (in dollars per share)	$0.39	'	'
Subordinate Units	'	'	'
Other comprehensive income (loss)	'	'	'
Limited partner interest in net income	$3,523	'	'
Net income per limited partner unit - basic (in dollars per share)	$0.40	'	'
Net income per limited partner unit - diluted (in dollars per share)	$0.40	'	'

CONSOLIDATED_AND_COMBINED_STAT1

CONSOLIDATED AND COMBINED STATEMENT OF PARTNERS' CAPITAL AND MEMBER'S EQUITY (USD $)	Total	Member's Equity	General Partner	Limited Partner	Limited Partner
In Thousands, unless otherwise specified				Subordinated Units	Common Units
Beginning Balance at Dec. 31, 2010	$23,670	$23,670	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'	'	'
Net income (loss)	8,541	8,541	'	'	'
Deferred gain from cash flow hedges	122	122	'	'	'
Reclassification of deferred gain from cash flow hedges into net income	-59	-59	'	'	'
Ending Balance at Dec. 31, 2011	32,274	32,274	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'	'	'
Net income (loss)	-4,306	-4,306	'	'	'
Deferred gain from cash flow hedges	689	689	'	'	'
Reclassification of deferred gain from cash flow hedges into net income	-752	-752	'	'	'
Capital contributions	4,374	4,374	'	'	'
Ending Balance at Dec. 31, 2012	32,279	32,279	0	0	0
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'	'	'
Net income (loss)	-6,003	-6,003	'	'	'
Capital contributions	3,574	3,574	'	'	'
Transfer of net liabilities to NuDevco Midstream Development, LLC on July 31, 2013	2,307	2,307	'	'	'
Contribution of net assets to Marlin Midstream Partners, LP at July 31, 2013	0	-32,157	643	15,757	15,757
Issuance of common units from Initial Public Offering, net of underwriting discount and other direct IPO costs at July 31, 2013	125,329	'	'	'	125,329
Ending Balance at Jul. 31, 2013	'	'	'	'	'
Beginning Balance at Dec. 31, 2012	32,279	'	0	0	0
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'	'	'
Net income (loss)	1,186	'	'	'	'
Deferred gain from cash flow hedges	0	'	'	'	'
Reclassification of deferred gain from cash flow hedges into net income	0	'	'	'	'
Distributions through December 31, 2013	-4,126	'	-82	-2,022	-2,022
Ending Balance at Dec. 31, 2013	160,550	0	705	17,258	142,587
Beginning Balance at Jul. 31, 2013	'	'	'	'	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'	'	'
Net income (loss)	7,190	'	144	3,523	3,523
Ending Balance at Dec. 31, 2013	$160,550	$0	$705	$17,258	$142,587

CONSOLIDATED_AND_COMBINED_STAT2

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'	'
Net income (loss)	$1,186	($4,306)	$8,541
Adjustments to reconcile net loss to net cash flows provided by operating activities:	'	'	'
Loss on disposal	0	0	217
Depreciation expense	8,197	7,689	5,365
Amortization of deferred financing costs	1,269	542	367
Equity-based compensation	3,012	0	0
Deferred Texas margin tax	75	0	0
Unrealized gain (loss) on derivatives	-57	-4,196	291
Unrealized Gain (loss) on derivatives—affiliates	0	-344	344
Changes in assets and liabilities:	'	'	'
(Increase) Decrease in accounts receivable	3,752	-480	-1,087
(Increase) decrease in accounts receivable—affiliates	-3,526	1,267	884
(Increase) decrease in inventory	-28	132	-252
(Increase) decrease in prepaid assets	-235	-36	63
(Increase) decrease in other current assets	3	236	-135
(Increase) decrease in other assets	51	-679	175
Increase (decrease) in accounts payable	120	-108	496
Increase (decrease) in accrued liabilities	813	1,192	-445
Increase in long-term incentive plan payable	32	0	0
Increase (decrease) in accounts payable—affiliates	-5,488	10,305	1,278
Net cash provided by operating activities	9,176	11,214	16,102
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'	'
Purchases of property, plant and equipment	-12,710	-12,445	-25,658
Net cash used in investing activities	-12,710	-12,445	-25,658
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'	'
Member Capital contributions	3,574	4,287	0
Borrowing of long-term debt	36,500	126,500	130,000
Repayments on long-term debt	-159,000	-123,500	-120,809
Payment of deferred financing costs	-1,141	-932	-1,094
Payments of Capital Distribution	-4,126	0	0
Proceeds from IPO, net of underwriting discount and other costs	125,329	0	0
Net cash provided by financing activities	1,136	6,355	8,097
NET INCREASE IN CASH AND CASH EQUIVALENTS	-2,398	5,124	-1,459
CASH AND CASH EQUIVALENTS—Beginning of Period	5,555	431	1,890
CASH AND CASH EQUIVALENTS—End of Period	3,157	5,555	431
Supplemental Cash Flow Information:	'	'	'
Cash paid for interest	3,448	4,296	4,619
Accrual of construction-in-progress and capital expenditures	1,407	635	1,977
Cash paid for texas margin taxes	40	67	6
Contribution of property from sole member	0	87	0
Net assets contributed to NuDevco Midstream Development, LLC	9,385	0	0
Intercompany accounts payable assigned to NuDevco Midstream Development, LLC	$11,692	$0	$0

ORGANIZATION_AND_SUMMARY_OF_SI

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	Organization
	Marlin Midstream Partners, LP (the "Partnership") is a midstream energy company that offers (i) natural gas gathering, compression, dehydration, treating, processing, and hydrocarbon dew-point control and transportation services to producers, marketers and third-party pipeline companies, and (ii) crude oil transloading services to Associated Energy Services, LP ("AES"), an affiliate of the Partnership.
	The Partnership is a Delaware limited partnership, formed in April 2013 by NuDevco Partners, LLC and its affiliates (“NuDevco”). NuDevco, a sole member limited liability company formed on August 27, 2010 under the Texas Limited Liability Company Act (“TLLCA”), is an affiliate of Spark Energy Ventures, LLC (“SEV”), a sole member limited liability company formed on October 8, 2007 under the TLLCA. NuDevco and SEV are both wholly owned by W. Keith Maxwell III. SEV was the sole member of Marlin Midstream, LLC and its subsidiaries ("Marlin Midstream"), and Mr. Maxwell was the sole member of Marlin Logistics, LLC ("Marlin Logistics") prior to the closing of the Partnership's initial public offering of 6,875,000 common units representing a 38.6% limited partner interest in the Partnership on July 31, 2013 ("IPO") as discussed below. Concurrently, with the closing of the IPO, the Partnership also executed a new credit facility as discussed below.
	In connection with the closing of the IPO, SEV contributed all of its interest in Marlin Midstream to the Partnership, and Mr. Maxwell contributed all of his interest in Marlin Logistics to the Partnership, through a series of transfers of interest in entities all under the common control of Mr. Maxwell in exchange for wholly owned subsidiaries of NuDevco receiving common units and all of the Partnership’s subordinated units and incentive distribution rights. The contribution of entities, as discussed above, to the Partnership is not considered a business combination accounted for under the purchase method, as it was a transfer of assets and operations under common control and, accordingly, balances were transferred at their historical cost. The Partnership's historical combined financial statements prior to the IPO are prepared using Marlin Midstream's and Marlin Logistics' historical basis in the assets and liabilities, and include all revenues, costs, assets and liabilities attributed to these entities for the periods presented. The Partnership's financial statements subsequent to the IPO are prepared on a consolidated basis.
	The Partnership’s general partner, Marlin Midstream GP, LLC manages the Partnership’s activities subject to the terms and conditions specified in the Partnership’s partnership agreement. The Partnership’s general partner is owned by NuDevco Midstream Development, LLC ("NuDevco Midstream Development"), an indirect wholly owned subsidiary of NuDevco. The operations of the general partner, in its capacity as general partner, are managed by its board of directors. Actions by the general partner that are made in its individual capacity will be made by NuDevco Midstream Development as the sole member of the Partnership's general partner and not by the board of directors of the general partner. The partnership's general partner will not be elected by the Partnership's unitholders and will not be subject to re-election on a regular basis in the future. The officers of the general partner will manage the day-to-day affairs of the Partnership's business.
	Marlin Midstream was formed November 26, 2002 as a sole member limited liability company under the TLLCA. Marlin Midstream is a midstream energy company offering the following midstream services: natural gas gathering, compression, dehydration, treating, processing and hydrocarbon dew-point control and transportation services to producers, third-party pipeline companies and marketers.
	Marlin Logistics, formerly known as FuelCo Energy, LLC, was formed August 26, 2010 as a sole member limited liability company under the TLLCA. Marlin Logistics is a crude oil logistics company that offers crude oil transloading services.
	As a company with less than $1.0 billion in revenues during its last fiscal year, the Partnership qualifies as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act of 2012, or the JOBS Act. An emerging growth company may take advantage of specified reduced reporting and other regulatory requirements for up to five years that are otherwise applicable generally to public companies, such as no requirement to provide selected financial data in their annual reports for any period prior to the earliest audited period presented in connection with their first registration statement under the Securities Act or the Exchange Act that became effective.
	The Partnership will remain an emerging growth company for five years unless, prior to that time, annual revenues total more than $1.0 billion, the Partnership becomes a “large accelerated filer,” as defined in Rule 12b-2 promulgated under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or the Partnership issues more than $1.0 billion of non-convertible debt over a three-year period.
	As a result of our election to avail ourselves of certain provisions of the JOBS Act, the information that we provide may be different than what you may receive from other public companies in which you hold an equity interest.
	Initial Public Offering of Marlin Midstream Partners, LP
	On July 31, 2013, the Partnership completed the IPO of 6,875,000 common units, representing a 38.6% limited partner interest, to the public for $20.00 per common unit, less an underwriting discount of $1.20 per common unit. After the closing of the IPO, substantially all the Partnership's gross margin is generated under fee-based commercial agreements, the substantial majority of which have minimum volume commitments.
	The Partnership’s general partner is entitled to 2.0% of all distributions that the Partnership makes. The general partner has the right, but not the obligation, to contribute a proportionate amount of capital to us in order to maintain its 2.0% general partner interest if the Partnership issues additional units. The 2.0% general partner interest, and the percentage of the Partnership’s cash distributions to which the general partner is entitled from such 2.0% interest, will be proportionately reduced if the Partnership issues additional units in the future (other than the issuance of common units upon conversion of outstanding subordinated units or the issuance of common units upon a reset of the incentive distribution rights) and the Partnership’s general partner does not contribute a proportionate amount of capital to the Partnership in order to maintain the general partners 2.0% general partner interest.
	NuDevco indirectly holds all of the incentive distribution rights issued in the IPO, which entitles NuDevco to receive an increasing percentage (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and certain target distribution levels have been achieved. The maximum distribution of 48.0% does not include any distributions that the Partnership’s general partner or its affiliates may receive on common, subordinated or general partner units that they own.
	The Partnership’s partnership agreement provides that, during the defined subordination period, the common units have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.35 per common unit before any distributions of available cash from operating surplus may be made on the subordinated units. The subordinated units are deemed “subordinated” because for a defined period of time the subordinated units will not be entitled to receive any distributions until the common units have received the minimum quarterly distribution plus any arrearages from prior quarters. Furthermore, no arrearages accrue or are payable on the subordinated units.
	Net proceeds to the Partnership from the IPO were $125.3 million, after underwriting discount, structuring fees and other direct IPO costs. Using those proceeds, the Partnership repaid its existing credit facility of approximately $121.9 million and the outstanding revolving credit facility of approximately $10.0 million, and settled its existing interest rate swap liability of approximately $0.1 million.
	At the consummation of the IPO, the amount of common, subordinated, and general partner units is summarized in the table below:
		Number of units at	Limited Partner
		31-Jul-13	Interest
	Publicly held common units	6,875,000	38.60%
	Common units held by NuDevco	1,849,545	10.40%
	Subordinated units held by NuDevco	8,724,545	49.00%
	General partner units	356,104	2.00%
	Total	17,805,194	100.00%
	There have been no subsequent issuances of common units.
	Our Fee-Based Commercial Agreements
	Prior to the IPO, the Partnership generated revenues primarily under keep-whole and other commodity-based gathering and processing agreements with third parties and its affiliates. At the closing of the IPO, the Partnership terminated the existing commodity-based gas gathering and processing agreement with AES, assigned to AES all of the remaining keep-whole and other commodity-based gathering and processing agreements with third party customers and entered into a new three-year fee-based gathering and processing agreement with AES with a minimum volume commitment and annual inflation adjustments.
	Following the closing of the IPO, the Partnership has multiple fee-based commercial agreements in place with Anadarko Petroleum Corporation (“Anadarko”) and AES, substantially all of which include minimum volume commitments and annual inflation adjustments that will initially be the source of a substantial portion of the Partnership's revenues.
	Credit Facility
	Concurrently with the closing of the IPO, the Partnership entered into a new $50.0 million senior secured revolving credit facility, which matures on July 31, 2017. If no event of default has occurred, the Partnership has the right, subject to approval by the administrative agent and certain lenders, to increase the borrowing capacity under the revolving credit facility to up to $150.0 million. The new revolving credit facility is available to fund expansions, acquisitions and working capital requirements for operations and general corporate purposes. At the closing of the IPO, the Partnership borrowed $25.0 million under the new revolving credit facility. At December 31, 2013, $4.0 million was outstanding under the new revolving credit facility.
	At our election, interest will be generally determined by reference to:
	•	the Eurodollar rate plus an applicable margin between 3.0% and 3.75% per annum (based upon the prevailing senior secured leverage ratio); or
	•	the alternate base rate plus an applicable margin between 2.0% and 2.75% per annum (based upon the prevailing senior secured leverage ratio). The alternate base rate is equal to the highest of Société Générale's prime rate, the federal funds rate plus 0.5% per annum or the reference Eurodollar rate plus 1.0%.
	Our new revolving credit facility is secured by the capital stock of our present and future subsidiaries, all of our and our subsidiaries' present and future property and assets (real and personal), control agreements relating to our and our subsidiaries' bank accounts and other instruments, investment property, general intangibles and contract rights, including rights under any agreements with AES or Anadarko.
	Our new revolving credit facility also contains covenants that, among other things, require us to maintain specified ratios or conditions. We must maintain a consolidated senior secured leverage ratio, consisting of consolidated indebtedness under our new revolving credit facility to consolidated EBITDA of not more than 4.0 to 1.0, as of the last day of each fiscal quarter. In addition, we must maintain a consolidated interest coverage ratio, consisting of our consolidated EBITDA minus capital expenditures to our consolidated interest expense, letter of credit fees and commitment fees of not less than 2.5 to 1.0, as of the last day of each fiscal quarter.
	In addition, our new revolving credit facility contains affirmative covenants that are customary for credit facilities of this type. The covenants will include delivery of financial statements and other information (including any filings made with the SEC), maintenance of property and insurance, payment of taxes and obligations, material compliance with laws, inspection of property, books and records and audits, use of proceeds, payments to bank blocked accounts, notice of defaults and certain other customary matters. For additional information relating to our long-term debt, please see Note 6, "Long-Term Debt and Interest Expense," to our Consolidated Financial Statements included in this Form 10-K.
	Other Transactions in Connection with the Consummation of the IPO:
	On July 31, 2013, in connection with the closing of the IPO, the following transactions occurred:
	•	the Partnership's general partner maintained its 2.0% general partner interest, and all of the Partnership's incentive distribution rights were issued to Marlin IDR Holdings, LLC;
	•	the Partnership issued 1,849,545 common units and 8,724,545 subordinated units to NuDevco Midstream Development for the contributions by SEV and Mr. Maxwell, representing a 49.0% limited partner interest in the Partnership;
	•	the Partnership transferred to affiliates of NuDevco (i) the Partnership's 50% interest in a CO2 processing facility located in Monell, Wyoming, (ii) certain transloading assets and purchase commitments owned by Marlin Logistics that are not currently under a service contract, (iii) certain property, plant and equipment and other equipment not yet in service and (iv) certain other immaterial contracts;
	•	NuDevco assumed $11.7 million of the non-current accounts payable balance owed by Marlin Midstream to affiliates of SEV and Marlin Midstream was released from such obligations; and
	•	the Partnership entered into an omnibus agreement with the general partner and its affiliates that addresses (i) the management and administrative services to be provided by NuDevco to the Partnership and the corresponding fees and expense reimbursements to be paid to NuDevco in connection therewith, (ii) the indemnification obligations between NuDevco and the Partnership for environmental and other liabilities and the operation of assets and (iii) the Partnership's right of first offer on certain of NuDevco Midstream Development's midstream energy assets.

BASIS_OF_PRESENTATION

BASIS OF PRESENTATION	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
BASIS OF PRESENTATION	'
	BASIS OF PRESENTATION
	The consolidated and combined financial statements have been prepared in accordance with generally accepted accounting principles in the United States ("GAAP") and pursuant to the rules and regulations of the Securities and Exchange Commission ("SEC").
	In preparing financial statements in accordance with GAAP, management makes informed judgments and estimates that affect the reported amounts of assets, liabilities, revenues, and expenses. Management evaluates its estimates and related assumptions regularly, utilizing historical experience and other methods considered reasonable under the particular circumstances. Changes in facts and circumstances or additional information may result in revised estimates and actual results may differ from these estimates. Effects on the business, financial condition and results of operations resulting from revisions to estimates are recognized when the facts that give rise to the revision become known. The information furnished herein reflects all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the consolidated and combined financial statements. The consolidated and combined financial statements include the accounts of the Partnership and its wholly-owned subsidiaries. All significant intercompany transactions and balances have been eliminated in consolidation.
	The accompanying combined financial statements have been prepared in accordance with Regulation S-X, Article 3, General Instructions as to Financial Statements and Staff Accounting Bulletin ("SAB") Topic 1-B, Allocations of Expenses and Related Disclosures in Financial Statements of Subsidiaries, Divisions or Lesser Business Components of Another Entity. Certain expenses incurred by SEV are only indirectly attributable to Marlin Midstream. As a result, certain assumptions and estimates are made in order to allocate a reasonable share of such expenses to the Partnership, so that the accompanying combined financial statements reflect substantially all costs of doing business. The allocations and related estimates and assumptions are described more fully in Note 11-"Transactions with Affiliates", which the Partnership believes are reasonable.
	SEV has allocated various corporate overhead expenses to the Partnership based on percentage of departmental usage, wages or headcount. These allocations are not necessarily indicative of the cost that the Partnership would have incurred had it operated as an independent stand-alone entity. As such, the consolidated and combined financial statements do not fully reflect what the Partnership's financial position, results of operations and cash flows would have been had the Partnership operated as a stand-alone company during the periods presented.
	At the closing of the IPO, the Partnership entered into an omnibus agreement with NuDevco and its affiliates which addresses the management and administrative services to be provided by NuDevco to the Partnership and the corresponding fees and expense reimbursements to be paid to NuDevco in connection therewith. Under the omnibus agreement, the Partnership pays an annual fee, initially in the amount of $0.6 million, for executive management services and is allocated general and administrative and operating expenses that are directly attributable to the Partnership.
	Prior to the IPO, Marlin Midstream relied upon SEV and its affiliates as a participant in SEV's credit facility. As a result, historical combined financial information is not necessarily indicative of what the Partnership's results of operations, financial position and cash flows will be in the future.
	Cash and Cash Equivalents
	Cash and cash equivalents consist of all unrestricted demand deposits and funds invested in highly liquid instruments with original maturities of three months or less. The Partnership periodically assesses the financial condition of the institutions where these funds are held and believes that its credit risk is minimal.
	Accounts Receivable
	Trade accounts receivable are recorded at the invoiced amount and do not bear interest. Amounts collected on trade accounts receivable are included in net cash provided by operating activities in the consolidated and combined statements of cash flows. The Partnership does not maintain an allowance for doubtful accounts. The Partnership elects to use the direct write-off method based on its collection history. For the years ended December 31, 2013 and 2012, no accounts receivable were written off.
	Inventory
	Inventory consists of NGLs and chemicals in bulk storage and is valued at the lower of weighted average cost or market. NGL inventories are used for sales contract requirements. Chemical inventories are expensed as transferred from bulk storage into production and are recorded in operation and maintenance in the consolidated and combined statements of operations.
	Deferred Financing Costs
	Costs incurred in connection with the issuance of long-term debt are capitalized and amortized to interest expense using the effective interest method over the life of the related debt.
	Property, Plant and Equipment
	Property, plant and equipment are stated at cost. Depreciation on property, plant and equipment is recorded on a straight-line basis for groups of property having similar economic characteristics over the estimated useful lives (primarily 5 to 40 years). Uncertainties that may impact these estimates include, but are not limited to, changes in laws and regulations relating to environmental matters, including air and water quality, restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are placed into service, management makes estimates with respect to useful lives. However, subsequent events could cause a change in estimates, thereby impacting future depreciation amounts.
	When items of property, plant and equipment are sold or otherwise disposed of, gains or losses are reported in the consolidated and combined statements of operations.
	The Partnership capitalizes all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering, insurance, taxes and the cost of funds used during construction. Capitalized interest is calculated by multiplying the Partnership’s monthly weighted average interest rate on outstanding debt by the amount of qualifying costs. Capitalized interest cannot exceed monthly gross interest expense. After major construction projects are completed, the associated capitalized costs including interest are depreciated over the estimated useful life of the related asset. During the years ended December 31, 2013 and 2012, respectively, the Partnership recorded $0.2 million and $0.2 million of capitalized interest, respectively.
	Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. In addition, certain of the Partnership’s plant assets require periodic and scheduled maintenance, such as overhauls. The cost of these scheduled maintenance projects are capitalized and depreciated on a straight-line basis until the next planned maintenance, which generally occurs every 5 years.
	Costs for planned integrity management projects are expensed in the period incurred. These types of costs include in-line inspection services, contractor repair services, materials and supplies, equipment rentals and labor costs. The costs of repairs, minor replacements and maintenance projects, which do not increase the original efficiency, productivity or capacity of property, plant and equipment, are expensed as incurred.
	Impairment of Long-lived Assets
	The Partnership evaluates its long-lived assets for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. A long-lived asset is considered impaired when the sum of the estimated, undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset. When alternative courses of action to recover the carrying amount of a long-lived asset are under consideration, estimates of future undiscounted cash flows take into account possible outcomes and probabilities of their occurrence. If the carrying amount of the long-lived asset is not recoverable based on the estimated future undiscounted cash flows, an impairment loss is recognized to the extent the carrying value exceeds the estimated fair value of the long-lived asset. With respect to natural gas processing plants and pipelines and NGL pipelines, management considers the volume of third-party reserves behind the asset and future NGL and natural gas prices to estimate cash flows. The amount of additional reserves developed by future drilling activity depends, in part, on expected natural gas prices. Projections of reserves, drilling activity, and future commodity prices are inherently subjective and contingent upon a number of variable factors, many of which are difficult to forecast. Any significant variance in any of these assumptions or factors could materially affect future cash flows, which could result in the impairment of an asset group.
	For assets identified to be disposed of in the future, the carrying value of these assets is compared to the estimated fair value, less the cost to sell, to determine if impairment is required. Until the assets are disposed of, an estimate of the fair value is determined when related events occur or circumstances change. There were no asset impairments for the years ended December 31, 2013 and 2012.
	Segment Reporting
	The Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 280, Segment Reporting, established standards for entities to report information about the operating segments and geographic areas in which they operate. The Partnership operates two segments, gathering and processing and crude oil logistics, and all of its operations are located in the United States. Our crude oil logistics segment had no material assets or operations as of or prior to December 31, 2012.
	Revenues and Cost of Revenues
	The Partnership’s revenues are derived primarily from natural gas processing and fees earned from its gathering and processing operations. Revenues are recognized by the Partnership using the following criteria: (1) persuasive evidence of an exchange arrangement exists, (2) delivery has occurred or services have been rendered, (3) the buyer’s price is fixed or determinable and collection is reasonably assured. Utilizing these criteria, revenues are recognized when the commodity is delivered or services are rendered. Similarly, cost of revenues is recognized when the commodity is purchased or delivered.
	The Partnership’s fee-based contracts provide for a fixed fee arrangement for one or more of the following midstream services: natural gas gathering, compression, dehydration, treating, processing and hydrocarbon dew-point control and transportation services to producers, third- party pipeline companies and marketers. Under these arrangements, the Partnership is paid a fixed fee based on the volume of the natural gas the Partnership gathers and processes, and recognizes revenues for its services in the month such services are performed. Substantially all of these fee-based agreements contain minimum volume commitments and annual inflation adjustments.
	Historically, under commercial agreements that did not require us to deliver NGLs to the customer in kind, we provided NGL transportation services to the customer whereby we purchased the NGLs from the customer at an index price, less fractionation and transportation fees, and simultaneously sold the NGLs to third parties at the same index price, less fractionation fees. The revenue generated by these activities was offset by a corresponding cost of revenues that was recorded when we compensated the customer for its share of the NGLs.
	Producers’ wells and other third-party gathering systems are connected to the Partnership’s gathering systems for delivery of natural gas to the Partnership’s processing and treating plants, where the natural gas is processed to extract NGLs and condensate or treated in order to satisfy downstream natural gas pipeline specifications. Under percentage of liquids (“POL”) arrangements, the Partnership retained a percentage of the liquids processed. Both the Partnership and producer depended on the volume of the commodity and its value and each party received a percentage of the commodity revenues. Revenues were directly correlated to the commodity’s market value. POL contracts also include fee-based revenues for gathering and other midstream services. Under both fixed fee and POL arrangements, the counterparties’ share of NGLs, if not delivered as a commodity, was recorded as cost of revenues.
	Under its keep-whole contracts, the Partnership was required to gather or purchase raw natural gas at current market rates. The volume of gas gathered or purchased was based on the measured volume at an agreed upon location (generally at the wellhead). The volume of gas redelivered or sold at the tailgate of the Partnership’s processing facility would be lower than the volume purchased at the wellhead primarily due to NGLs extracted through processing. The Partnership would make up or “keep the producer whole” for the condensate and NGL volumes through the delivery of or payment for a thermally equivalent volume of residue gas. The cost of these natural gas volumes was recorded as a cost of natural gas, NGLs and condensate revenue-affiliates. The keep-whole contract conveyed an economic benefit to the Partnership when the combined value of the individual NGLs was greater in the form of liquids than as a component of the natural gas stream; however, the Partnership was adversely impacted when the value of the NGLs is lower as liquids than as a component of the natural gas stream. Certain contracts also included fee-based revenues for gathering and other midstream services. Cost of revenues were derived primarily from the purchase of natural gas, NGLs and condensates. There were no material costs categorized as cost of revenue directly identified with gathering, processing and other revenue.
	Natural Gas Imbalances
	The consolidated and combined balance sheets include natural gas imbalance receivables and payables caused by the difference in natural gas delivered to the Partnership’s customers and the natural gas contractually owed to the customers. Most natural gas imbalances are settled monthly in cash and calculated according to the terms of their contracts. Changes in gas imbalances are reported net of the cost of product in the consolidated and combined statements of operations. As of December 31, 2013 and 2012, the Partnership recorded an imbalance receivable of $0.1 million and $0.2 million, respectively, which is recorded in accounts receivable in the consolidated and combined balance sheets.
	Hedging and Derivatives
	From time to time, the Partnership entered into derivative transactions to mitigate its exposure to price fluctuations in NGLs. The Partnership recognized all derivative instruments as either assets or liabilities in the combined balance sheet at their respective fair value. For derivatives designated in hedging relationships, changes in the fair value were recognized in accumulated other comprehensive income, to the extent the derivative was effective at offsetting the changes in cash flows being hedged, until the hedged item affected earnings. As of the date of our IPO on July 31, 2013, we settled our outstanding interest rate swap and have discontinued our hedging and derivatives program.
	Interest Rate Swaps
	The Partnership utilizes derivative instruments to manage its exposure to interest rate risk. In January 2011, the Partnership entered into an interest rate swap for this purpose (“2011 Swap”). The 2011 Swap did not meet the criteria necessary to qualify for cash flow hedge accounting and was recorded at fair value at each reporting period with changes in fair value recognized currently in earnings. The 2011 Swap was settled in full on December 17, 2012. On December 17, 2012, the Partnership entered into a new interest rate swap (“2012 Swap”) to manage its exposure to interest rate risk. The 2012 Swap did not meet the criteria necessary to qualify for cash flow hedge accounting and is recorded at fair value at each reporting period with changes in fair value recognized currently in earnings. Gains and losses on interest rate swaps are recorded in gain (loss) on interest rate swap in the combined statements of operations.
	Fair Value
	FASB ASC 820, Fair Value Measurement, established a single authoritative definition of fair value when accounting rules require the use of fair value, set out a framework for measuring fair value and required additional disclosures about fair value measurements. The standard clarifies that fair value is an exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The standard utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
	•Level 1-Quoted prices in active markets for identical assets or liabilities.
	•Level 2-Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities).
	•Level 3-Significant unobservable inputs (including the Partnership’s own assumptions in determining fair value).
	When the Partnership is required to measure fair value, and there is not a market-observable price for the asset or liability or a market- observable price for a similar asset or liability, the Partnership utilizes the cost, income, or market valuation approach depending on the quality of information available to support management’s assumptions.
	The carrying amount of long-term debt reported on the consolidated and combined balance sheets approximates fair value, because of the variable rate nature of the Partnership’s long-term debt. The carrying amounts of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities reported on the consolidated and combined balance sheets approximate fair value due to the short-term nature of these items. The fair value of the Partnership’s accounts receivable with affiliates and accounts payable with affiliates cannot be determined due to the related party nature of these items. Derivative instruments are measured at fair value at each reporting period.
	Asset Retirements Obligations
	FASB ASC 410, Asset Retirement and Environmental Obligations, requires the Partnership to evaluate whether any future asset retirement obligations exist as of December 31, 2013 and 2012, and whether the expected retirement date of the related costs of retirement can be estimated. The Partnership has concluded that its natural gas gathering system assets, which include pipelines and treating facilities, have an indeterminate life because they are owned and will operate for an indeterminate future period when properly maintained. A liability for these asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life is identified. The Partnership did not record any asset retirement obligations as of December 31, 2013 and 2012 because the Partnership has no current intention of discontinuing use of any significant assets.
	Environmental Expenditures
	The operations of the Partnership are subject to various federal, state and local laws and regulations relating to the protection of the environment. Although the Partnership believes that it is in compliance with applicable environmental regulations, the risk of costs and liabilities are inherent in pipeline ownership and operation, and there can be no assurances that significant costs and liabilities will not be incurred by the Partnership.
	Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Liabilities are recorded when the necessity for environmental remediation or other potential environmental liabilities become probable and the costs can be reasonably estimated. Management is not aware of any contingent liabilities that currently exist with respect to environmental matters.
	Income Taxes
	The Partnership is not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Therefore, income taxes are not levied at the entity level, but rather on the individual partners of the Partnership. Accordingly, the accompanying consolidated and combined financial statements do not include a provision for federal and state income taxes. The Partnership is subject to the Revised Texas Franchise Tax (“Texas Margin Tax”). The Texas Margin Tax is computed on modified gross margin and was not significant for the years ended December 31, 2013, 2012 and 2011, and is recorded as Texas margin tax expense in the consolidated and combined statements of operations. The Partnership does not do business in any other state where a similar tax is applied. As of December 31, 2013, the Partnership had no liability reported for unrecognized tax benefits.
	Net Income Per Unit
	The Partnership has omitted net income per unit for all historical periods prior to the IPO at July 31, 2013 because the Partnership operated under a sole member equity structure, which is different than the capital structure resulting from the consummation of the IPO and, as a result, the per unit data for periods prior to the IPO would not be meaningful to investors.
	The net income per unit figures on the consolidated Statement of Operations is based on the net income of the Partnership after the closing of the IPO on July 31, 2013 through December 31, 2013, since this is the amount of net income that is attributable to the newly issued Partnership units.
	Commitments and Contingencies
	Liabilities for loss contingencies arising from claims, assessments, litigation, fines, penalties and other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. Legal costs incurred in connection with loss contingencies are expensed as incurred. Recoveries of environmental remediation costs from third parties that are probable of realization are separately recorded as assets, and are not offset against the related environmental liability.
	Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study. Such accruals are adjusted as further information develops or circumstances change. Costs of expected future expenditures for environment remediation obligations are not discounted to their present value.
	Transactions with Affiliates
	From time to time, the Partnership enters into transactions with SEV related affiliates that have a common owner with the Partnership in order to reduce risk, create strategic alliances and supply or receive goods and services to these SEV related affiliates. As such, the accompanying consolidated and combined financial statements include costs that have been incurred by SEV on behalf of the Partnership. These amounts incurred by SEV are then billed or allocated to the Partnership and are classified on the consolidated and combined statements of operations as either direct operation and maintenance-affiliates or as general and administrative-affiliates.
	At our IPO, the Partnership entered into an omnibus agreement with the general partner and its affiliates that addresses (i) the management and administrative services to be provided by NuDevco to the Partnership and the corresponding fees and expense reimbursements to be paid to NuDevco in connection therewith, (ii) the indemnification obligations between NuDevco and the Partnership for environmental and other liabilities and the operation of assets and (iii) the Partnership's right of first offer on certain of NuDevco Midstream Development's midstream energy assets. For additional information relating to transactions with our affiliates, please see Note 11, "Transactions with Affiliates," to our Consolidated Financial Statements included in this Form 10-K.
	Use of Estimates and Assumptions
	The preparation of the Partnership’s consolidated and combined financial statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated and combined financial statements and the reported amounts of revenues and expenses during the reporting period. Certain prior year amounts have been reclassified to conform to the current year presentation. Actual results could materially differ from those estimates. Significant items subject to such estimates by the Partnership’s management include provisions for uncollectible receivables, valuation of long-lived assets and related estimated useful lives, valuation of derivatives, valuation of equity-based compensation, and reserves for contingencies.
Accounting for Awards under the Long-term Incentive Plan
The Long-term Incentive Plan ("LTIP") provides for the grant of unit options, unit appreciation awards, restricted units, phantom units, distribution equivalent rights, unit awards, profits interest units, and other unit-based awards. On August 1, 2013, phantom units, with distribution equivalent rights, of 292,000 units were awarded to certain employees of NuDevco Midstream Development and its affiliates who provide direct or indirect services to the Partnership pursuant to affiliate agreements, and 20,000 units were awarded to certain board members of the Partnership’s general partner. All of the phantom unit awards granted to-date are considered non-employee equity based awards and are required to be remeasured at fair market value at each reporting period and amortized to compensation expense on a straight-line basis over the vesting period of the phantom units with a corresponding increase in a liability. Management intends to settle the awards by allowing the recipient to choose between issuing the net amount of common units due, less common units equivalent to pay withholding taxes, due upon vesting with the Partnership paying the amount of withholding taxes due in cash or issuing the gross amount of common units due with the recipient paying the withholding taxes. The phantom unit awards were awarded to individuals who are not deemed to be employees of the Partnership.
Distribution equivalent rights are accrued for each phantom unit award as the Partnership declares cash distributions and are recorded as a decrease in partners’ capital with a corresponding liability in accordance with the vesting period of the underlying phantom unit, which will be settled in cash when the underlying phantom units vest.
Recent Accounting Pronouncements
In February 2013 the FASB issued Accounting Standards Update (“ASU”) No. 2013-04, Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (“ASU 2013-04”), regarding accounting for obligations resulting from joint and several liability arrangements. ASU 2013-04 is effective for interim and annual periods beginning January 1, 2014. Early adoption is permitted with retrospective application. The Partnership adopted this standard upon issuance and has applied the requirements to its 2013 and 2012 combined and consolidated financial statements.
In December 2011, the FASB issued ASU No. 2011-11, Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). ASU 2011-11 retains the existing offsetting requirements and enhances the disclosure requirements to allow investors to better compare financial statements prepared under GAAP with those prepared under International Financial Reporting Standards (“IFRS”). On January 31, 2013, the FASB issued ASU No. 2013-01, Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities (“ASU 2013-01”). ASU 2013-01 limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements and securities lending transactions. Both standards are effective for interim and annual periods beginning January 1, 2013 and should be applied retrospectively. For the years ended December 31, 2013 and 2012, the Partnership had no offsetting in the financial statements.
In February 2013, the FASB issued Accounting Standards Update ASU No. 2013-02, Reporting Amounts Reclassified Out of Accumulated Comprehensive Income (“ASU 2013-02”), related to the reporting of amounts reclassified out of accumulated other comprehensive income. This guidance requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the face of the financial statements or in the related notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required to be reclassified in its entirety in the same reporting period. For amounts that are not required to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional details about those amounts. The guidance is effective for annual reporting periods, and interim periods within those years, beginning after December 15, 2012. Section 107 of the JOBS Act provides that an emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933, as amended, for complying with new or revised accounting standards. As such, the Partnership can delay the adoption of certain accounting standards until these standards would otherwise apply to private companies. The Partnership has elected to delay such adoption of new or revised accounting standards, and as a result, the Partnership will not adopt ASU 2013-02 until interim periods in 2014 as required by nonpublic entities.

PARTNERSHIP_EQUITY_AND_DISTRIB

PARTNERSHIP EQUITY AND DISTRIBUTIONS	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
PARTNERSHIP EQUITY AND DISTRIBUTIONS	'
	PARTNERSHIP EQUITY AND DISTRIBUTIONS
	As discussed in Note 1, on July 31, 2013, the Partnership completed the IPO of 6,875,000 common units, representing a 38.6% limited partner interest, to the public for $20.00 per common unit, less an underwriting discount of $1.20 per common unit. Additionally, 1,849,545 common units, representing a 10.4% limited partner interest, and 8,724,545 subordinated units, representing a 49.0% interest, were transferred to NuDevco Midstream Development, and 356,104 general partner units, representing a 2.0% general partner interest, were transferred to Marlin Midstream GP, LLC.
	Distributable Cash and Distributions
	The partnership agreement requires the Partnership to distribute all available cash to unitholders of record, as of the applicable record date, no later than 45 days after the end of each quarter, beginning with the quarter ending September 30, 2013. For the quarter ended September 30, 2013, the amount of the distribution was adjusted based on the net income of the Partnership for the period from the IPO date of July 31, 2013 through September 30, 2013.
	Available cash generally means, for any quarter, all cash and cash equivalents on hand at the end of that quarter:
	•less, the amount of cash reserves established by the General Partner to:
	◦	provide for the proper conduct of the business (including reserves for future capital expenditures and anticipated future debt service requirements and for anticipated shortfalls on future minimum commitment payments to which prior credits may be applied);
	◦	comply with applicable law, any of our debt instruments or other agreements; or
	◦	provide funds for distributions to unitholders and to the general partner for any one or more of the next four quarters (provided that the general partner may not establish cash reserves for distributions if the effect of the establishment of such reserves will prevent us from distributing the minimum quarterly distribution on all common units and any cumulative arrearages on such common units for the current quarter);
	•	plus, if the general partner so determines, all or any portion of the cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made subsequent to the end of such quarter.
	The Partnership declared the following cash distributions to its unitholders of record for the periods presented
	In Thousands, except per-unit amounts		Total Quarterly		Total		Date of
	Quarter ended:		Distribution per Unit		Distribution		Distribution
	December 31, 2013		$	0.35	$	6,341	3-Feb-14
	September 30, 2013	-1	$	0.23	$	4,167	4-Nov-13
	30-Jun-13	-2	—		—		—
	(1) This distribution represents a prorated amount of the full minimum quarterly distribution of $0.35 per unit for each whole quarter based on the number of days between the closing of the Partnership's IPO on July 31, 2013 and September 30, 2013.
	(2) No distributions were declared for the quarter ended June 30, 2013. This quarter was included in the results reported in the report on Form 10-Q for the second quarter ended June 30, 2013; however, this quarter was prior to the completion of the IPO.
	Subordinated Units and Common Units Held by NuDevco Midstream Development
	NuDevco Midstream Development owns 100% of the interest in the Partnership's general partner, which owns 2.0% of the Partnership, a 10.4% limited partner interest and 49.0% subordinated limited partner interest in the Partnership. The Partnership agreement provides that, during the subordination period described below, the subordinated units will not be entitled to receive any distributions until the common units have received the minimum quarterly distribution plus any arrearages from prior quarters. No arrearages accrue or are payable on the subordinated units.
	Except as described below, the subordination period began on the closing date of the IPO and extends until the first business day following the distribution of available cash in respect of any quarter beginning after September 30, 2016, that each of the following tests are met:
	•	distributions of available cash from operating surplus on each of the outstanding common units, subordinated units and general partner units equaled or exceeded $1.40 (the annualized minimum quarterly distribution), for each of the three consecutive, non-overlapping four-quarter periods immediately preceding that date;
	•	the adjusted operating surplus generated during each of the three consecutive, non-overlapping four-quarter periods immediately preceding that date equaled or exceeded the sum of $1.40 (the annualized minimum quarterly distribution) on all of the outstanding common units, subordinated units and general partner units during those periods on a fully diluted basis; and
	•	there are no arrearages in payment of the minimum quarterly distribution on the common units.

NET_INCOME_PER_UNIT

NET INCOME PER UNIT	12 Months Ended
	Dec. 31, 2013
NET INCOME PER UNIT [Abstract]	'
NET INCOME PER UNIT	'
	NET INCOME PER UNIT
	The net income per unit figures on the consolidated Statement of Operations are based on the net income of the Partnership after the closing of the offering on July 31, 2013 through December 31, 2013, since this is the amount of net income that is attributable to the newly issued common, general partner and subordinated units.
	The Partnership's net income for periods subsequent to the IPO is allocated to the general partner and the limited partners in accordance with their respective ownership percentages and, when applicable, giving effect to incentive distributions allocable to the general partner. There were no incentive distributions allocable to NuDevco as of December 31, 2013. Basic and diluted net income per unit is calculated by dividing the partner's interest in net income by the weighted average number of units outstanding during the period.
	The following table illustrates the Partnership’s calculation of net income per unit for common and subordinated partner units
	In Thousands, except per unit data
	Net income (post-IPO, August 1, 2013 to December 31, 2013)	$	7,190
	Less: general partner interest in net income	(144		)
	Limited partner interest in net income	$	7,046
	Net income allocable to common units	$	3,523
	Net income allocable to subordinated units	3,523
	Limited partner interest in net income	$	7,046
	Net income per limited partner common unit - basic	$	0.4
	Net income per limited subordinated unit - basic	$	0.4
	Net income per limited partner unit - basic	$	0.4
	Net income per limited partner common unit - diluted	$	0.39
	Net income per limited subordinated unit - diluted	$	0.4
	Net income per limited partner unit - diluted	$	0.4
	Weighted average limited partner units outstanding - basic
	Common units	8,724,545
	Subordinated units	8,724,545
	Total	17,449,090
	Weighted average limited partner units outstanding - diluted
	Common units	9,036,545
	Subordinated units	8,724,545
	Total	17,761,090

PROPERTY_PLANT_AND_EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
PROPERTY, PLANT AND EQUIPMENT	'
	PROPERTY, PLANT AND EQUIPMENT
	Net property, plant and equipment are composed of the following:
	In Thousands	Estimated Useful	December 31,			December 31,
		Lives (Years)	2013			2012
	Gas processing plants (1)	5 – 40	$	133,859		$	132,690
	Gathering pipelines and related equipment	5 – 40	47,728			36,853
	Land and rights of way	—	11,043			8,197
	Construction-in-progress	—	2,594			12,557
	Information technology and other	2 – 10	1,548			2,396
	Office building	15	306			306
	Autos	5	357			296
	Total		197,435			193,295
	Accumulated depreciation		(34,887		)	(28,156		)
	Property, plant and equipment, net		$	162,548		$	165,139
	-1	Includes inlet and residue pipelines and connections.
	The Partnership’s principal assets consist of two related natural gas processing facilities located in Panola County, Texas, a natural gas processing facility located in Tyler County, Texas, two natural gas gathering systems connected to its Panola County processing facilities and two NGL transportation pipelines that connect its Panola County and Tyler County processing facilities to third party NGL pipelines.
	In June 2006, the Partnership and Anadarko Gathering Company (“Anadarko”) entered into a collaborative agreement of construction, ownership and operation of the Monell processing facility located in Monell, Wyoming. Under the agreement, the Partnership and Anadarko each owned 50% of the ownership interest in the plant. The Partnership was responsible for design and construction of the Monell facility. Anadarko was designated as an operator of the facility who has exclusive right to operate the facility until terminated by unanimous vote of the owners. Revenue generated from and capital expenditures and operating expenses incurred in connection with the operation of the plant were allocated on a pro-rata basis in proportion to each owner’s ownership interest. The Partnership recorded its proportional cost of the Monell facility and its share of revenues and expenses in its consolidated and combined financial statements, as earned and incurred prior to the closing of the IPO, respectively.
	At the completion of the IPO, the Partnership transferred the Partnership's 50% interest in the CO2 processing facility located in Monell, Wyoming to affiliates of NuDevco. As such, subsequent to the closing of the IPO, the Partnership incurs no revenues or expenses associated with the Monell facility.
	For the years ended December 31, 2013, 2012 and 2011, the Partnership recorded revenues of $0.2 million, $1.2 million and $1.6 million, respectively, and recorded expenses of $0.3 million, $0.4 million and $0.4 million, respectively, attributable to the Monell facility in connection with the collaborative arrangement. These revenues are recorded in natural gas, NGLs and condensate revenue and the expenses are recorded in operation and maintenance in the consolidated and combined Statements of Operations.
	As of December 31, 2012, property, plant and equipment, net recorded in the combined Balance Sheet attributable to the Monell facility was $3.5 million. On July 31, 2013, in connection with the IPO, the Partnership transferred property, plant and equipment, net of $3.2 million attributable to the Monell facility to affiliates of NuDevco.
	The cost of property, plant and equipment classified as “Construction-in-progress” is excluded from costs being depreciated. These amounts represent property that is not yet suitable to be placed into productive service as of the respective balance sheet date.
	Depreciation expense was $8.2 million, $7.7 million and $5.4 million for the years ended December 31, 2013, 2012 and 2011 respectively.

LONGTERM_DEBT_AND_INTEREST_EXP

LONG-TERM DEBT AND INTEREST EXPENSE	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT AND INTEREST EXPENSE	'
	LONG-TERM DEBT AND INTEREST EXPENSE
	Long-term debt consists of the following:
	In Thousands		31-Dec-13			31-Dec-12
	Term loan		$	—		$	125,000
	Revolving credit facility		4,000			1,500
	Total debt		4,000			126,500
	Less: current maturities		—			6,250
	Total long-term debt		$	4,000		$	120,250
	In October 2007, SEV and all of its subsidiaries (collectively, the “Borrowers”), including Marlin Midstream, entered into a credit agreement, which provided for a working capital facility, a term loan and a revolving credit facility (the “Credit Agreement”), as co-borrowers and were jointly and severally liable for amounts borrowed under the Credit Agreement. The Credit Agreement was secured by substantially all of the assets of SEV and its subsidiaries, including all of Marlin Midstream’s assets.
	The Credit Agreement was amended on May 30, 2008 to provide for a $177.5 million working capital facility, a $100.0 million term loan, and a $35.0 million revolving credit facility. On January 24, 2011, the Borrowers amended and restated the Credit Agreement (the “Fifth Amended Credit Agreement”) to decrease the working capital facility to $150.0 million, to increase the term loan to $130.0 million and to eliminate the revolving credit facility.
	On December 17, 2012, the Borrowers amended and restated the Fifth Amended Credit Agreement to decrease the working capital facility to $70.0 million, to decrease the term loan to $125.0 million and to reinstate the revolving credit facility in the amount of $30.0 million (the “Sixth Amended Credit Agreement”). The Sixth Amended Credit Agreement was scheduled to mature on December 17, 2014.
	Although Marlin Midstream was jointly and severally liable for SEV’s borrowings, Marlin Midstream did not historically have access to the working capital facility, but was the primary recipient of the proceeds from the term loan and revolving credit facility.
	The Partnership applied ASU 2013-04, Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (“ASU 2013-04”), which prescribes the accounting for joint and several liability arrangements. This guidance requires an entity to measure its obligation resulting from joint and several liability arrangements for which the total amount under the arrangement is fixed at the reporting date, as the sum of the amount the reporting entity agreed to pay on the basis of its arrangement among its co-obligors and any additional amount the reporting entity expects to pay on behalf of its co-obligors. Based on the Sixth Amended Credit Agreement and understanding among the Borrowers, the term loan and the revolving credit facility were assigned specifically to Marlin Midstream. The Partnership recognized the proceeds from the term loan and the revolving credit facility on its combined Balance Sheet at December 31, 2012 in the amount of $126.5 million, which represented the amounts Marlin Midstream agreed with the other borrowers to pay, and the amounts Marlin Midstream expected to pay.
	Term Loan and Revolving Credit Facility
	Term loan
	The term loan consisted of $130.0 million in 2011 under the Fifth Amended Credit Agreement and was later amended on December 17, 2012 under the Sixth Amended Credit Agreement. The term loan consisted of outstanding borrowings of $125.0 million as of December 31, 2012 under the Sixth Amended Credit Agreement. The term loan required quarterly principal payments of $1.6 million to maturity, with the balance of $112.5 million due on December 17, 2014.
	Under the Sixth Amended Credit Agreement, Marlin Midstream may have elected to have loans under the term loan bear interest either (i) at a Eurodollar based rate plus a margin ranging from 3.50% to 4.25% depending on SEV’s consolidated funded indebtedness ratio then in effect, or (ii) at a base rate loan plus a margin ranging from 2.50% to 3.25% depending on SEV’s consolidated funded indebtedness ratio then in effect.
	The interest rate for the term loan was 3.96% at December 31, 2012. The Sixth Amended Credit Facility was repaid on July 31, 2013 with funds received from the IPO and borrowings under the Partnership's new credit facility.
	Revolving credit facility
	The revolving credit facility was reinstated on December 17, 2012 with a borrowing capacity of $30.0 million as part of the Sixth Amended Credit Agreement. The outstanding balance on the revolving credit facility at December 31, 2012 was $1.5 million. The revolving credit facility outstanding principal was due on December 31, 2014.
	The unused portion of the revolving credit facility was subject to a commitment fee of 0.50%. The interest rate was 3.96% at December 31, 2012. The Sixth Amended Credit Facility was repaid on July 31, 2013 with funds received from the IPO and borrowings under the Partnership's new credit facility.
	New Credit Facility
	Concurrently with the closing of our IPO, the Partnership entered into a new $50.0 million senior secured revolving credit facility, which matures on July 31, 2017. If no event of default has occurred, the Partnership has the right, subject to approval by the administrative agent and certain lenders, to increase the borrowing capacity under the new revolving credit facility to up to $150.0 million. The new credit facility is available to fund expansions, acquisitions and working capital requirements for our operations and general Partnership purposes.
	At the Partnership's election, interest will be generally determined by reference to:
	•	the Eurodollar rate plus an applicable margin between 3.0% and 3.75% per annum (based upon the prevailing senior secured leverage ratio); or
	•	the alternate base rate plus an applicable margin between 2.0% and 2.75% per annum (based upon the prevailing senior secured leverage ratio). The alternate base rate is equal to the highest of Société Générale’s prime rate, the federal funds rate plus 0.5% per annum or the reference Eurodollar rate plus 1.0%.
	The new revolving credit facility is secured by the capital stock of our present and future subsidiaries, all of our and our subsidiaries’ present and future property and assets (real and personal) control agreements relating to our and our subsidiaries’ bank accounts and collateral assignments of our and our subsidiaries’ material construction, ownership and operation agreements, including any agreements with AES or Anadarko.
	At the closing of the IPO, the Partnership borrowed $25.0 million under the new revolving credit facility, a portion of which, along with the proceeds from the IPO, was used to repay approximately $131.9 million of outstanding borrowings under the previous credit facility. Immediately upon repayment, the previous credit facility was terminated. At December 31, 2013, the Partnership had $4.0 million outstanding on the senior secured revolving credit facility.
	The new revolving credit facility contains various operational and financial covenants that are typical for these types of agreements and may restrict the Partnership from assuming certain types of debt, granting liens, selling substantial portions of assets, transferring assets, merging, dissolving, or otherwise materially changing the character of the business. As of December 31, 2013, the Partnership was in compliance with all debt covenants.
	Debt Maturities
	Principal amounts of long-term debt under the new senior secured revolving credit facility mature on July 31, 2017.
	Deferred Financing Costs
	Deferred financing costs were $1.0 million and $1.2 million as of December 31, 2013 and 2012, respectively. Of these amounts, $0.3 million and $0.7 million are included in other current assets within the consolidated and combined Balance Sheets at December 31, 2013 and 2012, respectively, and $0.7 million and $0.5 million are included in other assets within the consolidated and combined Balance Sheets at December 31, 2013 and 2012, respectively, based on the term of the related debt obligations.
	Amortization of deferred financing costs was $0.5 million, $0.4 million and $0.4 million for the years ended December 31, 2013, 2012 and 2011, respectively. Amortization of deferred financing costs is recorded in interest expense, net of amounts capitalized, in the consolidated and combined Statements of Operations.
	In conjunction with executing the Sixth Amended Credit Agreement in December 2012, the Partnership paid $1.0 million of financing costs, of which $0.9 million was capitalized and $0.1 million was expensed immediately in general and administrative expenses in the consolidated and combined Statements of Operations. Simultaneously, the Partnership expensed $0.2 million of existing unamortized deferred financing costs related to the Fifth Amended Credit Agreement, which is recorded in interest expense in the consolidated and combined Statements of Operations.
	In conjunction with executing the new revolving credit facility on July 31, 2013, the Partnership paid $1.1 million of financing costs, all of which were capitalized. Simultaneously, the Partnership expensed $0.8 million of existing unamortized deferred financing costs related to the Sixth Amended Credit Agreement, which is recorded in interest expense in the consolidated and combined Statements of Operations.
	Interest Expense
	A reconciliation of total interest expense to “interest expense, net of amounts capitalized” as reported in the consolidated and combined Statements of Operations for the years ended December 31, 2013 and 2012 is as follows:
	In Thousands	Years Ended December 31,
		2013			2012			2011
	Interest expense on long-term debt	$	3,312		$	4,599		$	4,545
	Interest expense from amortization of deferred financing costs	508			365			367
	Interest expense from write-off of unamortized deferred financing costs	761			177			—
	Less interest expense capitalized	(232		)	(214		)	(1,179		)
	Total interest expense, net of amounts capitalized	$	4,349		$	4,927		$	3,733

DERIVATIVE_FINANCIAL_INSTRUMEN

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
DERIVATIVE FINANCIAL INSTRUMENTS	'
	DERIVATIVE FINANCIAL INSTRUMENTS
	The Partnership historically used interest-rate related derivative instruments to manage its exposure related to changes in interest rates on its variable rate debt instruments and periodically used commodity derivatives to manage its exposure to commodity price fluctuations. The Partnership does not enter into speculative or trading derivative instruments.
	By using derivative financial instruments to hedge exposures to changes in interest rates and commodity prices, the Partnership exposed itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract was positive, the counterparty owed the Partnership, which created credit risk for the Partnership. When the fair value of the derivative contract was negative, the Partnership owed the counterparty, and therefore, the Partnership was not exposed to the counterparty’s credit risk in those circumstances. The Partnership minimized counterparty credit risk in derivative instruments by entering into transactions with high-quality counterparties. The derivative instruments entered into by the Partnership did not contain credit-risk-related contingent features.
	Market risk is the adverse effect on the fair value of a derivative instrument that results from a change in the underlying interest rates or commodity prices. For derivative instruments where hedge accounting is utilized, unrealized gains and losses recognized on derivative instruments due to changes in the fair value of the derivative instruments will offset corresponding realized gains and losses on the related hedged item. Unrealized gains or losses are recognized on the derivative instruments, to the extent the hedge is effective, are deferred in other comprehensive income, and recognized in income when the underlying hedged transaction is recognized. For derivative instruments where hedge accounting is not utilized, unrealized gains and losses due to changes in the fair value of the derivative instruments are recognized currently in earnings and may not fully offset current period realized gain or losses on the related hedged item. The market risk associated with interest rate and commodity price contracts is managed by establishing and monitoring parameters that limit the types and degree of market risk that may be undertaken.
	The Partnership maintains a commodity-price-risk management strategy that allows for the use of derivative instruments to minimize significant unanticipated earnings fluctuations caused by commodity-price-volatility. Since the Partnership has entered into primarily fee-based contracts, the Partnership did not have any outstanding commodity-price related derivative instruments as of December 31, 2013.
	Commodity Derivatives
	The Partnership was historically exposed to market risk from changes in energy commodity prices within its operations. The Partnership sold NGL volumes received as compensation for processing services and also bought natural gas to satisfy the required fuel and shrink needed to recover NGLs. To reduce exposure to a decrease in revenues from fluctuations in NGL market prices or increases in costs and operating expenses from fluctuations in natural gas market prices, the Partnership, at times, entered into NGL or natural gas derivative contracts to mitigate the price risk on forecasted sales of NGLs and purchases of natural gas. The Partnership’s NGL derivatives were designated as cash flow hedges, while its natural gas derivatives did not qualify for hedge accounting despite hedging its future cash flows on an economic basis.
	Changes in the fair value of commodity derivatives that were not designated as cash flow hedges were recorded within cost of revenues—affiliates in the consolidated and combined Statements of Operations. Changes in the fair value of designated cash flow hedges, to the extent effective, were deferred in other comprehensive income and reclassified into earnings in the same period or periods in which the hedged forecasted purchases or sales affected earnings, or when it was probable that the hedged forecasted transaction would not occur by the end of the originally specified time period. Settlements of derivatives were included in cash flows from operating activities for the Partnership. The Partnership has no outstanding commodity derivative instruments at December 31, 2013 or 2012.
	Interest Rate Swap
	On January 24, 2011, Marlin Midstream entered into an interest rate swap ("2011 Swap"). The 2011 Swap paid a fixed rate and received a floating rate in order to fix the interest rate on the Partnership’s term loan and was scheduled to mature on January 24, 2014. The notional amount of the 2011 Swap as of December 31, 2011 was $100.0 million.
	On December 17, 2012, Marlin Midstream terminated the 2011 Swap and entered into a new interest rate swap ("2012 Swap") in order to fix a portion of the interest rate on Marlin Midstream’s amended term loan. Marlin Midstream paid a fixed rate and received a floating rate under the 2012 Swap. The maturity date of the 2012 Swap was December 17, 2014, and the notional amount of the 2012 Swap at December 31, 2012 was $62.5 million. On July 31, 2013, in connection with the Partnership's IPO, the 2012 Swap was settled for approximately $0.1 million.
	Marlin Midstream’s interest rate swaps did not meet the criteria necessary to qualify for cash flow hedge accounting and were recorded at fair value at each reporting period with the associated unrealized gain or loss recorded in gain (loss) on interest rate swap in the consolidated and combined Statements of Operations.
	The following table presents the fair value of the Partnership’s derivative assets and liabilities including amounts for designated and undesignated hedge activities:
	In Thousands
	Description of Derivatives	Balance Sheet Location	December 31, 2013						December 31, 2012
			Assets			Liabilities			Assets			Liabilities
	Undesignated interest rate swap contract	Other assets	$	—		$	—		$	15		$	—
	Undesignated interest rate swap contract	Fair value of derivative	$	—		$	—		$	—		$	(72	)
		liabilities
	Total		$	—		$	—		$	15		$	(72	)
	The following table presents the net realized and unrealized gains (losses) recognized in net income for derivative instruments not designated as hedging instruments:
	In Thousands
	Description of Derivatives	Statement of Operations	Years Ended December 31,
		Location
			2013			2012			2011
	Natural gas option contracts	Cost of revenues—affiliates	$	—		$	(87	)	$	(496	)
	Interest rate swap contracts	Gain (loss) on interest rate swap	$	(48	)	$	(851	)	$	(2,176	)
	Total loss recognized in income		$	(48	)	$	(938	)	$	(2,672	)
	The following table presents the gain for NGL forward contracts designated and accounted for as cash flow hedges, as recognized in other comprehensive income and cost of revenues—affiliates:
	In Thousands
	Description of Derivatives	Location	Years Ended December 31,
			2013			2012			2011
	Gain recognized in accumulated other comprehensive income		$	—		$	689		$	122
		Accumulated other
		comprehensive income
	Gain reclassified from accumulated other comprehensive income to income	Cost of revenues—affiliates	$	—		$	(752	)	$	(59	)
	As of December 31, 2013 and 2012, respectively, there are no deferred gains or losses remaining in accumulated other comprehensive income as the Partnership did not have any open derivative instruments designated as cash flow hedges at December 31, 2013 and 2012, respectively.

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	FAIR VALUE OF FINANCIAL INSTRUMENTS
	FASB ASC 820, Fair Value Measurement, established a single authoritative definition of fair value when accounting rules require the use of fair value, set out a framework for measuring fair value and required additional disclosures about fair value measurements. The standard clarifies that fair value is an exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The standard utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
	•	Level 1—Quoted prices in active markets for identical assets or liabilities.
	•	Level 2—Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities).
	•	Level 3—Significant unobservable inputs (including the Partnership’s own assumptions in determining fair value).
	When the Partnership is required to measure fair value, and there is not a market-observable price for the asset or liability or a market-observable price for a similar asset or liability, the Partnership utilizes the cost, income, or market valuation approach depending on the quality of information available to support management’s assumptions.
	The following table provides the Partnership’s carrying values of financial instruments measured at fair value on a recurring basis, by input level. Financial instruments are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Partnership’s assessment of the significance of a particular input to the fair value requires judgment and may affect the placement of assets and liabilities within the fair value hierarchy levels. The Partnership has not presented its derivative assets and liabilities on a net basis in the consolidated and combined Balance Sheets and has not been required to maintain any cash collateral offset for any of its derivative financial instruments.
		Level 1		Level 2			Level 3		Total
	In Thousands
	31-Dec-13
	Interest rate swap liability—current	$	—	$	—		$	—	$	—
	Interest rate swap asset—long-term	$	—	$	—		$	—	$	—
	31-Dec-12
	Interest rate swap liability—current	$	—	$	(72	)	$	—	$	(72	)
	Interest rate swap asset—long-term	$	—	$	15		$	—	$	15
	The Partnership had no financial instruments at December 31, 2013. At the IPO date, the Partnership settled the outstanding interest rate swap.
	The Partnership had no financial instruments measured using Level 1 or 3 at December 31, 2012. The Partnership had no transfers of assets or liabilities between any of the above levels during 2013 and 2012. The interest rate swap derivatives were valued using current forward interest rates as quoted by brokers to be received in a cash market. The Partnership also considered counterparty credit rating, which is internally estimated in determining a credit adjustment. The credit adjustment was not material as of December 31, 2012.
	The estimated fair value of accounts receivable, accounts receivable - affiliates, accounts payable, accounts payable - affiliates and accrued liabilities approximate their carrying values due to their short-term nature. The estimated fair value of the Partnership’s outstanding long-term debt approximates carrying value due to the variable rate nature of the Partnership’s long-term debt.

SEGMENT_INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
SEGMENT INFORMATION	'
	SEGMENT INFORMATION
	The Partnership's revenues are derived from two operating segments: gathering and processing, and crude oil logistics. These segments, along with our corporate segment, are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment, and expertise required for their respective operations.
	The following tables present financial information by segment for the year ended December 31, 2013. Our crude oil logistics segment had no material assets, liabilities, or operations for the years ended December 31, 2012 and 2011, respectively.
	Year ended December 31, 2013
		Midstream		Crude Oil		Corporate and			Marlin Midstream
	In Thousands	Natural Gas		Logistics		Consolidation			Partners, LP
	Total Revenues	$	47,052	$	5,808	$	—		$	52,860
	Cost of revenues	13,999		—		—			13,999
	Operation and maintenance	14,424		613		854			15,891
	General and administrative	—		—		7,886			7,886
	Other operating expenses	9,390		23		—			9,413
	Total operating expenses	37,813		636		8,740			47,189
	Operating income	9,239		5,172		(8,740		)	5,671
	Interest expense, net of amounts capitalized	—		—		(4,349		)	(4,349		)
	Loss on interest rate swap	—		—		(48		)	(48		)
	Net income (loss) before tax	9,239		5,172		(13,137		)	1,274
	Texas margin tax expense	—		—		88			88
	Net income	$	9,239	$	5,172	$	(13,225	)	$	1,186
	Balance sheet at December 31, 2013
	In Thousands	Midstream		Crude Oil		Corporate and			Marlin Midstream
		Natural Gas		Logistics		Consolidation			Partners, LP
	Assets:
	Current Assets	$	5,727	$	1,195	$	3,772		$	10,694
	Property, Plant and Equipment, Net	162,029		519		—			162,548
	Other Assets	163		—		737			900
	Total Assets	$	167,919	$	1,714	$	4,509		$	174,142
	Liabilities and Partners' Capital
	Total current liabilities	$	2,796	$	353	$	6,077		$	9,226
	Total long-term liabilities	—		—		4,366			4,366
	Total liabilities	2,796		353		10,443			13,592
	Partners' Capital	165,123		1,361		(5,934		)	160,550
	Total liabilities and Partners' Capital	$	167,919	$	1,714	$	4,509		$	174,142

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	COMMITMENTS AND CONTINGENCIES
	In 2012, the Partnership entered into an agreement to purchase railcars with a future cash obligation of $12.6 million due in 2014. On July 31, 2013, in connection with the closing of the IPO, the Partnership transferred its deposit on the railcars of $0.7 million and assigned the future obligation to NuDevco Midstream Development. The deposit on railcars was recorded in other current assets at December 31, 2012 in the combined Balance Sheet.
	The Partnership has reserved capacity of 3,500 barrels a day at a third-party fractionator. If the Partnership fails to deliver 95% of the reserved capacity, the Partnership is obligated to pay a fixed fee. The maximum total fixed fee that the Partnership would be obligated to pay is approximately $2.2 million per year through the end of the contract, which expires April 30, 2015. The Partnership recorded $0.5 million of expense for the twelve months ended December 31, 2013 for deficiency payments for under delivery of volumes. No payments were accrued or paid in 2012.
	From time to time, the Partnership may be involved in legal, tax, regulatory and other proceedings in the ordinary course of business. Management does not believe that the Partnership is a party to any litigation that will have a material impact on our financial condition or results of operations.

TRANSACTIONS_WITH_AFFILIATES

TRANSACTIONS WITH AFFILIATES	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
TRANSACTIONS WITH AFFILIATES	'
	TRANSACTIONS WITH AFFILIATES
	From time to time, the Partnership enters into transactions with SEV related affiliates that have a common owner with the Partnership in order to reduce risk, create strategic alliances and supply or receive goods and services to these SEV related affiliates. For additional information relating to transactions with our affiliates coinciding with the closing of the IPO, please see Note 1, "Organization and Summary of Significant Accounting Policies" to our Consolidated Financial Statements included in this Form 10-K.
	Accounts receivable from and accounts payable to affiliates
	The Partnership had receivables due from affiliates of $3.6 million and $0.1 million at December 31, 2013 and 2012, respectively. At December 31, 2013, receivables due from affiliates primarily related to our fee-based gathering and processing agreement with a subsidiary of SEV, and our fee-based transloading services agreement with a subsidiary of SEV. Payables to affiliates were $1.6 million and $18.7 million at December 31, 2013 and 2012, respectively. At December 31, 2013, payables to affiliates primarily related to settlements under our gathering and processing agreement with a subsidiary of SEV and reimbursement to an affiliate of NuDevco for certain general and administrative and operating costs under the omnibus agreement with NuDevco. At December 31, 2012, payables to affiliates primarily related to gas purchases from affiliates to satisfy requirements under certain keep-whole contracts. Long-term incentive plan-payable to affiliates represents amounts accrued related to equity-based compensation to affiliate employees and directors.
	On April 8, 2013, SEV and the Partnership entered an Acknowledgment and Agreement, whereby SEV and the Partnership acknowledged and agreed that $14.7 million of the accounts payable-affiliates balance (the "Outstanding Amount") as of March 31, 2013 (i) was not required to be paid sooner than March 31, 2014, (ii) that no interest shall accrue on the Outstanding Amount or any future accounts payable-affiliates balances owed by the Partnership, and (iii) the Acknowledgment and Agreement does not preclude the Partnership from paying the Outstanding Amount prior to March 31, 2014. Accordingly, $14.7 million was reclassified to long-term accounts payable-affiliates in the December 31, 2012 combined Balance Sheet.
	On April 25, 2013, the Partnership received a capital contribution of $3.0 million from its sole member. On April 26, 2013, the Partnership paid $3.0 million of the Outstanding Amount, reducing the Outstanding Amount to $11.7 million.
	On June 3, 2013 SEV and the Partnership entered into a revised Acknowledgment and Agreement, whereby SEV and the Partnership acknowledged and agreed that $11.7 million of the accounts payable-affiliates balance (the "Remaining Outstanding Amount") as of March 31, 2013 (i) was not required to be paid sooner than July 31, 2014, (ii) that no interest shall accrue on the Remaining Outstanding Amount or any future accounts payable­ affiliates balances owed by the Partnership, and (iii) the Acknowledgment and Agreement does not preclude the Partnership from paying the Remaining Outstanding Amount prior to July 31, 2014.
	In July 2013, in connection with the closing of the IPO, NuDevco Midstream Development assumed the Remaining Outstanding Amount of $11.7 million accounts payable-affiliates balance and the Partnership was released from such obligation.
	Revenues and cost of revenues
	Prior to the IPO on July 31, 2013, the Partnership provided processing services for a subsidiary of SEV, whereby the Partnership gathered natural gas from third parties, extracted NGLs, and redelivered the processed natural gas to the subsidiary of SEV. Under certain third-party contracts, the Partnership transferred all natural gas purchased to the subsidiary of SEV at market price. The Partnership also replaced energy used in processing due to the extraction of liquids, compression and transportation of natural gas, and fuel by purchasing natural gas from a subsidiary of SEV at the same market price. The Partnership used the MMBtu volume to measure how much energy is used in processing. Cost of natural gas, NGLs and condensate revenue—affiliates included in the Partnership’s results of operations for the years ended December 31, 2013, 2012 and 2011 from these agreements were $3.0 million, $7.7 million and $17.4 million, respectively.
	Additionally, the Partnership has entered into a gas transportation agreement with a subsidiary of SEV. The Partnership receives the higher of (i) a minimum monthly payment or (ii) a transportation fee per MMBtu times actual volumes delivered. The current transportation agreement was set to expire on February 28, 2013, but was extended for three additional years at a fixed rate per MMBtu without a minimum monthly payment. Included in the Partnership’s results of operations for the years ended December 31, 2013, 2012 and 2011 are gathering, processing and other revenue—affiliates of less than $0.1 million, $0.3 million and $0.3 million, respectively, related to these transactions.
	In connection with the IPO, the Partnership entered into a three-year fee-based commercial agreement with a subsidiary of SEV, requiring a minimum monthly volume commitment of 80 MMcf/d. This agreement became effective August 1, 2013. Included in the Partnership's results of operations for the year ended December 31, 2013 are gathering, processing, transloading and other revenue—affiliates of $7.1 million related to this agreement. Cost of natural gas, NGLs and condensate revenue - affiliates included in the Partnership’s results of operations for the year ended December 31, 2013 related to this agreement were $2.5 million.
	In connection with the IPO, the Partnership entered into three-year transloading services agreements with a subsidiary of SEV, requiring minimum monthly volume commitments for crude oil transloading services. Included in the Partnership's results of operations for the year ended December 31, 2013 are gathering, processing, transloading and other revenue—affiliates of $5.8 million related to these agreements.
	Cost allocations
	Prior to the IPO, SEV and its affiliates had paid certain expenses on behalf of the Partnership, such as insurance, professional fees, and financing fees. These expenses were reimbursed by the Partnership to SEV and its affiliates and are included in operation and maintenance—affiliates and general and administrative—affiliates in the consolidated and combined Statements of Operations. In addition, SEV and its affiliates have allocated certain overhead costs associated with general and administrative services, including facilities, information services, human resources and other support departments to the Partnership. Where costs incurred on the Partnership’s behalf could not be determined by specific identification, the costs were primarily allocated to the Partnership based on percentage of departmental usage, wages or headcount. The Partnership believes these allocations were a reasonable reflection of the utilization of services provided. However, the allocations may not fully reflect the expenses that would have been incurred had the Partnership been a stand-alone company during the periods presented.
	At the closing of the IPO, the Partnership entered into an omnibus agreement with NuDevco and its affiliates which addresses the management and administrative and overhead services to be provided by NuDevco to the Partnership and the corresponding fees and expense reimbursements to be paid to NuDevco in connection therewith. Under the omnibus agreement, the Partnership pays an annual fee, initially in the amount of $0.6 million, for executive management services.
	The total amount charged to the Partnership for direct reimbursement of operating and overhead cost allocations, which is recorded in operation and maintenance—affiliates, for the years ended December 31, 2013, 2012 and 2011 was $3.5 million, $0.8 million and $0.3 million, respectively. The total amount charged to the Partnership for direct reimbursement of administrative and overhead cost allocations, which is recorded in general and administrative—affiliates, for the years ended December 31, 2013, 2012 and 2011 was $4.2 million, $1.0 million and $0.9 million, respectively. Amounts incurred by the Partnership for the year ended 2013 include expense for the Marlin Midstream Partners, LP 2013 Long-Term Incentive Plan ("LTIP").
	Equipment purchase
	In 2012, the Partnership purchased a field office facility, vehicles and computer equipment from an affiliate of SEV for $0.3 million. The purchased assets were bought by the Partnership at SEV’s historical cost basis at the time of sale, as the transactions were between entities under common control.
	On October 25, 2013, the Partnership entered into a non-binding letter of intent to purchase a skid transloader, coupled with a transloading services agreement, from NuDevco Midstream Development for approximately $45.0 million. That letter of intent expired on December 31, 2013. As part of the letter of intent, an earnest money deposit of $2.5 million was paid by the Partnership on October 25, 2013, which would either be applied to the purchase price or refunded in full to the Partnership. The letter on intent expired on December 31, 2013, and the earnest money deposit of $2.5 million was refunded to the Partnership.
	Capital Contributions
	During the seven months prior to the IPO on July 31, 2013, the Partnership received capital contributions of $3.6 million from its sole member, who is also the sole member of SEV and NuDevco.

EQUITY_BASED_COMPENSATION

EQUITY BASED COMPENSATION	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
EQUITY BASED COMPENSATION	'
	EQUITY BASED COMPENSATION
	In connection with the IPO, the board of directors of the Partnership’s general partner adopted the LTIP. Individuals who are eligible to receive awards under the LTIP include (1) employees of the Partnership and NuDevco Midstream Development and its affiliates, (2) directors of the Partnership’s general partner, and (3) consultants. The LTIP provides for the grant of unit options, unit appreciation awards, restricted units, phantom units, distribution equivalent rights, unit awards, profits interest units, and other unit-based awards. The maximum number of common units issuable under the LTIP is 1,750,000.
	On August 1, 2013, phantom units, with distribution equivalent rights, of 292,000 units were awarded to certain employees of NuDevco Midstream Development and its affiliates who provide direct or indirect services to the Partnership pursuant to affiliate agreements, and 20,000 units were awarded to certain board members of the Partnership’s general partner. All of the phantom unit awards granted to-date are considered non-employee equity based awards and are required to be remeasured at fair market value at each reporting period and amortized to compensation expense on a straight-line basis over the vesting period of the phantom units with a corresponding increase in a liability. Management intends to settle the awards by allowing the recipient to choose between issuing the net amount of common units due, less common units equivalent to pay withholding taxes, due upon vesting with the Partnership paying the amount of withholding taxes due in cash or issuing the gross amount of common units due with the recipient paying the withholding taxes. The phantom unit awards were awarded to individuals who are not deemed to be employees of the Partnership.
	Distribution equivalent rights are accrued for each phantom unit award as the Partnership declares cash distributions and are recorded as a decrease in partners’ capital with a corresponding liability in accordance with the vesting period of the underlying phantom unit, which will be settled in cash when the underlying phantom units vest. As of December 31, 2013, a liability of approximately $32,000 was recorded for distributions associated with unvested phantom units under our LTIP plan.
	The phantom units awarded to employees of NuDevco Midstream Development and its affiliates will vest in five equal annual installments with the first installment vesting on June 30, 2014, provided that for any individual who has attained a total of five or more years of service with NuDevco Midstream Development or its affiliates at the grant date of award the phantom unit awards fully vested on February 15, 2014. The phantom unit awards to board members of the Partnership’s general partner fully vested on February 15, 2014.
	For the year ended December 31, 2013, approximately $2.1 million in compensation expense was recorded in general and administrative expenses - affiliates and approximately $0.9 million in compensation expense was recorded in operation and maintenance - affiliates in the consolidated Statement of Operations. No compensation expense was recorded for the same periods in 2012 as there were no LTIP awards outstanding. A summary of the phantom units activity for the year ended December 31, 2013 is presented below:
		Number of shares	Weighted Average Grant-Date Fair Value
	Total Non-vested at January 1, 2013	—	$	—
	Granted	312,000	20
	Exercised	—	—
	Forfeited or canceled	—	—
	Total Outstanding at December 31, 2013	312,000	$	20
	Unrecognized compensation expense associated with the unvested phantom units at December 31, 2013 was approximately $2.2 million and is expected to be recognized over a weighted average period of approximately five years.

CONCENTRATIONS_OF_CREDIT_RISK

CONCENTRATIONS OF CREDIT RISK	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
CONCENTRATIONS OF CREDIT RISK	'
	CONCENTRATIONS OF CREDIT RISK
	Substantially all of the Partnership’s receivables are from companies in a similar industry and include independent exploration and production companies, pipeline companies and marketers. The industry concentration of these customers may impact the Partnership’s overall exposure to credit risk, either positively or negatively, as its customers may be similarly affected by changes in commodity prices, regulation and other economic factors. The Partnership performs credit analysis in order to monitor its credit risks and ensure that its customers are creditworthy.
	Following the closing of the IPO, the Partnership's revenues are mainly derived from fees earned from minimum capacity agreements for its midstream operations, which includes gathering and processing fees, and fees earned from its minimum capacity transloading agreements. In addition, the Partnership derives revenues from the sale of NGLs produced from natural gas processing. Total revenues from two third-party customers and one affiliate customer constituted approximately 98% of total revenues for the year ended December 31, 2013.
	Historically, the Partnership’s revenues were derived mainly from the sale of NGLs produced from natural gas processing and fees earned from its midstream operations including gathering and processing. Revenues from two third-party customers constituted approximately 93% and 97% of total revenues for the years ended December 31, 2012 and 2011, respectively. The Partnership had contractual arrangements with both customers negotiated at standard commercial terms for the provision of services and/or sale of NGLs with remaining terms ranging from two to six years.

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	SUBSEQUENT EVENTS
	On January 21, 2014, the Partnership announced that the board of directors of its general partner declared a quarterly cash distribution of $0.35 per unit, or $1.40 on an annualized basis, to unitholders of record as of February 3, 2014. The Partnership paid the quarterly distribution to unitholders on February 7, 2014.

SUPPLEMENTAL_QUARTERLY_FINANCI

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited)	'
	SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited)
	Marlin Midstream Partners, LP
	Summarized quarterly financial data for the year ended December 31, 2013 is as follows:
		For the year ending December 31, 2013
	in thousands except volume and per unit amounts	Q1			Q2			Q3			Q4			TOTAL
	Revenues	$	7,504		$	10,298		$	18,950		$	16,108		$	52,860
	Cost of revenues	2,528			2,680			6,479			2,312			13,999
	Gross margin	4,976			7,618			12,471			13,796			38,861
	Operating expenses	3,896			3,700			4,283			4,012			15,891
	G&A expenses	1,411			1,321			2,482			2,672			7,886
	Other operating expenses	2,219			2,369			2,349			2,476			9,413
	Operating income	(2,550		)	228			3,357			4,636			5,671
	Other income(expense)	(1,374		)	(1,421		)	(1,424		)	(178		)	(4,397		)
	Net income before Texas margin tax	$	(3,924	)	$	(1,193	)	$	1,933		$	4,458		$	1,274
	Net income per limited partner unit - basic year-to-date							$	0.16		$	0.4
	Net income per limited partner unit - diluted year-to-date							$	0.15		$	0.39
	Weighted average limited partner units outstanding - basic							17,449,090			17,449,090
	Weighted average limited partner units outstanding - diluted							17,761,090			17,761,090
	Adjusted quarterly EBITDA for the year ended December 31, 2013 is as follows:
		Q1		Q2		Q3		Q4		Total
	Net income (loss)	(3,935	)	(1,206	)	1,922		4,405		1,186
	Interest expense, net of amounts capitalized	1,363		1,426		1,382		178		4,349
	Texas margin tax expense	11		13		11		53		88
	Equity-based compensation	—		—		1,284		1,728		3,012
	Loss on interest rate swap	10		(5	)	43		—		48
	Depreciation expense	1,984		2,050		2,058		2,105		8,197
	Adjusted EBITDA	(567	)	2,278		6,700		8,469		16,880

BASIS_OF_PRESENTATION_Policies

BASIS OF PRESENTATION (Policies)	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	Cash and cash equivalents consist of all unrestricted demand deposits and funds invested in highly liquid instruments with original maturities of three months or less. The Partnership periodically assesses the financial condition of the institutions where these funds are held and believes that its credit risk is minimal.
Accounts Receivable	'
	Accounts Receivable
	Trade accounts receivable are recorded at the invoiced amount and do not bear interest. Amounts collected on trade accounts receivable are included in net cash provided by operating activities in the consolidated and combined statements of cash flows. The Partnership does not maintain an allowance for doubtful accounts. The Partnership elects to use the direct write-off method based on its collection history.
Inventory	'
	Inventory
	Inventory consists of NGLs and chemicals in bulk storage and is valued at the lower of weighted average cost or market. NGL inventories are used for sales contract requirements. Chemical inventories are expensed as transferred from bulk storage into production and are recorded in operation and maintenance in the consolidated and combined statements of operations.
Deferred Financing Costs	'
	Deferred Financing Costs
	Costs incurred in connection with the issuance of long-term debt are capitalized and amortized to interest expense using the effective interest method over the life of the related debt.
Property, Plant and Equipment	'
	Property, Plant and Equipment
	Property, plant and equipment are stated at cost. Depreciation on property, plant and equipment is recorded on a straight-line basis for groups of property having similar economic characteristics over the estimated useful lives (primarily 5 to 40 years). Uncertainties that may impact these estimates include, but are not limited to, changes in laws and regulations relating to environmental matters, including air and water quality, restoration and abandonment requirements, economic conditions and supply and demand in the area. When assets are placed into service, management makes estimates with respect to useful lives. However, subsequent events could cause a change in estimates, thereby impacting future depreciation amounts.
	When items of property, plant and equipment are sold or otherwise disposed of, gains or losses are reported in the consolidated and combined statements of operations.
	The Partnership capitalizes all construction-related direct labor and material costs, as well as indirect construction costs. Indirect construction costs include general engineering, insurance, taxes and the cost of funds used during construction. Capitalized interest is calculated by multiplying the Partnership’s monthly weighted average interest rate on outstanding debt by the amount of qualifying costs. Capitalized interest cannot exceed monthly gross interest expense. After major construction projects are completed, the associated capitalized costs including interest are depreciated over the estimated useful life of the related asset. During the years ended December 31, 2013 and 2012, respectively, the Partnership recorded $0.2 million and $0.2 million of capitalized interest, respectively.
	Costs, including complete asset replacements and enhancements or upgrades that increase the original efficiency, productivity or capacity of property, plant and equipment, are also capitalized. In addition, certain of the Partnership’s plant assets require periodic and scheduled maintenance, such as overhauls. The cost of these scheduled maintenance projects are capitalized and depreciated on a straight-line basis until the next planned maintenance, which generally occurs every 5 years.
	Costs for planned integrity management projects are expensed in the period incurred. These types of costs include in-line inspection services, contractor repair services, materials and supplies, equipment rentals and labor costs. The costs of repairs, minor replacements and maintenance projects, which do not increase the original efficiency, productivity or capacity of property, plant and equipment, are expensed as incurred.
Impairment or Long-Lived Assets	'
	Impairment of Long-lived Assets
	The Partnership evaluates its long-lived assets for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. A long-lived asset is considered impaired when the sum of the estimated, undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset. When alternative courses of action to recover the carrying amount of a long-lived asset are under consideration, estimates of future undiscounted cash flows take into account possible outcomes and probabilities of their occurrence. If the carrying amount of the long-lived asset is not recoverable based on the estimated future undiscounted cash flows, an impairment loss is recognized to the extent the carrying value exceeds the estimated fair value of the long-lived asset. With respect to natural gas processing plants and pipelines and NGL pipelines, management considers the volume of third-party reserves behind the asset and future NGL and natural gas prices to estimate cash flows. The amount of additional reserves developed by future drilling activity depends, in part, on expected natural gas prices. Projections of reserves, drilling activity, and future commodity prices are inherently subjective and contingent upon a number of variable factors, many of which are difficult to forecast. Any significant variance in any of these assumptions or factors could materially affect future cash flows, which could result in the impairment of an asset group.
	For assets identified to be disposed of in the future, the carrying value of these assets is compared to the estimated fair value, less the cost to sell, to determine if impairment is required. Until the assets are disposed of, an estimate of the fair value is determined when related events occur or circumstances change.
Segment Reporting	'
	Segment Reporting
	The Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 280, Segment Reporting, established standards for entities to report information about the operating segments and geographic areas in which they operate. The Partnership operates two segments, gathering and processing and crude oil logistics, and all of its operations are located in the United States.
Revenues and Cost of Revenues	'
	Revenues and Cost of Revenues
	The Partnership’s revenues are derived primarily from natural gas processing and fees earned from its gathering and processing operations. Revenues are recognized by the Partnership using the following criteria: (1) persuasive evidence of an exchange arrangement exists, (2) delivery has occurred or services have been rendered, (3) the buyer’s price is fixed or determinable and collection is reasonably assured. Utilizing these criteria, revenues are recognized when the commodity is delivered or services are rendered. Similarly, cost of revenues is recognized when the commodity is purchased or delivered.
	The Partnership’s fee-based contracts provide for a fixed fee arrangement for one or more of the following midstream services: natural gas gathering, compression, dehydration, treating, processing and hydrocarbon dew-point control and transportation services to producers, third- party pipeline companies and marketers. Under these arrangements, the Partnership is paid a fixed fee based on the volume of the natural gas the Partnership gathers and processes, and recognizes revenues for its services in the month such services are performed. Substantially all of these fee-based agreements contain minimum volume commitments and annual inflation adjustments.
	Historically, under commercial agreements that did not require us to deliver NGLs to the customer in kind, we provided NGL transportation services to the customer whereby we purchased the NGLs from the customer at an index price, less fractionation and transportation fees, and simultaneously sold the NGLs to third parties at the same index price, less fractionation fees. The revenue generated by these activities was offset by a corresponding cost of revenues that was recorded when we compensated the customer for its share of the NGLs.
	Producers’ wells and other third-party gathering systems are connected to the Partnership’s gathering systems for delivery of natural gas to the Partnership’s processing and treating plants, where the natural gas is processed to extract NGLs and condensate or treated in order to satisfy downstream natural gas pipeline specifications. Under percentage of liquids (“POL”) arrangements, the Partnership retained a percentage of the liquids processed. Both the Partnership and producer depended on the volume of the commodity and its value and each party received a percentage of the commodity revenues. Revenues were directly correlated to the commodity’s market value. POL contracts also include fee-based revenues for gathering and other midstream services. Under both fixed fee and POL arrangements, the counterparties’ share of NGLs, if not delivered as a commodity, was recorded as cost of revenues.
	Under its keep-whole contracts, the Partnership was required to gather or purchase raw natural gas at current market rates. The volume of gas gathered or purchased was based on the measured volume at an agreed upon location (generally at the wellhead). The volume of gas redelivered or sold at the tailgate of the Partnership’s processing facility would be lower than the volume purchased at the wellhead primarily due to NGLs extracted through processing. The Partnership would make up or “keep the producer whole” for the condensate and NGL volumes through the delivery of or payment for a thermally equivalent volume of residue gas. The cost of these natural gas volumes was recorded as a cost of natural gas, NGLs and condensate revenue-affiliates. The keep-whole contract conveyed an economic benefit to the Partnership when the combined value of the individual NGLs was greater in the form of liquids than as a component of the natural gas stream; however, the Partnership was adversely impacted when the value of the NGLs is lower as liquids than as a component of the natural gas stream. Certain contracts also included fee-based revenues for gathering and other midstream services. Cost of revenues were derived primarily from the purchase of natural gas, NGLs and condensates. There were no material costs categorized as cost of revenue directly identified with gathering, processing and other revenue.
Natural Gas Imbalances	'
	Natural Gas Imbalances
	The consolidated and combined balance sheets include natural gas imbalance receivables and payables caused by the difference in natural gas delivered to the Partnership’s customers and the natural gas contractually owed to the customers. Most natural gas imbalances are settled monthly in cash and calculated according to the terms of their contracts. Changes in gas imbalances are reported net of the cost of product in the consolidated and combined statements of operations. As of December 31, 2013 and 2012, the Partnership recorded an imbalance receivable of $0.1 million and $0.2 million, respectively, which is recorded in accounts receivable in the consolidated and combined balance sheets.
Hedging and Derivatives	'
	Hedging and Derivatives
	From time to time, the Partnership entered into derivative transactions to mitigate its exposure to price fluctuations in NGLs. The Partnership recognized all derivative instruments as either assets or liabilities in the combined balance sheet at their respective fair value. For derivatives designated in hedging relationships, changes in the fair value were recognized in accumulated other comprehensive income, to the extent the derivative was effective at offsetting the changes in cash flows being hedged, until the hedged item affected earnings. As of the date of our IPO on July 31, 2013, we settled our outstanding interest rate swap and have discontinued our hedging and derivatives program.
	Interest Rate Swaps
	The Partnership utilizes derivative instruments to manage its exposure to interest rate risk. In January 2011, the Partnership entered into an interest rate swap for this purpose (“2011 Swap”). The 2011 Swap did not meet the criteria necessary to qualify for cash flow hedge accounting and was recorded at fair value at each reporting period with changes in fair value recognized currently in earnings. The 2011 Swap was settled in full on December 17, 2012. On December 17, 2012, the Partnership entered into a new interest rate swap (“2012 Swap”) to manage its exposure to interest rate risk. The 2012 Swap did not meet the criteria necessary to qualify for cash flow hedge accounting and is recorded at fair value at each reporting period with changes in fair value recognized currently in earnings. Gains and losses on interest rate swaps are recorded in gain (loss) on interest rate swap in the combined statements of operations.
Interest Rate Swaps	'
	Interest Rate Swaps
	The Partnership utilizes derivative instruments to manage its exposure to interest rate risk. In January 2011, the Partnership entered into an interest rate swap for this purpose (“2011 Swap”). The 2011 Swap did not meet the criteria necessary to qualify for cash flow hedge accounting and was recorded at fair value at each reporting period with changes in fair value recognized currently in earnings. The 2011 Swap was settled in full on December 17, 2012. On December 17, 2012, the Partnership entered into a new interest rate swap (“2012 Swap”) to manage its exposure to interest rate risk. The 2012 Swap did not meet the criteria necessary to qualify for cash flow hedge accounting and is recorded at fair value at each reporting period with changes in fair value recognized currently in earnings. Gains and losses on interest rate swaps are recorded in gain (loss) on interest rate swap in the combined statements of operations.
Fair Value	'
	Fair Value
	FASB ASC 820, Fair Value Measurement, established a single authoritative definition of fair value when accounting rules require the use of fair value, set out a framework for measuring fair value and required additional disclosures about fair value measurements. The standard clarifies that fair value is an exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. The standard utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
	•Level 1-Quoted prices in active markets for identical assets or liabilities.
	•Level 2-Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities).
	•Level 3-Significant unobservable inputs (including the Partnership’s own assumptions in determining fair value).
	When the Partnership is required to measure fair value, and there is not a market-observable price for the asset or liability or a market- observable price for a similar asset or liability, the Partnership utilizes the cost, income, or market valuation approach depending on the quality of information available to support management’s assumptions.
	The carrying amount of long-term debt reported on the consolidated and combined balance sheets approximates fair value, because of the variable rate nature of the Partnership’s long-term debt. The carrying amounts of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities reported on the consolidated and combined balance sheets approximate fair value due to the short-term nature of these items. The fair value of the Partnership’s accounts receivable with affiliates and accounts payable with affiliates cannot be determined due to the related party nature of these items. Derivative instruments are measured at fair value at each reporting period.
Asset Retirement Obligations	'
	Asset Retirements Obligations
	FASB ASC 410, Asset Retirement and Environmental Obligations, requires the Partnership to evaluate whether any future asset retirement obligations exist as of December 31, 2013 and 2012, and whether the expected retirement date of the related costs of retirement can be estimated. The Partnership has concluded that its natural gas gathering system assets, which include pipelines and treating facilities, have an indeterminate life because they are owned and will operate for an indeterminate future period when properly maintained. A liability for these asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life is identified. The Partnership did not record any asset retirement obligations as of December 31, 2013 and 2012 because the Partnership has no current intention of discontinuing use of any significant assets.
Environmental Expenditures	'
	Environmental Expenditures
	The operations of the Partnership are subject to various federal, state and local laws and regulations relating to the protection of the environment. Although the Partnership believes that it is in compliance with applicable environmental regulations, the risk of costs and liabilities are inherent in pipeline ownership and operation, and there can be no assurances that significant costs and liabilities will not be incurred by the Partnership.
	Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Liabilities are recorded when the necessity for environmental remediation or other potential environmental liabilities become probable and the costs can be reasonably estimated. Management is not aware of any contingent liabilities that currently exist with respect to environmental matters.
Income Taxes	'
	Income Taxes
	The Partnership is not a taxable entity for U.S. federal income tax purposes or for the majority of states that impose an income tax. Therefore, income taxes are not levied at the entity level, but rather on the individual partners of the Partnership. Accordingly, the accompanying consolidated and combined financial statements do not include a provision for federal and state income taxes. The Partnership is subject to the Revised Texas Franchise Tax (“Texas Margin Tax”). The Texas Margin Tax is computed on modified gross margin and was not significant for the years ended December 31, 2013, 2012 and 2011, and is recorded as Texas margin tax expense in the consolidated and combined statements of operations. The Partnership does not do business in any other state where a similar tax is applied.
Net Income Per Unit	'
	Net Income Per Unit
	The Partnership has omitted net income per unit for all historical periods prior to the IPO at July 31, 2013 because the Partnership operated under a sole member equity structure, which is different than the capital structure resulting from the consummation of the IPO and, as a result, the per unit data for periods prior to the IPO would not be meaningful to investors.
	The net income per unit figures on the consolidated Statement of Operations is based on the net income of the Partnership after the closing of the IPO on July 31, 2013 through December 31, 2013, since this is the amount of net income that is attributable to the newly issued Partnership units.
Commitments and Contingencies	'
	Commitments and Contingencies
	Liabilities for loss contingencies arising from claims, assessments, litigation, fines, penalties and other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably estimated. Legal costs incurred in connection with loss contingencies are expensed as incurred. Recoveries of environmental remediation costs from third parties that are probable of realization are separately recorded as assets, and are not offset against the related environmental liability.
	Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study. Such accruals are adjusted as further information develops or circumstances change. Costs of expected future expenditures for environment remediation obligations are not discounted to their present value.
Transactions with Affiliates	'
	Transactions with Affiliates
	From time to time, the Partnership enters into transactions with SEV related affiliates that have a common owner with the Partnership in order to reduce risk, create strategic alliances and supply or receive goods and services to these SEV related affiliates. As such, the accompanying consolidated and combined financial statements include costs that have been incurred by SEV on behalf of the Partnership. These amounts incurred by SEV are then billed or allocated to the Partnership and are classified on the consolidated and combined statements of operations as either direct operation and maintenance-affiliates or as general and administrative-affiliates.
	At our IPO, the Partnership entered into an omnibus agreement with the general partner and its affiliates that addresses (i) the management and administrative services to be provided by NuDevco to the Partnership and the corresponding fees and expense reimbursements to be paid to NuDevco in connection therewith, (ii) the indemnification obligations between NuDevco and the Partnership for environmental and other liabilities and the operation of assets and (iii) the Partnership's right of first offer on certain of NuDevco Midstream Development's midstream energy assets.
Use of Estimates and Assumptions	'
	Use of Estimates and Assumptions
	The preparation of the Partnership’s consolidated and combined financial statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated and combined financial statements and the reported amounts of revenues and expenses during the reporting period. Certain prior year amounts have been reclassified to conform to the current year presentation. Actual results could materially differ from those estimates. Significant items subject to such estimates by the Partnership’s management include provisions for uncollectible receivables, valuation of long-lived assets and related estimated useful lives, valuation of derivatives, valuation of equity-based compensation, and reserves for contingencies.
Accounting for Awards under the Long-term Incentive Plan	'
	Accounting for Awards under the Long-term Incentive Plan
	The Long-term Incentive Plan ("LTIP") provides for the grant of unit options, unit appreciation awards, restricted units, phantom units, distribution equivalent rights, unit awards, profits interest units, and other unit-based awards. On August 1, 2013, phantom units, with distribution equivalent rights, of 292,000 units were awarded to certain employees of NuDevco Midstream Development and its affiliates who provide direct or indirect services to the Partnership pursuant to affiliate agreements, and 20,000 units were awarded to certain board members of the Partnership’s general partner. All of the phantom unit awards granted to-date are considered non-employee equity based awards and are required to be remeasured at fair market value at each reporting period and amortized to compensation expense on a straight-line basis over the vesting period of the phantom units with a corresponding increase in a liability. Management intends to settle the awards by allowing the recipient to choose between issuing the net amount of common units due, less common units equivalent to pay withholding taxes, due upon vesting with the Partnership paying the amount of withholding taxes due in cash or issuing the gross amount of common units due with the recipient paying the withholding taxes. The phantom unit awards were awarded to individuals who are not deemed to be employees of the Partnership.
	Distribution equivalent rights are accrued for each phantom unit award as the Partnership declares cash distributions and are recorded as a decrease in partners’ capital with a corresponding liability in accordance with the vesting period of the underlying phantom unit, which will be settled in cash when the underlying phantom units vest.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	In February 2013 the FASB issued Accounting Standards Update (“ASU”) No. 2013-04, Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date (“ASU 2013-04”), regarding accounting for obligations resulting from joint and several liability arrangements. ASU 2013-04 is effective for interim and annual periods beginning January 1, 2014. Early adoption is permitted with retrospective application. The Partnership adopted this standard upon issuance and has applied the requirements to its 2013 and 2012 combined and consolidated financial statements.
	In December 2011, the FASB issued ASU No. 2011-11, Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). ASU 2011-11 retains the existing offsetting requirements and enhances the disclosure requirements to allow investors to better compare financial statements prepared under GAAP with those prepared under International Financial Reporting Standards (“IFRS”). On January 31, 2013, the FASB issued ASU No. 2013-01, Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities (“ASU 2013-01”). ASU 2013-01 limits the scope of the new balance sheet offsetting disclosures to derivatives, repurchase agreements and securities lending transactions. Both standards are effective for interim and annual periods beginning January 1, 2013 and should be applied retrospectively. For the years ended December 31, 2013 and 2012, the Partnership had no offsetting in the financial statements.
	In February 2013, the FASB issued Accounting Standards Update ASU No. 2013-02, Reporting Amounts Reclassified Out of Accumulated Comprehensive Income (“ASU 2013-02”), related to the reporting of amounts reclassified out of accumulated other comprehensive income. This guidance requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the face of the financial statements or in the related notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required to be reclassified in its entirety in the same reporting period. For amounts that are not required to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional details about those amounts. The guidance is effective for annual reporting periods, and interim periods within those years, beginning after December 15, 2012. Section 107 of the JOBS Act provides that an emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act of 1933, as amended, for complying with new or revised accounting standards. As such, the Partnership can delay the adoption of certain accounting standards until these standards would otherwise apply to private companies. The Partnership has elected to delay such adoption of new or revised accounting standards, and as a result, the Partnership will not adopt ASU 2013-02 until interim periods in 2014 as required by nonpublic entities.

ORGANIZATION_AND_SUMMARY_OF_SI1

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Schedule of Common, Subordinate, and General Partner Units	'
	At the consummation of the IPO, the amount of common, subordinated, and general partner units is summarized in the table below:
		Number of units at	Limited Partner
		31-Jul-13	Interest
	Publicly held common units	6,875,000	38.60%
	Common units held by NuDevco	1,849,545	10.40%
	Subordinated units held by NuDevco	8,724,545	49.00%
	General partner units	356,104	2.00%
	Total	17,805,194	100.00%

PARTNERSHIP_EQUITY_AND_DISTRIB1

PARTNERSHIP EQUITY AND DISTRIBUTIONS (Tables)	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Schedule of Cash Distributions to Unitholders	'
	The Partnership declared the following cash distributions to its unitholders of record for the periods presented
	In Thousands, except per-unit amounts		Total Quarterly		Total		Date of
	Quarter ended:		Distribution per Unit		Distribution		Distribution
	December 31, 2013		$	0.35	$	6,341	3-Feb-14
	September 30, 2013	-1	$	0.23	$	4,167	4-Nov-13
	30-Jun-13	-2	—		—		—
	(1) This distribution represents a prorated amount of the full minimum quarterly distribution of $0.35 per unit for each whole quarter based on the number of days between the closing of the Partnership's IPO on July 31, 2013 and September 30, 2013.
	(2) No distributions were declared for the quarter ended June 30, 2013. This quarter was included in the results reported in the report on Form 10-Q for the second quarter ended June 30, 2013; however, this quarter was prior to the completion of the IPO.

NET_INCOME_PER_UNIT_Tables

NET INCOME PER UNIT (Tables)	12 Months Ended
	Dec. 31, 2013
NET INCOME PER UNIT [Abstract]	'
Schedule of Net Income per Unit	'
	The following table illustrates the Partnership’s calculation of net income per unit for common and subordinated partner units
	In Thousands, except per unit data
	Net income (post-IPO, August 1, 2013 to December 31, 2013)	$	7,190
	Less: general partner interest in net income	(144		)
	Limited partner interest in net income	$	7,046
	Net income allocable to common units	$	3,523
	Net income allocable to subordinated units	3,523
	Limited partner interest in net income	$	7,046
	Net income per limited partner common unit - basic	$	0.4
	Net income per limited subordinated unit - basic	$	0.4
	Net income per limited partner unit - basic	$	0.4
	Net income per limited partner common unit - diluted	$	0.39
	Net income per limited subordinated unit - diluted	$	0.4
	Net income per limited partner unit - diluted	$	0.4
	Weighted average limited partner units outstanding - basic
	Common units	8,724,545
	Subordinated units	8,724,545
	Total	17,449,090
	Weighted average limited partner units outstanding - diluted
	Common units	9,036,545
	Subordinated units	8,724,545
	Total	17,761,090

PROPERTY_PLANT_AND_EQUIPMENT_T

PROPERTY, PLANT AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Schedule of property, plant and equipment	'
	Net property, plant and equipment are composed of the following:
	In Thousands	Estimated Useful	December 31,			December 31,
		Lives (Years)	2013			2012
	Gas processing plants (1)	5 – 40	$	133,859		$	132,690
	Gathering pipelines and related equipment	5 – 40	47,728			36,853
	Land and rights of way	—	11,043			8,197
	Construction-in-progress	—	2,594			12,557
	Information technology and other	2 – 10	1,548			2,396
	Office building	15	306			306
	Autos	5	357			296
	Total		197,435			193,295
	Accumulated depreciation		(34,887		)	(28,156		)
	Property, plant and equipment, net		$	162,548		$	165,139
	-1	Includes inlet and residue pipelines and connections.

LONGTERM_DEBT_AND_INTEREST_EXP1

LONG-TERM DEBT AND INTEREST EXPENSE (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of Long-term Debt Instruments	'
	Long-term debt consists of the following:
	In Thousands		31-Dec-13			31-Dec-12
	Term loan		$	—		$	125,000
	Revolving credit facility		4,000			1,500
	Total debt		4,000			126,500
	Less: current maturities		—			6,250
	Total long-term debt		$	4,000		$	120,250
Schedule of Reconciliation Of Interest Expense	'
	A reconciliation of total interest expense to “interest expense, net of amounts capitalized” as reported in the consolidated and combined Statements of Operations for the years ended December 31, 2013 and 2012 is as follows:
	In Thousands	Years Ended December 31,
		2013			2012			2011
	Interest expense on long-term debt	$	3,312		$	4,599		$	4,545
	Interest expense from amortization of deferred financing costs	508			365			367
	Interest expense from write-off of unamortized deferred financing costs	761			177			—
	Less interest expense capitalized	(232		)	(214		)	(1,179		)
	Total interest expense, net of amounts capitalized	$	4,349		$	4,927		$	3,733

DERIVATIVE_FINANCIAL_INSTRUMEN1

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Assets and Liabilities, by Balance Sheet Location	'
	The following table presents the fair value of the Partnership’s derivative assets and liabilities including amounts for designated and undesignated hedge activities:
	In Thousands
	Description of Derivatives	Balance Sheet Location	December 31, 2013						December 31, 2012
			Assets			Liabilities			Assets			Liabilities
	Undesignated interest rate swap contract	Other assets	$	—		$	—		$	15		$	—
	Undesignated interest rate swap contract	Fair value of derivative	$	—		$	—		$	—		$	(72	)
		liabilities
	Total		$	—		$	—		$	15		$	(72	)
Gain (Loss) on Derivative Assets and Liabilities, by Location in Statement of Operations	'
	The following table presents the net realized and unrealized gains (losses) recognized in net income for derivative instruments not designated as hedging instruments:
	In Thousands
	Description of Derivatives	Statement of Operations	Years Ended December 31,
		Location
			2013			2012			2011
	Natural gas option contracts	Cost of revenues—affiliates	$	—		$	(87	)	$	(496	)
	Interest rate swap contracts	Gain (loss) on interest rate swap	$	(48	)	$	(851	)	$	(2,176	)
	Total loss recognized in income		$	(48	)	$	(938	)	$	(2,672	)
Cash Flow Hedging Derivatives, Accumulated Other Comprehensive Income (Loss) Activity	'
	The following table presents the gain for NGL forward contracts designated and accounted for as cash flow hedges, as recognized in other comprehensive income and cost of revenues—affiliates:
	In Thousands
	Description of Derivatives	Location	Years Ended December 31,
			2013			2012			2011
	Gain recognized in accumulated other comprehensive income		$	—		$	689		$	122
		Accumulated other
		comprehensive income
	Gain reclassified from accumulated other comprehensive income to income	Cost of revenues—affiliates	$	—		$	(752	)	$	(59	)

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
		Level 1		Level 2			Level 3		Total
	In Thousands
	31-Dec-13
	Interest rate swap liability—current	$	—	$	—		$	—	$	—
	Interest rate swap asset—long-term	$	—	$	—		$	—	$	—
	31-Dec-12
	Interest rate swap liability—current	$	—	$	(72	)	$	—	$	(72	)
	Interest rate swap asset—long-term	$	—	$	15		$	—	$	15

SEGMENT_INFORMATION_Tables

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment	'
	The following tables present financial information by segment for the year ended December 31, 2013. Our crude oil logistics segment had no material assets, liabilities, or operations for the years ended December 31, 2012 and 2011, respectively.
	Year ended December 31, 2013
		Midstream		Crude Oil		Corporate and			Marlin Midstream
	In Thousands	Natural Gas		Logistics		Consolidation			Partners, LP
	Total Revenues	$	47,052	$	5,808	$	—		$	52,860
	Cost of revenues	13,999		—		—			13,999
	Operation and maintenance	14,424		613		854			15,891
	General and administrative	—		—		7,886			7,886
	Other operating expenses	9,390		23		—			9,413
	Total operating expenses	37,813		636		8,740			47,189
	Operating income	9,239		5,172		(8,740		)	5,671
	Interest expense, net of amounts capitalized	—		—		(4,349		)	(4,349		)
	Loss on interest rate swap	—		—		(48		)	(48		)
	Net income (loss) before tax	9,239		5,172		(13,137		)	1,274
	Texas margin tax expense	—		—		88			88
	Net income	$	9,239	$	5,172	$	(13,225	)	$	1,186
	Balance sheet at December 31, 2013
	In Thousands	Midstream		Crude Oil		Corporate and			Marlin Midstream
		Natural Gas		Logistics		Consolidation			Partners, LP
	Assets:
	Current Assets	$	5,727	$	1,195	$	3,772		$	10,694
	Property, Plant and Equipment, Net	162,029		519		—			162,548
	Other Assets	163		—		737			900
	Total Assets	$	167,919	$	1,714	$	4,509		$	174,142
	Liabilities and Partners' Capital
	Total current liabilities	$	2,796	$	353	$	6,077		$	9,226
	Total long-term liabilities	—		—		4,366			4,366
	Total liabilities	2,796		353		10,443			13,592
	Partners' Capital	165,123		1,361		(5,934		)	160,550
	Total liabilities and Partners' Capital	$	167,919	$	1,714	$	4,509		$	174,142

EQUITY_BASED_COMPENSATION_Tabl

EQUITY BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award	'
	A summary of the phantom units activity for the year ended December 31, 2013 is presented below:
		Number of shares	Weighted Average Grant-Date Fair Value
	Total Non-vested at January 1, 2013	—	$	—
	Granted	312,000	20
	Exercised	—	—
	Forfeited or canceled	—	—
	Total Outstanding at December 31, 2013	312,000	$	20

SUPPLEMENTAL_QUARTERLY_FINANCI1

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information	'
	Summarized quarterly financial data for the year ended December 31, 2013 is as follows:
		For the year ending December 31, 2013
	in thousands except volume and per unit amounts	Q1			Q2			Q3			Q4			TOTAL
	Revenues	$	7,504		$	10,298		$	18,950		$	16,108		$	52,860
	Cost of revenues	2,528			2,680			6,479			2,312			13,999
	Gross margin	4,976			7,618			12,471			13,796			38,861
	Operating expenses	3,896			3,700			4,283			4,012			15,891
	G&A expenses	1,411			1,321			2,482			2,672			7,886
	Other operating expenses	2,219			2,369			2,349			2,476			9,413
	Operating income	(2,550		)	228			3,357			4,636			5,671
	Other income(expense)	(1,374		)	(1,421		)	(1,424		)	(178		)	(4,397		)
	Net income before Texas margin tax	$	(3,924	)	$	(1,193	)	$	1,933		$	4,458		$	1,274
	Net income per limited partner unit - basic year-to-date							$	0.16		$	0.4
	Net income per limited partner unit - diluted year-to-date							$	0.15		$	0.39
	Weighted average limited partner units outstanding - basic							17,449,090			17,449,090
	Weighted average limited partner units outstanding - diluted							17,761,090			17,761,090
Adjusted quarterly EBITDA	'
	Adjusted quarterly EBITDA for the year ended December 31, 2013 is as follows:
		Q1		Q2		Q3		Q4		Total
	Net income (loss)	(3,935	)	(1,206	)	1,922		4,405		1,186
	Interest expense, net of amounts capitalized	1,363		1,426		1,382		178		4,349
	Texas margin tax expense	11		13		11		53		88
	Equity-based compensation	—		—		1,284		1,728		3,012
	Loss on interest rate swap	10		(5	)	43		—		48
	Depreciation expense	1,984		2,050		2,058		2,105		8,197
	Adjusted EBITDA	(567	)	2,278		6,700		8,469		16,880

ORGANIZATION_AND_SUMMARY_OF_SI2

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Schedule of Common, Subordinate, and General Partner Units (Details)	0 Months Ended	12 Months Ended
	Jul. 31, 2013	Dec. 31, 2013
Limited Partners' Capital Account [Line Items]	'	'
Limited partner's, Ownership percentage	'	2.00%
General partner units	356,104	356,104
General partner ownership interest	2.00%	100.00%
Partners' Capital Account, Units	17,805,194	'
Total Ownership Percentage	100.00%	'
Common Units	'	'
Limited Partners' Capital Account [Line Items]	'	'
Limited partner's capital, units outstanding	'	8,724,545
Limited partner's, Ownership percentage	'	10.40%
Common Units | Publicly Held Units	'	'
Limited Partners' Capital Account [Line Items]	'	'
Limited partner's capital, units outstanding	6,875,000	'
Limited partner's, Ownership percentage	38.60%	'
Common Units | Units Held By NuDevco	'	'
Limited Partners' Capital Account [Line Items]	'	'
Limited partner's capital, units outstanding	1,849,545	'
Limited partner's, Ownership percentage	10.40%	'
Subordinate Units	'	'
Limited Partners' Capital Account [Line Items]	'	'
Limited partner's capital, units outstanding	'	8,724,545
Subordinated units held by NuDevco	8,724,545	'
Subordinted untis held by NuDevco, Percentage of ownership	49.00%	49.00%

ORGANIZATION_AND_SUMMARY_OF_SI3

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Schedule of Fee-Based Commercial Agreements (Details)	0 Months Ended
	Jul. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Supply Commitment, Term	'3 years

ORGANIZATION_AND_SUMMARY_OF_SI4

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Textual-Initial Public Offering (Details) (USD $)	0 Months Ended	12 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 31, 2013	Dec. 31, 2013
Line of Credit Facility [Line Items]	'	'
Limited partner's, Ownership percentage	'	2.00%
Common units sold in IPO, price per unit	$20	'
Underwritting discount per share	$1.20	'
General partner ownership interest	2.00%	100.00%
Percentage of quarterly distributions of available cash from operating surplus for distributions	23.00%	'
Quarterly distribution of available cash from operating surplus by common units during subordination period	$0.35	'
Net proceeds from sale of units	$125.30	'
Repayment of credit facility	131.9	'
Payment of unsued commitment fees and interest rate swap liability	0.1	'
Common Units	'	'
Line of Credit Facility [Line Items]	'	'
Limited partner's, Ownership percentage	'	10.40%
Term Loan	'	'
Line of Credit Facility [Line Items]	'	'
Repayment of credit facility	121.9	'
Revolving Credit Facility	'	'
Line of Credit Facility [Line Items]	'	'
Repayment of credit facility	$10	'
Publicly Held Units | Common Units	'	'
Line of Credit Facility [Line Items]	'	'
Common units sold in IPO	6,875,000	'
Limited partner's, Ownership percentage	38.60%	'
Minimum	'	'
Line of Credit Facility [Line Items]	'	'
Percentage of quarterly distributions of available cash from operating surplus for distributions	13.00%	'
Maximum	'	'
Line of Credit Facility [Line Items]	'	'
Percentage of quarterly distributions of available cash from operating surplus for distributions	48.00%	'

ORGANIZATION_AND_SUMMARY_OF_SI5

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Textual-Credit Facility (Details) (USD $)

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2012

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Minimum

Maximum

Eurodollar

Eurodollar

Alternate Base Rate

Alternate Base Rate

Alternate Base Rate - Federal Funds Rate

Alternate Base Rate - Federal Funds Rate

Alternate Base Rate - Eurodollar Rate

Alternate Base Rate - Eurodollar Rate

Revolving Credit Facility

Revolving Credit Facility

Minimum

Maximum

Minimum

Maximum

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

$50,000,000

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity, in case of non-default

'

150,000,000

'

'

'

'

'

'

'

'

'

'

'

Amount outstanding

$4,000,000

$25,000,000

$1,500,000

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

3.00%

3.75%

2.00%

2.75%

0.50%

0.50%

1.00%

1.00%

Line of credit facility, covenant, senior secured leverage ratio

'

'

'

'

4

'

'

'

'

'

'

'

'

Line of credit facility, covenant, interest coverage ratio

'

'

'

2.5

'

'

'

'

'

'

'

'

'

ORGANIZATION_AND_SUMMARY_OF_SI6

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Textual-Other Transactions (Details) (USD $)	0 Months Ended	12 Months Ended		0 Months Ended	12 Months Ended		0 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Jul. 31, 2013	Jul. 31, 2013	Jul. 31, 2013
			Common Units	Subordinate Units	Subordinate Units	Units Held By NuDevco	Release of Accounts Payable Obligation	Release of Accounts Payable Obligation	Processing Facility
						Common Units			Monell, Wyoming
									Collaborative Arrangement
Limited Partners' Capital Account [Line Items]	'	'	'	'	'	'	'	'	'
General partner ownership interest	2.00%	100.00%	'	'	'	'	'	'	'
Limited partner's capital, units outstanding	'	'	8,724,545	'	8,724,545	1,849,545	'	'	'
Subordinated units held by NuDevco	'	'	'	8,724,545	'	'	'	'	'
Subordinted untis held by NuDevco, Percentage of ownership	'	'	'	49.00%	49.00%	'	'	'	'
Investment in Joint Venture, Interest Percentage	'	'	'	'	'	'	'	'	50.00%
Amounts of related party transaction	'	'	'	'	'	'	$11.70	$11.70	'

BASIS_OF_PRESENTATION_Textual_

BASIS OF PRESENTATION Textual (Details) (USD $)	12 Months Ended							0 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Jul. 31, 2013
	segment			Management Services	Minimum	Maximum	Long Term Incentive Plan	Employee of related party	Board members
				Principal Owner			Phantom Share Units (PSUs)	Long Term Incentive Plan	Long Term Incentive Plan
								Phantom Share Units (PSUs)	Phantom Share Units (PSUs)
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'
Amount of annual fee for executive management services	'	'	'	$600,000	'	'	'	'	'
Property, plant and equipment, Estimated useful lives	'	'	'	'	'5 years	'40 years	'	'	'
Capitalized interest	232,000	214,000	1,179,000	'	'	'	'	'	'
Property, plant and equipment, scheduled maintenance frequency	'5 years	'	'	'	'	'	'	'	'
Number of operating segments	2	'	'	'	'	'	'	'	'
Imbalance receivables	$100,000	$200,000	'	'	'	'	'	'	'
Units awarded (in shares)	'	'	'	'	'	'	312,000	292,000	20,000

PARTNERSHIP_EQUITY_AND_DISTRIB2

PARTNERSHIP EQUITY AND DISTRIBUTIONS Textual (Details) (USD $)	0 Months Ended	3 Months Ended	12 Months Ended
	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
		Quarter	Quarter
		Period	Period
Limited Partners' Capital Account [Line Items]	'	'	'
Limited partner's, Ownership percentage	'	'	2.00%
Common units sold in IPO, price per unit	$20	'	'
Underwritting discount per share	$1.20	'	'
General partner units	356,104	356,104	356,104
General partner ownership interest	2.00%	'	100.00%
Maximum number of days after quarter-end to distribute all available cash to unitholders	'	'45 days	'
Annualized Minimum Quarterly Distribution	'	'	$1.40
Number of consecutive, non-overlapping four-quarter periods for subordination period test	'	3	3
Number of quarters per consecutive, non-overlapping period for subordination period test	'	4	4
Common Units	'	'	'
Limited Partners' Capital Account [Line Items]	'	'	'
Limited partner's, Ownership percentage	'	'	10.40%
Limited partner's capital, units outstanding	'	8,724,545	8,724,545
Subordinate Units	'	'	'
Limited Partners' Capital Account [Line Items]	'	'	'
Limited partner's capital, units outstanding	'	8,724,545	8,724,545
Subordinated units held by NuDevco	8,724,545	'	'
Subordinted untis held by NuDevco, Percentage of ownership	49.00%	'	49.00%
Publicly Held Units | Common Units	'	'	'
Limited Partners' Capital Account [Line Items]	'	'	'
Common units sold in IPO	6,875,000	'	'
Limited partner's, Ownership percentage	38.60%	'	'
Limited partner's capital, units outstanding	6,875,000	'	'
Units Held By NuDevco | Common Units	'	'	'
Limited Partners' Capital Account [Line Items]	'	'	'
Limited partner's, Ownership percentage	10.40%	'	'
Limited partner's capital, units outstanding	1,849,545	'	'

PARTNERSHIP_EQUITY_AND_DISTRIB3

PARTNERSHIP EQUITY AND DISTRIBUTIONS Schedule of Cash Distributions to Unitholders (Details) (USD $)	2 Months Ended	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013
Equity [Abstract]	'	'	'	'
Quarterly distribution per unit	$0.35	$0.35	$0.23	$0
Distribution Made to Unitholders, Cash Distributions Declared	'	$6,341	$4,167	$0
Distribution Made to Unitholders, Distribution Date	'	3-Feb-14	4-Nov-13	'

NET_INCOME_PER_UNIT_Schedule_o

NET INCOME PER UNIT Schedule of net income per Limited Partner Unit (Details) (USD $)	3 Months Ended				5 Months Ended	7 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income (loss)	$4,405	$1,922	($1,206)	($3,935)	$7,190	($6,003)	$1,186	($4,306)	$8,541
Less: general partner interest in net income	'	'	'	'	-144	'	'	'	'
Limited partner interest in net income	'	'	'	'	7,046	'	7,046	'	'
Net income per limited partner unit - basic (in dollars per share)	$0.40	$0.16	'	'	'	'	$0.40	'	'
Net income per limited partner unit - diluted (in dollars per share)	$0.39	$0.15	'	'	'	'	$0.40	'	'
Weighted average limited partner units outstanding - basic	17,449,090	17,449,090	'	'	'	'	17,449,090	'	'
Weighted average limited partner units outstanding - diluted	17,761,090	17,761,090	'	'	'	'	17,761,090	'	'
Common Units	'	'	'	'	'	'	'	'	'
Limited partner interest in net income	'	'	'	'	'	'	3,523	'	'
Net income per limited partner unit - basic (in dollars per share)	'	'	'	'	'	'	$0.40	'	'
Net income per limited partner unit - diluted (in dollars per share)	'	'	'	'	'	'	$0.39	'	'
Weighted average limited partner units outstanding - basic	'	'	'	'	'	'	8,724,545	'	'
Weighted average limited partner units outstanding - diluted	'	'	'	'	'	'	9,036,545	'	'
Subordinate Units	'	'	'	'	'	'	'	'	'
Limited partner interest in net income	'	'	'	'	'	'	$3,523	'	'
Net income per limited partner unit - basic (in dollars per share)	'	'	'	'	'	'	$0.40	'	'
Net income per limited partner unit - diluted (in dollars per share)	'	'	'	'	'	'	$0.40	'	'
Weighted average limited partner units outstanding - basic	'	'	'	'	'	'	8,724,545	'	'
Weighted average limited partner units outstanding - diluted	'	'	'	'	'	'	8,724,545	'	'

PROPERTY_PLANT_AND_EQUIPMENT_S

PROPERTY, PLANT AND EQUIPMENT Schedule of property, plant and equipment (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	$197,435		$193,295
Accumulated depreciation	-34,887		-28,156
Property, plant and equipment, net	162,548		165,139
Minimum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'5 years		'
Maximum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'40 years		'
Gas processing plants	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	133,859	[1]	132,690	[1]
Gas processing plants | Minimum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'5 years	[1]	'
Gas processing plants | Maximum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'40 years	[1]	'
Gathering pipelines and related equipment	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	47,728		36,853
Gathering pipelines and related equipment | Minimum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'5 years		'
Gathering pipelines and related equipment | Maximum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'40 years		'
Land and rights of way	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	11,043		8,197
Construction-in-progress	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	2,594		12,557
Information technology and other	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	1,548		2,396
Information technology and other | Minimum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'2 years		'
Information technology and other | Maximum	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, Estimated useful lives	'10 years		'
Office building	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	306		306
Property, plant and equipment, Estimated useful lives	'15 years		'
Autos	'		'
Property, Plant and Equipment [Line Items]	'		'
Property, plant and equipment, gross	$357		$296
Property, plant and equipment, Estimated useful lives	'5 years		'
[1]	Includes inlet and residue pipelines and connections.

PROPERTY_PLANT_AND_EQUIPMENT_T1

PROPERTY, PLANT AND EQUIPMENT Textual (Details) (USD $)

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jul. 31, 2013

Natural gas and liquid transportation pipelines

Panola County, Texas

Panola County, Texas

Tyler County, Texas

Collaborative Arrangement

Collaborative Arrangement

Collaborative Arrangement

Collaborative Arrangement

Affiliated Entity

facility

Natural gas processing

Natural gas gathering

Natural gas processing

Monell, Wyoming

Monell, Wyoming

Monell, Wyoming

Monell, Wyoming

Collaborative Arrangement

facility

facility

facility

Processing Facility

Processing Facility

Processing Facility

Processing Facility

Monell, Wyoming

Processing Facility

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of facilities

'

'

'

'

'

'

'

2

2

2

1

'

'

'

'

'

Percentage interest in processing facility

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

Natural gas, NGLs and condensate revenue

'

'

'

'

$15,792,000

$34,708,000

$55,558,000

'

'

'

'

'

$200,000

$1,200,000

$1,600,000

'

Operation and maintenance

4,012,000

4,283,000

3,700,000

3,896,000

15,891,000

'

'

'

'

'

'

'

300,000

400,000

400,000

'

Property, plant and equipment, net

162,548,000

'

'

'

162,548,000

165,139,000

'

'

'

'

'

'

'

3,500,000

'

'

Property, plant and equipment transferred out

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3,200,000

Depreciation expense

$2,105,000

$2,058,000

$2,050,000

$1,984,000

$8,197,000

$7,689,000

$5,365,000

'

'

'

'

'

'

'

'

'

LONGTERM_DEBT_AND_INTEREST_EXP2

LONG-TERM DEBT AND INTEREST EXPENSE Long-term Debt (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
Total Debt	$4,000	$126,500
Less: current maturities	0	6,250
Total long-term debt	4,000	120,250
Term Loan	'	'
Debt Instrument [Line Items]	'	'
Total Debt	0	125,000
Revolving Credit Facility	'	'
Debt Instrument [Line Items]	'	'
Total Debt	$4,000	$1,500

LONGTERM_DEBT_AND_INTEREST_EXP3

LONG-TERM DEBT AND INTEREST EXPENSE Interest Expense (Details) (USD $)	3 Months Ended				12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Debt Disclosure [Abstract]	'	'	'	'	'	'	'
Interest expense on long-term debt	'	'	'	'	$3,312	$4,599	$4,545
Interest expense from amortization of deferred financing costs	'	'	'	'	508	365	367
Interest expense from write-off of unamortized deferred financing costs	'	'	'	'	761	177	0
Less interest expense capitalized	'	'	'	'	-232	-214	-1,179
Total interest expense, net of amounts capitalized	$178	$1,382	$1,426	$1,363	$4,349	$4,927	$3,733

LONGTERM_DEBT_AND_INTEREST_EXP4

LONG-TERM DEBT AND INTEREST EXPENSE Textual (Details) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

30-May-08

30-May-08

30-May-08

Jul. 31, 2013

Jan. 24, 2011

Dec. 31, 2011

Jan. 24, 2011

Dec. 31, 2012

Dec. 31, 2012

Dec. 17, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 17, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 17, 2012

Jul. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Alternate Base Rate - Federal Funds Rate

Alternate Base Rate - Eurodollar Rate

Term Loan

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

Interest Expense

Amended Credit Agreement

Amended Credit Agreement

Amended Credit Agreement

Fifth Amended Credit Agreement

Fifth Amended Credit Agreement

Fifth Amended Credit Agreement

Fifth Amended Credit Agreement

Fifth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Sixth Amended Credit Agreement

Eurodollar

Eurodollar

Alternate Base Rate

Alternate Base Rate

Alternate Base Rate - Federal Funds Rate

Alternate Base Rate - Eurodollar Rate

Working Capital Facility

Term Loan

Revolving Credit Facility

Working Capital Facility

Term Loan

Term Loan

Interest Expense

Working Capital Facility

Term Loan

Term Loan

Term Loan

Term Loan

Term Loan

Term Loan

Term Loan

Revolving Credit Facility

Interest Expense

Interest Expense

General and Administrative Expense

Minimum

Maximum

Minimum

Maximum

Eurodollar

Eurodollar

Base Rate

Base Rate

Minimum

Maximum

Minimum

Maximum

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

'

'

'

'

$50,000,000

'

'

'

'

'

'

'

'

'

$177,500,000

$100,000,000

$35,000,000

'

$150,000,000

$130,000,000

$130,000,000

'

'

$70,000,000

'

'

$125,000,000

'

'

'

'

$30,000,000

'

'

'

Proceeds from the term loan and the revolving credit facility

'

4,000,000

126,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, quarterly principal payments till maturity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

'

'

'

'

'

'

'

'

'

'

Credit facility, balance due on maturity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

112,500,000

'

'

'

'

'

'

'

'

'

'

Interest rate at period end

'

'

'

'

'

'

'

'

'

3.96%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.96%

'

'

'

'

'

'

'

'

'

Amount outstanding

'

'

'

'

'

'

'

25,000,000

4,000,000

1,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

125,000,000

'

'

'

'

'

'

'

'

'

Unused capacity, commitment fee percentage

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity, in case of non-default

'

'

'

'

'

'

'

150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

0.50%

1.00%

'

'

'

'

3.00%

3.75%

2.00%

2.75%

0.50%

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.50%

4.25%

2.50%

3.25%

'

'

'

'

Repayment of credit facility

131,900,000

'

'

'

'

'

121,900,000

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt

'

4,000,000

120,250,000

'

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs

'

1,000,000

1,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs included in current assets

'

300,000

700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs included in other assets

'

700,000

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of deferred financing costs

'

1,269,000

542,000

367,000

'

'

'

'

'

'

'

'

'

'

'

'

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

'

Financing costs paid

'

1,141,000

932,000

1,094,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,100,000

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized finance costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

900,000

'

'

'

'

'

'

'

'

'

'

'

'

Financing costs expensed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$200,000

'

'

'

'

'

'

'

'

'

'

$800,000

'

$100,000

DERIVATIVE_FINANCIAL_INSTRUMEN2

DERIVATIVE FINANCIAL INSTRUMENTS Derivative Assets and Liabilities, by Balance Sheet Location (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivative Assets	'	'
Derivative asset, fair value	$0	$15
Derivative Liabilities	'	'
Derivative liability, fair value	0	-72
Interest rate contract | Swap contract | Undesignated hedging instrument | Other assets	'	'
Derivative Assets	'	'
Derivative asset, gross asset	0	15
Derivative Liabilities	'	'
Derivative liability, gross asset	0	0
Interest rate contract | Swap contract | Undesignated hedging instrument | Fair value of derivative liabilities	'	'
Derivative Assets	'	'
Derivative asset, gross liability	0	0
Derivative Liabilities	'	'
Derivative liability, gross liability	$0	($72)

DERIVATIVE_FINANCIAL_INSTRUMEN3

DERIVATIVE FINANCIAL INSTRUMENTS Gain (Loss) on Derivative Assets and Liabilities, by Location in Statement of Operations (Details) (Not designated as hedging, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (loss) on derivatives	($48)	($938)	($2,672)
Option contract | Naturgal gas contract | Cost of revenues - affiliates	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (loss) on derivatives	0	-87	-496
Swap contract | Interest rate contract | Gain (loss) on interest rate swap	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain (loss) on derivatives	($48)	($851)	($2,176)

DERIVATIVE_FINANCIAL_INSTRUMEN4

DERIVATIVE FINANCIAL INSTRUMENTS Cash Flow Hedging Derivatives, Accumulated Other Comprehensive Income (Loss) Activity (Details) (Natural gas liquid contract, Forward contracts, Designated as hedging instrument, Cash flow hedge, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cost of revenues - affiliates	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain reclassified from accumulated other comprehensive income to income	$0	($752)	($59)
Accumulated other comprehensive income	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Gain recognized in accumulated other comprehensive income	$0	$689	$122

DERIVATIVE_FINANCIAL_INSTRUMEN5

DERIVATIVE FINANCIAL INSTRUMENTS Textual (Details) (Interest rate contract, Swap contract, Not designated as hedging, USD $)	1 Months Ended	12 Months Ended
	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
		instrument	instrument
Interest rate contract | Swap contract | Not designated as hedging	'	'	'	'
Derivative [Line Items]	'	'	'	'
Notional amount of derivative	'	'	$62,500,000	$100,000,000
Settlement of terminated derivative instruments	100,000	'	'	'
Deferred gains or losses remaining in AOCI	'	$0	$0	'
Number of open derivative instruments	'	0	0	'

FAIR_VALUE_OF_FINANCIAL_INSTRU2

FAIR VALUE OF FINANCIAL INSTRUMENTS Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis (Details) (Fair Value, Measurements, Recurring, USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current Liabiities	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Interest rate swap liability	$0	($72)
Current Liabiities | Level 2	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Interest rate swap liability	0	-72
Long Term Assets	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Interest rate swap asset	0	15
Long Term Assets | Level 2	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Interest rate swap asset	$0	$15

SEGMENT_INFORMATION_Details

SEGMENT INFORMATION (Details) (USD $)	3 Months Ended				5 Months Ended	7 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
							segment
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Number of operating segments	'	'	'	'	'	'	2	'	'
Total Revenues	$16,108	$18,950	$10,298	$7,504	'	'	$52,860	$51,049	$65,818
Cost of revenues	'	'	'	'	'	'	13,999	'	'
Operation and maintenance	4,012	4,283	3,700	3,896	'	'	15,891	'	'
General and administrative	2,672	2,482	1,321	1,411	'	'	7,886	'	'
Other operating expenses	2,476	2,349	2,369	2,219	'	'	9,413	'	'
Total operating expenses	'	'	'	'	'	'	47,189	49,499	51,453
Operating income	4,636	3,357	228	-2,550	'	'	5,671	1,550	14,365
Interest expense, net of amounts capitalized	-178	-1,382	-1,426	-1,363	'	'	-4,349	-4,927	-3,733
Loss on interest rate swap	'	'	'	'	'	'	-48	-851	-2,176
Net income (loss) before tax	4,458	1,933	-1,193	-3,924	'	'	1,274	-4,205	8,476
Texas margin tax expense	53	11	13	11	'	'	88	101	-65
Net income (loss)	4,405	1,922	-1,206	-3,935	7,190	-6,003	1,186	-4,306	8,541
Assets:	'	'	'	'	'	'	'	'	'
Current Assets	10,694	'	'	'	10,694	'	10,694	13,598	'
Property, Plant and Equipment, Net	162,548	'	'	'	162,548	'	162,548	165,139	'
Other Assets	900	'	'	'	900	'	900	2,059	'
TOTAL ASSETS	174,142	'	'	'	174,142	'	174,142	180,796	'
Liabilities and Partners' Capital	'	'	'	'	'	'	'	'	'
Total current liabilities	9,226	'	'	'	9,226	'	9,226	13,575	'
Total long-term liabilities	4,366	'	'	'	4,366	'	4,366	'	'
Total liabilities	13,592	'	'	'	13,592	'	13,592	148,517	'
Partners' Capital	160,550	'	'	'	160,550	'	160,550	'	'
TOTAL LIABILITIES AND PARTNERS' CAPITAL AND MEMBER'S EQUITY	174,142	'	'	'	174,142	'	174,142	180,796	'
Midstream Natural Gas	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Total Revenues	'	'	'	'	'	'	47,052	'	'
Cost of revenues	'	'	'	'	'	'	13,999	'	'
Operation and maintenance	'	'	'	'	'	'	14,424	'	'
General and administrative	'	'	'	'	'	'	0	'	'
Other operating expenses	'	'	'	'	'	'	9,390	'	'
Total operating expenses	'	'	'	'	'	'	37,813	'	'
Operating income	'	'	'	'	'	'	9,239	'	'
Interest expense, net of amounts capitalized	'	'	'	'	'	'	0	'	'
Loss on interest rate swap	'	'	'	'	'	'	0	'	'
Net income (loss) before tax	'	'	'	'	'	'	9,239	'	'
Texas margin tax expense	'	'	'	'	'	'	0	'	'
Net income (loss)	'	'	'	'	'	'	9,239	'	'
Assets:	'	'	'	'	'	'	'	'	'
Current Assets	5,727	'	'	'	5,727	'	5,727	'	'
Property, Plant and Equipment, Net	162,029	'	'	'	162,029	'	162,029	'	'
Other Assets	163	'	'	'	163	'	163	'	'
TOTAL ASSETS	167,919	'	'	'	167,919	'	167,919	'	'
Liabilities and Partners' Capital	'	'	'	'	'	'	'	'	'
Total current liabilities	2,796	'	'	'	2,796	'	2,796	'	'
Total long-term liabilities	0	'	'	'	0	'	0	'	'
Total liabilities	2,796	'	'	'	2,796	'	2,796	'	'
Partners' Capital	165,123	'	'	'	165,123	'	165,123	'	'
TOTAL LIABILITIES AND PARTNERS' CAPITAL AND MEMBER'S EQUITY	167,919	'	'	'	167,919	'	167,919	'	'
Crude Oil Logistics	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Total Revenues	'	'	'	'	'	'	5,808	'	'
Cost of revenues	'	'	'	'	'	'	0	'	'
Operation and maintenance	'	'	'	'	'	'	613	'	'
General and administrative	'	'	'	'	'	'	0	'	'
Other operating expenses	'	'	'	'	'	'	23	'	'
Total operating expenses	'	'	'	'	'	'	636	'	'
Operating income	'	'	'	'	'	'	5,172	'	'
Interest expense, net of amounts capitalized	'	'	'	'	'	'	0	'	'
Loss on interest rate swap	'	'	'	'	'	'	0	'	'
Net income (loss) before tax	'	'	'	'	'	'	5,172	'	'
Texas margin tax expense	'	'	'	'	'	'	0	'	'
Net income (loss)	'	'	'	'	'	'	5,172	'	'
Assets:	'	'	'	'	'	'	'	'	'
Current Assets	1,195	'	'	'	1,195	'	1,195	'	'
Property, Plant and Equipment, Net	519	'	'	'	519	'	519	'	'
Other Assets	0	'	'	'	0	'	0	'	'
TOTAL ASSETS	1,714	'	'	'	1,714	'	1,714	'	'
Liabilities and Partners' Capital	'	'	'	'	'	'	'	'	'
Total current liabilities	353	'	'	'	353	'	353	'	'
Total long-term liabilities	0	'	'	'	0	'	0	'	'
Total liabilities	353	'	'	'	353	'	353	'	'
Partners' Capital	1,361	'	'	'	1,361	'	1,361	'	'
TOTAL LIABILITIES AND PARTNERS' CAPITAL AND MEMBER'S EQUITY	1,714	'	'	'	1,714	'	1,714	'	'
Corporate and Consolidation	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'
Total Revenues	'	'	'	'	'	'	0	'	'
Cost of revenues	'	'	'	'	'	'	0	'	'
Operation and maintenance	'	'	'	'	'	'	854	'	'
General and administrative	'	'	'	'	'	'	7,886	'	'
Other operating expenses	'	'	'	'	'	'	0	'	'
Total operating expenses	'	'	'	'	'	'	8,740	'	'
Operating income	'	'	'	'	'	'	-8,740	'	'
Interest expense, net of amounts capitalized	'	'	'	'	'	'	-4,349	'	'
Loss on interest rate swap	'	'	'	'	'	'	-48	'	'
Net income (loss) before tax	'	'	'	'	'	'	-13,137	'	'
Net income (loss)	'	'	'	'	'	'	-13,225	'	'
Assets:	'	'	'	'	'	'	'	'	'
Current Assets	3,772	'	'	'	3,772	'	3,772	'	'
Property, Plant and Equipment, Net	0	'	'	'	0	'	0	'	'
Other Assets	737	'	'	'	737	'	737	'	'
TOTAL ASSETS	4,509	'	'	'	4,509	'	4,509	'	'
Liabilities and Partners' Capital	'	'	'	'	'	'	'	'	'
Total current liabilities	6,077	'	'	'	6,077	'	6,077	'	'
Total long-term liabilities	4,366	'	'	'	4,366	'	4,366	'	'
Total liabilities	10,443	'	'	'	10,443	'	10,443	'	'
Partners' Capital	-5,934	'	'	'	-5,934	'	-5,934	'	'
TOTAL LIABILITIES AND PARTNERS' CAPITAL AND MEMBER'S EQUITY	$4,509	'	'	'	$4,509	'	$4,509	'	'

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES Textual - Purchase Commitment (Details) (Capital Addition Purchase Commitments, USD $)	0 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jul. 31, 2013	Dec. 31, 2012
Capital Addition Purchase Commitments	'	'
Long-term Purchase Commitment [Line Items]	'	'
Railcars purchase commitment, amount	'	$12.60
Railcars purchase, deposit paid	$0.70	'

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES Textual - Supply Commitment (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Supply Commitment [Line Items]	'	'
Inventory delivery supply commitment, minimum reserved capacity cut-off for fee obligation, percentage	95.00%	'
Inventory delivery supply commitment, deficiency fee payable	$500,000	$0
Supply Commitment	'	'
Supply Commitment [Line Items]	'	'
Inventory delivery commitment, reserve capacity, per day	3,500	'
Maximum	'	'
Supply Commitment [Line Items]	'	'
Inventory delivery supply commitment, maximum fee obligation	$2,200,000	'

TRANSACTIONS_WITH_AFFILIATES_D

TRANSACTIONS WITH AFFILIATES (Details) (USD $)

0 Months Ended

5 Months Ended

7 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

Apr. 25, 2013

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2013

Apr. 26, 2013

Jul. 31, 2013

Jul. 31, 2013

Apr. 08, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jul. 31, 2013

Dec. 31, 2013

Oct. 25, 2013

Dec. 31, 2013

Sep. 30, 2012

Dec. 31, 2011

Jul. 31, 2013

Repayment of Accounts Payable

Release of Accounts Payable Obligation

Release of Accounts Payable Obligation

SEV

SEV

Principal Owner

Gas transportation agreement

Fee-based commercial agreement

Fee-based commercial agreement

Fee-based commercial agreement

Transloading services agreement

Transloading services agreement

Non-binding letter of intent

Maximum

Maximum

Maximum

Minimum

Purchase of Property Plant and Equipment

Management Services

SEV

SEV

SEV

Gas transportation agreement

Gas transportation agreement

Gas transportation agreement

Fee-based commercial agreement

MMcf

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts receivable—affiliates

'

$3,632,000

'

$3,632,000

$96,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payables and accrued liabilities to affiliates

'

1,600,000

'

1,600,000

18,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable—affiliates

'

0

'

0

14,692,000

'

11,700,000

'

'

'

14,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital contributions

3,000,000

'

3,574,000

'

4,374,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amounts of related party transaction

'

'

'

'

'

'

'

3,000,000

11,700,000

11,700,000

'

300,000

600,000

'

'

'

'

'

'

45,000,000

'

'

'

'

Cost of natural gas, NGLs and condensate revenue—affiliates

'

3,000,000

'

5,515,000

7,668,000

17,407,000

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

Extension Period of Current Transportation Agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

Gathering, processing, transloading and other revenue—affiliates

'

'

'

13,015,000

254,000

254,000

'

'

'

'

'

'

'

'

'

7,100,000

'

'

5,800,000

'

100,000

300,000

300,000

'

Length of period of related party agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'3 years

'

'

'

'

'

'

Monthly volume commitment in service agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

80

Operation and maintenance—affiliates

'

'

'

3,490,000

793,000

327,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General and administrative—affiliates

'

'

'

4,187,000

1,021,000

907,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earnest money deposits

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

'

'

'

'

Earnest money deposit refunded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,500,000

'

'

'

'

EQUITY_BASED_COMPENSATION_Deta

EQUITY BASED COMPENSATION (Details) (USD $)	12 Months Ended		12 Months Ended	0 Months Ended		3 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
		Long Term Incentive Plan	Long Term Incentive Plan	Employee of related party	Board members	General and Administrative Expense - Affiliate	Operation and Maintenance - Affiliates
			Phantom Share Units (PSUs)	Long Term Incentive Plan	Long Term Incentive Plan
			Installment	Phantom Share Units (PSUs)	Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'	'	'	'
Maximum number of common units issuable	'	1,750,000	'	'	'	'	'
Allocated share based compensation expense	$0	'	'	'	'	$2,100,000	$900,000
Number of annual vesting installment	'	'	5	'	'	'	'
Minimum years of service at grant date of award per vesting schedule	'	'	'5 years	'	'	'	'
Liability recorded for distributions associated with unvested grants	'	'	32,000	'	'	'	'
Number of Shares	'	'	'	'	'	'	'
Total Non-vested at January 1, 2013 (in shares)	'	'	0	'	'	'	'
Granted (in shares)	'	'	312,000	292,000	20,000	'	'
Exercised (in shares)	'	'	0	'	'	'	'
Forfeited or canceled (in shares)	'	'	0	'	'	'	'
Total Outstanding at December 31, 2013 (in shares)	'	'	312,000	'	'	'	'
Weighted Average Grant-Date Fair Value	'	'	'	'	'	'	'
Granted	'	'	$20	'	'	'	'
Total Outstanding at December 31, 2013	'	'	$20	'	'	'	'
Unrecognized compensation expense associated with the unvested phantom units	'	'	$2,200,000	'	'	'	'
Nonvested awards, compensation cost not yet recognized, period for recognition	'	'	'5 years	'	'	'	'

CONCENTRATIONS_OF_CREDIT_RISK_

CONCENTRATIONS OF CREDIT RISK (Details) (Customer Concentration Risk)	5 Months Ended	12 Months Ended	5 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012	Dec. 31, 2012
	Revenues	Revenues	One third-party customer and one affiliate customer	Two third-party customers	Two third-party customers	Two third-party customers	Two third-party customers
	Customer	Customer	Revenues	Revenues	Revenues	Minimum	Maximum
Concentration Risk [Line Items]	'	'	'	'	'	'	'
Concentration risk, number of third-party customer	2	2	'	'	'	'	'
Concentration risk, number of affiliate customer	1	'	'	'	'	'	'
Concentration risk, percentage	'	'	98.00%	93.00%	97.00%	'	'
Contractual arrangements remaining terms	'	'	'	'	'	'2 years	'6 years

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (USD $)	2 Months Ended	3 Months Ended			0 Months Ended
	Sep. 30, 2013	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Jan. 21, 2014
					Subsequent Event
Subsequent Event [Line Items]	'	'	'	'	'
Quarterly distribution per unit	$0.35	$0.35	$0.23	$0	$0.35
Distribution Made to Unitholders, Annualized Distributions Declared, Per Unit	'	'	'	'	$1.40

SUPPLEMENTAL_QUARTERLY_FINANCI2

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited) (Details) (USD $)	3 Months Ended				5 Months Ended	7 Months Ended	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Jul. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'
Net income (loss)	$4,405	$1,922	($1,206)	($3,935)	$7,190	($6,003)	$1,186	($4,306)	$8,541
Revenues	16,108	18,950	10,298	7,504	'	'	52,860	51,049	65,818
Cost of revenues	2,312	6,479	2,680	2,528	'	'	13,999	'	'
Gross margin	13,796	12,471	7,618	4,976	'	'	38,861	'	'
Operating expenses	4,012	4,283	3,700	3,896	'	'	15,891	'	'
Operating expenses	'	'	'	'	'	'	47,189	49,499	51,453
G&A expenses	2,672	2,482	1,321	1,411	'	'	7,886	'	'
Other operating expenses	2,476	2,349	2,369	2,219	'	'	9,413	'	'
Operating income	4,636	3,357	228	-2,550	'	'	5,671	1,550	14,365
Other income(expense)	-178	-1,424	-1,421	-1,374	'	'	-4,397	'	'
Net income before Texas margin tax	4,458	1,933	-1,193	-3,924	'	'	1,274	-4,205	8,476
Net income per limited partner unit - basic year-to-date	$0.40	$0.16	'	'	'	'	$0.40	'	'
Net income per limited partner unit - diluted year-to-date	$0.39	$0.15	'	'	'	'	$0.40	'	'
Weighted average limited partner units outstanding - basic	17,449,090	17,449,090	'	'	'	'	17,449,090	'	'
Weighted average limited partner units outstanding - diluted	17,761,090	17,761,090	'	'	'	'	17,761,090	'	'
Total interest expense, net of amounts capitalized	178	1,382	1,426	1,363	'	'	4,349	4,927	3,733
Texas margin tax expense	53	11	13	11	'	'	88	101	-65
Equity-based compensation	1,728	1,284	0	0	'	'	3,012	0	0
Loss on interest rate swap	0	43	-5	10	'	'	48	'	'
Depreciation expense	2,105	2,058	2,050	1,984	'	'	8,197	7,689	5,365
Adjusted EBITDA	$8,469	$6,700	$2,278	($567)	'	'	$16,880	'	'