Azure Midstream Partners (AZUR) 10-K 12 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Feb. 27, 2015	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	MARLIN MIDSTREAM PARTNERS, LP
Entity Central Index Key	1575599
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus (Q1,Q2,Q3,FY)	FY
Amendment Flag	FALSE
Entity Common Stock, Shares Outstanding		17,723,793
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$139,975

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS
Cash and cash equivalents	$2,603	$3,157
Accounts receivable	1,545	2,969
Accounts receivable—affiliates	3,963	3,632
Inventory	213	321
Prepaid assets	456	330
Other current assets	285	285
Total current assets	9,065	10,694
PROPERTY, PLANT AND EQUIPMENT, NET	162,158	162,548
OTHER ASSETS	615	900
TOTAL ASSETS	171,838	174,142
CURRENT LIABILITIES
Accounts payable	1,185	2,791
Accrued liabilities	2,370	2,131
Accounts payable—affiliates	1,438	1,552
Long-term incentive plan payable - affiliates	547	2,752
Total current liabilities	5,540	9,226
LONG-TERM LIABILITIES
Long-term incentive plan payable - affiliates	469	291
Deferred income tax	399	75
Long-term debt	11,000	4,000
Total liabilities	17,408	13,592
PARTNERS' CAPITAL
Partners' Capital	154,430	160,550
TOTAL LIABILITIES AND PARTNERS' CAPITAL	171,838	174,142
General Partner
PARTNERS' CAPITAL
Partners' Capital	560	705
Common Units | Limited Partner
PARTNERS' CAPITAL
Partners' Capital	141,156	142,587
Subordinate Units | Limited Partner
PARTNERS' CAPITAL
Partners' Capital	$12,714	$17,258

CONSOLIDATED_BALANCE_SHEETS_PA

CONSOLIDATED BALANCE SHEETS (PARENTHETICAL)	Dec. 31, 2014	Dec. 31, 2013
General partners' capital account, units issued	357,935	356,104
General partner units, outstanding	357,935	356,104
Common Units
Limited partners' capital account, units issued	8,979,248	8,724,545
Limited partner's capital, units outstanding	8,979,248	8,724,545
Subordinate Units
Limited partners' capital account, units issued	8,724,545	8,724,545
Limited partner's capital, units outstanding	8,724,545	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, 2014	Dec. 31, 2013	Dec. 31, 2012
REVENUES:
Natural gas, NGLs and condensate revenue	$13,569	$15,792	$34,708
Gathering, processing, transloading and other revenue	23,635	24,053	16,087
Gathering, processing, transloading and other revenue—affiliates	38,024	13,015	254
Total Revenues	75,228	52,860	51,049
OPERATING EXPENSES:
Cost of natural gas, NGLs and condensate revenue	4,790	8,484	13,355
Cost of natural gas, NGLs and condensate revenue—affiliates	12,558	5,515	7,668
Operation and maintenance	8,899	12,401	15,035
Operation and maintenance—affiliates	6,668	3,490	793
General and administrative	3,602	3,699	3,045
General and administrative—affiliates	5,067	4,187	1,021
Property tax expense	1,316	1,216	893
Depreciation expense	8,817	8,197	7,689
Loss on disposals of equipment	60	0	0
Total operating expenses	51,777	47,189	49,499
Operating income	23,451	5,671	1,550
Interest expense, net of amounts capitalized	-766	-4,349	-4,927
Interest and other income	0	0	23
Loss on interest rate swap	0	-48	-851
Net income (loss) before tax	22,685	1,274	-4,205
Income tax expense	553	88	101
Net income (loss)	22,132	1,186	-4,306
Other comprehensive income (loss)
Deferred gain from cash flow hedges	0	0	689
Reclassification of deferred gain from cash flow hedges into net income	0	0	-752
Comprehensive income (loss)	22,132	1,186	-4,369
Less: Allocation of East New Mexico Dropdown net income prior to acquisition (see Note 5)	-160
Less: general partner interest in net income	-435
Limited partner interest in net income	21,537
Net income per limited partner unit - basic (in dollars per share)		$0.40
Net income per limited partner unit - diluted (in dollars per share)	$1.21	$0.39
Common Units
Other comprehensive income (loss)
Limited partner interest in net income	10,923
Net income per limited partner unit - basic (in dollars per share)	$1.23
Net income per limited partner unit - diluted (in dollars per share)	$1.21
Subordinate Units
Other comprehensive income (loss)
Limited partner interest in net income	$10,614
Net income per limited partner unit - basic (in dollars per share)	$1.22
Net income per limited partner unit - diluted (in dollars per share)	$1.22

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, 2011	$32,274		$32,274
Increase (Decrease) in Partners' Capital
Net income (loss)	-4,306		-4,306
Capital contributions	4,374		4,374
Deferred gain from cash flow hedges	689		689
Reclassification of deferred gain from cash flow hedges	-752		-752
Ending Balance at Dec. 31, 2012	32,279		32,279
Increase (Decrease) in Partners' Capital
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
Increase (Decrease) in Partners' Capital
Net income (loss)	1,186
Deferred gain from cash flow hedges	0
Reclassification of deferred gain from cash flow hedges	0
Distributions	-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
Net income (loss)	7,190	[1]		144	3,523	3,523
Ending Balance at Dec. 31, 2013	160,550		0	705	17,258	142,587
Increase (Decrease) in Partners' Capital
Issuance of common units under the Long-Term Incentive Plan	2,962					2,962
Net income (loss)	22,132
Net income (loss), excluding net loss allocated to facility prior to acquisition	21,972			435	10,614	10,923
Deferred gain from cash flow hedges	0
Reclassification of deferred gain from cash flow hedges	0
Distributions	-25,819			-509	-12,473	-12,837
Issuance of general partner units (Note5)	38			38
Issuance of common units for assets acquired from affiliate (Note5)	257					257
Excess cash purchase price over historical cost of assets acquired from affiliate (Note 5)	-5,530			-109	-2,685	-2,736
Ending Balance at Dec. 31, 2014	$154,430		$0	$560	$12,714	$141,156
[1]	Post-IPO, August 1, 2013 to December 31, 2013 for the year ended December 31, 2013.

CONSOLIDATED_AND_COMBINED_STAT2

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$22,132	$1,186	($4,306)
Adjustments to reconcile net income to net cash flows provided by operating activities:
Loss on disposal	60	0	0
Allocation of East New Mexico Dropdown net income prior to acquisition	-160	0	0
Depreciation expense	8,817	8,197	7,689
Amortization of deferred financing costs	285	1,269	542
Equity-based compensation	1,963	3,012	0
Deferred income tax	325	75	0
Unrealized gain (loss) on derivatives	0	-57	-4,196
Unrealized Gain (loss) on derivatives—affiliates	0	0	-344
Changes in assets and liabilities:
(Increase) Decrease in accounts receivable	1,424	3,752	-480
(Increase) decrease in accounts receivable—affiliates	-332	-3,526	1,267
(Increase) decrease in inventory	108	-28	132
(Increase) decrease in prepaid assets	-126	-235	-36
(Increase) decrease in other current assets	0	3	236
(Increase) decrease in other assets	0	51	-679
Increase (decrease) in accounts payable	-324	120	-108
Increase (decrease) in accrued liabilities	234	813	1,192
Increase in long-term incentive plan payable	-1,028	32	0
Increase (decrease) in accounts payable—affiliates	-114	-5,488	10,305
Net cash provided by operating activities	33,264	9,176	11,214
CASH FLOWS FROM INVESTING ACTIVITIES:
Purchases of property, plant and equipment	-9,508	-12,710	-12,445
Net cash used in investing activities	-9,508	-12,710	-12,445
CASH FLOWS FROM FINANCING ACTIVITIES:
Member Capital contributions	0	3,574	4,287
Issuance of general partner units	38	0	0
Borrowing of long-term debt	29,500	36,500	126,500
Repayments on long-term debt	-22,500	-159,000	-123,500
Payment of deferred financing costs	0	-1,141	-932
Distributions	-25,818	-4,126	0
Proceeds from IPO, net of underwriting discount and other costs	0	125,329	0
Excess cash purchase price over historical cost of assets acquired from affiliate (Note 5)	-5,530	0	0
Net cash (used in) provided by financing activities	-24,310	1,136	6,355
NET INCREASE IN CASH AND CASH EQUIVALENTS	-554	-2,398	5,124
CASH AND CASH EQUIVALENTS—Beginning of Period	3,157	5,555	431
CASH AND CASH EQUIVALENTS—End of Period	2,603	3,157	5,555
Supplemental Cash Flow Information:
Cash paid for interest	510	3,448	4,296
Accrual of construction-in-progress and capital expenditures	125	1,407	635
Cash paid for income taxes	52	40	67
Issuance of common units for assets acquired from affiliate (Note 5)	257	0	0
Contribution of property from sole member	0	0	87
Net assets contributed to NuDevco Midstream Development, LLC	0	9,385	0
Intercompany accounts payable assigned to NuDevco Midstream Development, LLC	$0	$11,692	$0

ORGANIZATION

ORGANIZATION	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
ORGANIZATION	ORGANIZATION
	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.
	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%
	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, 2014, $11.0 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_AND_ACCO

BASIS OF PRESENTATION AND ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF PRESENTATION AND ACCOUNTING POLICIES	BASIS OF PRESENTATION AND ACCOUNTING POLICIES
	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 prior to the IPO. 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 prior to the IPO. 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 prior to the IPO.
	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, currently 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 prior to the IPO is not necessarily indicative of what the Partnership's results of operations, financial position and cash flows will be in the future.
	On August 1, 2014, the Partnership acquired 100% interest in the East New Mexico Transloading Facility ("East New Mexico Dropdown") from NuDevco Midstream Development. As the acquisition represented a transfer of assets under common control, the consolidated financial statements and related information presented herein have been recast to include the historical results of the East New Mexico Dropdown since July 2, 2014, the date the facility commenced operations. See Note 5 (“Property, Plant and Equipment”) for further discussion of the transaction.
	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, 2014 and 2013, 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, 2014 and 2013, respectively, the Partnership recorded $45,000 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, 2014 and 2013.
	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. There was no imbalance receivable as of December 31, 2014. As of December 31, 2013, the Partnership recorded an imbalance receivable of $0.1 million, 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, 2014 and 2013, 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, 2014 and 2013 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 $0.6 million, $0.1 million and $0.1 million for the years ended December 31, 2014, 2013 and 2012, 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, 2014, the Partnership had no liability recorded 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 for the year ending December 31, 2013 are 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 Partnership units. Net income related to acquisitions from affiliates under common control for periods prior to the acquisition date are allocated 100% to the general partner in determining net income per unit.
	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. 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. On December 5, 2014, phantom units, with distribution equivalent rights, of 215,000 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 May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014-09 will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective on January 1, 2017. Early application is not permitted. The standard permits the use of either the retrospective or cumulative effect transition method. We are evaluating the effect that ASU 2014-09 will have on our consolidated financial statements and related disclosures. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.

PARTNERSHIP_EQUITY_AND_DISTRIB

PARTNERSHIP EQUITY AND DISTRIBUTIONS	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
PARTNERSHIP EQUITY AND DISTRIBUTIONS	PARTNERSHIP EQUITY AND DISTRIBUTIONS
	Outstanding Units
	At December 31, 2014, the Partnership had outstanding common units of 8,979,248 and subordinated units of 8,724,545. NuDevco Midstream Development owns 100% of the interest in the Partnership’s general partner, which owns an approximate 2% general partner interest in the Partnership, 22% of the Partnership’s outstanding common units, representing an 11% interest in the Partnership, and 100% of the Partnership’s outstanding subordinated units, representing a 48% interest in the Partnership. See Note 5 (“Property, Plant and Equipment”) for discussion of common units and general partnership interest issued on August 1, 2014 in connection with the East New Mexico Dropdown.
	At December 31, 2013, the Partnership had outstanding common units of 8,724,545 and subordinated units of 8,724,545. At December 31, 2013, NuDevco Midstream Development owned 100% of the interest in the Partnership’s general partner, which owns an approximate 2% general partner interest in the Partnership, 21% of the Partnership's outstanding common units, representing a 10% interest in the Partnership, and 100% of the Partnership’s outstanding subordinated units, representing a 49% interest in the Partnership.
	Distributable Cash and Distributions
	The partnership agreement requires the Partnership to distribute all available cash, as defined in its partnership agreement, to unitholders of record, as of the applicable record date, no later than 45 days after the end of each quarter.
	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 the Partnership's 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 the Partnership 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 general and limited partners of record for the periods presented
	In Thousands, except per-unit amounts		Total Quarterly		Total		Date of
	Quarter ended:		Distribution per Unit		Distribution (2)		Distribution
	December 31, 2014		$	0.365	$	6,593	11-Feb-15
	September 30, 2014		$	0.365	$	6,593	4-Nov-14
	30-Jun-14		$	0.36	$	6,469	5-Aug-14
	March 31, 2014		$	0.355	$	6,375	6-May-14
	December 31, 2013		$	0.35	$	6,232	3-Feb-14
	September 30, 2013	-1	$	0.23	$	4,095	4-Nov-13
	(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) Total distribution amount includes the distribution paid to our general partner and does not include the distribution equivalent rights ("DER") payments that accrue on all unvested phantom units that have been issued under our LTIP.
	General Partner Interest
	The Partnership’s general partner is entitled to 2% of all distributions made by the Partnership. If the Partnership issues additional units, the general partner has the right, but not the obligation, to contribute a proportionate amount of capital to the Partnership in order to maintain its 2% general partner interest. The 2% general partner interest, and the percentage of the Partnership’s cash distributions to which the general partner is entitled from such 2% 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 partner's 2% general partner interest.
	Incentive Distribution Rights
	NuDevco indirectly holds all of the incentive distribution rights ("IDRs") issued in the IPO. IDRs entitle NuDevco to receive an increasing percentage (13%, 23% and 48%) 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% 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.
	Subordinated Units and Common Units Held by NuDevco Midstream Development
	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, holders of the subordinated units will not be entitled to receive any distributions until holders of 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.
	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, 2014
NET INCOME PER UNIT [Abstract]
NET INCOME PER UNIT	NET INCOME PER UNIT
	The net income per unit figures on the consolidated and combined Statement of Operations for the year ended December 31, 2013 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, 2014 or 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. Net income attributable to the East New Mexico Dropdown for the period July 2, 2014 through July 31, 2014 is not allocated to the limited partners for purposes of calculating net income per limited partner unit.
		For the year ending December 31,
		2014			2013
	Net income (1)	$	22,132		$	7,190
	Less: allocation of East New Mexico dropdown net income prior to acquisition	(160		)	—
	Less: general partner interest in net income	(435		)	(144		)
	Limited partner interest in net income	$	21,537		$	7,046
	Net income allocable to common units	$	10,923		$	3,523
	Net income allocable to subordinated units	10,614			3,523
	Limited partner interest in net income	$	21,537		$	7,046
	Net income per limited partner common unit - basic	$	1.23		$	0.4
	Net income per limited subordinated unit - basic	$	1.22		$	0.4
	Net income per limited partner unit - basic	$	1.22		$	0.4
	Net income per limited partner common unit - diluted	$	1.21		$	0.39
	Net income per limited subordinated unit - diluted	$	1.22		$	0.4
	Net income per limited partner unit - diluted	$	1.21		$	0.4
	Weighted average limited partner units outstanding - basic
	Common units	8,902,295			8,724,545
	Subordinated units	8,724,545			8,724,545
	Total	17,626,840			17,449,090
	Weighted average limited partner units outstanding - diluted
	Common units	9,026,734			9,036,545
	Subordinated units	8,724,545			8,724,545
	Total	17,751,279			17,761,090
	(1) Post-IPO, August 1, 2013 to December 31, 2013 for the year ended December 31, 2013.

PROPERTY_PLANT_AND_EQUIPMENT

PROPERTY, PLANT AND EQUIPMENT	12 Months Ended
	Dec. 31, 2014
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)	2014			2013
	Gas processing plants (1)	5 – 40	$	136,638		$	133,859
	Gathering pipelines and related equipment	5 – 40	52,591			47,728
	Land and rights of way	—	11,818			11,043
	Construction-in-progress	—	1,955			2,594
	Information technology and other	2 – 10	2,065			1,548
	Office building	15	306			306
	Autos	5	472			357
	Total		205,845			197,435
	Accumulated depreciation		(43,687		)	(34,887		)
	Property, plant and equipment, net		$	162,158		$	162,548
	-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.
	The Partnership's principal crude oil logistics assets consist of three crude oil transloading facilities: (i) its Wildcat facility located in Carbon County, Utah, where the Partnership currently operates one skid transloader and two ladder transloaders, (ii) its Big Horn facility located in Big Horn County, Wyoming, where the Partnership currently operates one skid transloader and one ladder transloader, and (iii) its East New Mexico facility located in Sandoval County, New Mexico, where the Partnership currently operates one skid transloader, which was acquired on August 1, 2014, as discussed below.
	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 incurred no revenues or expenses associated with the Monell facility. The Partnership was responsible for the design and construction of the Monell facility. Anadarko was designated as an operator of the Monell facility with 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 condensed consolidated and combined financial statements, as earned and incurred prior to the closing of the IPO, respectively.
	For the years ended December 31, 2013 and 2012, the Partnership recorded revenues of $0.2 million and $1.2 million, respectively, and recorded expenses of $0.3 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.
	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 $8.8 million, $8.2 million and $7.7 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	Acquisitions
	On July 30, 2014, the Partnership entered into a Contribution Agreement with NuDevco Midstream Development and Marlin Midstream GP, LLC, the general partner of the Partnership, for the purchase of the East New Mexico Transloading Facility, located in Sandoval County, New Mexico, for $7.4 million. The purchase closed on August 1, 2014 and the total purchase price consisted of a $5.5 million cash payment and 89,720 Partnership common units issued to NuDevco Midstream Development, which were valued at the historical carrying value of the assets acquired of approximately $0.3 million. The assets acquired by the Partnership consist of one skid transloader and other miscellaneous equipment, which were subsequently assigned to Marlin Logistics. Additionally, the general partner of the Partnership made a capital contribution of $38,000 for the issuance of general partnership interest, to allow the general partner to maintain its 2% general partner interest in the Partnership.
	The East New Mexico Dropdown represented a transaction between entities under common control. As a result, the consolidated and combined financial statements and related information presented herein have been recast to include the historical results of the East New Mexico Dropdown. Net income for the facility was approximately $0.2 million for the period July 2, 2014, the date operations commenced, through July 31, 2014. In addition, the Partnership recorded the assets of the East New Mexico Dropdown acquired at their historical carrying value to NuDevco Midstream Development on the date of acquisition. Any difference between consideration given and the historical carrying value of the assets is recognized as a reduction to partners' capital on a pro-rata basis. Cash consideration up to the historical carrying value of the assets acquired is presented as an investing activity and cash consideration in excess of the historical carrying value of the assets acquired is presented as a financing activity in the consolidated and combined Statements of Cash Flows.
	In conjunction with the East New Mexico Dropdown, the Partnership entered into a three-year transloading services agreement with AES, effective August 1, 2014, requiring minimum monthly volume commitments for crude oil transloading services to be operated at the East New Mexico Transloading Facility.

LONGTERM_DEBT_AND_INTEREST_EXP

LONG-TERM DEBT AND INTEREST EXPENSE	12 Months Ended
	Dec. 31, 2014
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-14			31-Dec-13
	Revolving credit facility		11,000			4,000
	Total long-term debt		$	11,000		$	4,000
	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, 2014 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, 2014 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 $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 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, were 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, 2014, the Partnership had $11.0 million outstanding on the senior secured revolving credit facility.
	The Partnership's revolving credit facility also contains covenants that, among other things, require it to maintain specified ratios or conditions. The Partnership must maintain a consolidated senior secured leverage ratio, consisting of consolidated indebtedness under its 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, the Partnership must maintain a consolidated interest coverage ratio, consisting of its consolidated EBITDA minus capital expenditures to its 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. As of December 31, 2014, the Partnership was in compliance with all debt covenants.
	In addition, the Partnership's 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.
	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 $0.7 million and $1.0 million as of December 31, 2014 and 2013, respectively. Of these amounts, $0.3 million and $0.3 million are included in other current assets within both of the consolidated Balance Sheets at December 31, 2014 and 2013, and $0.4 million and $0.7 million are included in other assets within the consolidated Balance Sheets at December 31, 2014 and 2013, respectively, based on the term of the related debt obligations.
	Amortization of deferred financing costs was $0.3 million, $0.5 million and $0.4 million for the years ended December 31, 2014, 2013 and 2012, 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 current 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, 2014, 2013 and 2012 is as follows:
	In Thousands	Years Ended December 31,
		2014			2013			2012
	Interest expense on long-term debt	$	526		$	3,312		$	4,599
	Interest expense from amortization of deferred financing costs	285			508			365
	Interest expense from write-off of unamortized deferred financing costs	—			761			177
	Less interest expense capitalized	(45		)	(232		)	(214		)
	Total interest expense, net of amounts capitalized	$	766		$	4,349		$	4,927

DERIVATIVE_FINANCIAL_INSTRUMEN

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2014
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, 2014 and 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, 2014 or 2013.
	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.
	As of December 31, 2014 and 2013, respectively, there are no derivative assets and liabilities, including balances for designated and undesignated hedge activities, as the Partnership did not have any open derivative instruments designated as cash flow hedges at December 31, 2014 and 2013, respectively.
	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 Location	Years Ended December 31,
			2014		2013			2012
	Natural gas option contracts	Cost of revenues—affiliates	$	—	$	—		$	(87	)
	Interest rate swap contracts	Gain (loss) on interest rate swap	$	—	$	(48	)	$	(851	)
	Total loss recognized in income		$	—	$	(48	)	$	(938	)
	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,
			2014		2013			2012
	Gain recognized in accumulated other comprehensive income		$	—	$	—		$	689
		Accumulated other
		comprehensive income
	Gain reclassified from accumulated other comprehensive income to income	Cost of revenues—affiliates	$	—	$	—		$	(752	)
	As of December 31, 2014 and 2013, 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, 2014 and 2013, respectively.

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2014
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. 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 had no financial instruments at December 31, 2014 and 2013. At the IPO date, the Partnership settled the outstanding 2012 Swap.
	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, 2014
Segment Reporting [Abstract]
SEGMENT INFORMATION	SEGMENT INFORMATION
	The Partnership's revenues are derived from two operating segments: (i) gathering and processing and (ii) logistics. These segments 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. Gross margin is a primary performance measure used by management. The Partnership defines gross margin as revenues less costs of revenues. Gross margin should not be considered an alternative to, or more meaningful than, operating income as determined in accordance with generally accepted accounting principles.
	The following tables present financial information by segment for the years ended December 31, 2014 and 2013. Our crude oil logistics segment had no material assets, liabilities, or operations prior to the Partnership's IPO.
	Year ended December 31, 2014
		Gathering &		Logistics		Corporate and			Marlin Midstream
	In Thousands	Processing				Consolidation			Partners, LP
	Total revenues	$	59,926	$	15,302	$	—		$	75,228
	Cost of revenues	17,348		—		—			17,348
	Gross margin	42,578		15,302		—			57,880
	Operation and maintenance	12,828		2,087		652			15,567
	General and administrative	—		—		8,669			8,669
	Other operating expenses	10,097		96		—			10,193
	Operating income	19,653		13,119		(9,321		)	23,451
	Interest expense, net of amounts capitalized	—		—		(766		)	(766		)
	Gain (loss) on interest rate swap	—		—		—			—
	Net income before tax	19,653		13,119		(10,087		)	22,685
	Income tax expense	—		—		553			553
	Net income (loss)	$	19,653	$	13,119	$	(10,640	)	$	22,132
	Year ended December 31, 2013
		Gathering &		Logistics		Corporate and			Marlin Midstream
	In Thousands	Processing				Consolidation			Partners, LP
	Total revenues	$	47,052	$	5,808	$	—		$	52,860
	Cost of revenues	13,999		—		—			13,999
	Gross margin	33,053		5,808		—			38,861
	Operation and maintenance	14,424		613		854			15,891
	General and administrative	—		—		7,886			7,886
	Other operating expenses	9,390		23		—			9,413
	Operating income	9,239		5,172		(8,740		)	5,671
	Interest expense, net of amounts capitalized	—		—		(4,349		)	(4,349		)
	Gain (loss) on interest rate swap	—		—		(48		)	(48		)
	Net income before tax	9,239		5,172		(13,137		)	1,274
	Income tax expense	—		—		88			88
	Net income (loss)	$	9,239	$	5,172	$	(13,225	)	$	1,186
	The following table presents financial information by segment at December 31, 2014 and 2013, respectively:
	Balance Sheet at December 31, 2014
	In Thousands	Gathering &		Logistics		Corporate and			Marlin Midstream
		Processing				Consolidation			Partners, LP
	Assets:
	Current assets	$	4,268	$	1,733	$	3,064		$	9,065
	Property, plant and equipment, net	161,389		769		—			162,158
	Other assets	163		—		452			615
	Total Assets	$	165,820	$	2,502	$	3,516		$	171,838
	Liabilities and Partners’ Capital
	Total current liabilities	$	1,323	$	132	$	4,085		$	5,540
	Total long-term liabilities	—		—		11,868			11,868
	Total Liabilities	1,323		132		15,953			17,408
	Partners’ Capital	164,497		2,370		(12,437		)	154,430
	Total Liabilities and Partners’ Capital	$	165,820	$	2,502	$	3,516		$	171,838
	Balance Sheet at December 31, 2013
	In Thousands	Gathering &		Logistics		Corporate and			Marlin Midstream
		Processing				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, 2014
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES
	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. Under the three-year fee-based commercial agreement with AES, the Partnership is reimbursed for a majority of any deficiency payments accrued under the reserved capacity agreement. The Partnership recorded $0.9 million and $0.5 million of expense, net of deficiency reimbursements, for the twelve months ended December 31, 2014 and 2013, respectively, 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 its financial condition or results of operations.

TRANSACTIONS_WITH_AFFILIATES

TRANSACTIONS WITH AFFILIATES	12 Months Ended
	Dec. 31, 2014
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".
	Accounts receivable from and accounts payable to affiliates
	The Partnership had receivables due from affiliates of $4.0 million and $3.6 million at December 31, 2014 and 2013, respectively. Receivables due from affiliates primarily related to our fee-based gathering and processing agreements with SEV and AES, and our fee-based transloading services agreement with AES. Payables to affiliates were $1.4 million and $1.6 million at December 31, 2014 and 2013, respectively. Payables to affiliates primarily related to settlements under our gathering and processing agreements with SEV and AES and reimbursement to an affiliate of NuDevco for certain general and administrative and operating costs under the omnibus agreement with NuDevco. Long-term incentive plan-payable to affiliates represents amounts accrued related to equity-based compensation to affiliate employees and directors.
	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 and 2012 from these agreements was $3.0 million and $7.7 million, respectively.
	Additionally, the Partnership has entered into a gas transportation agreement with a subsidiary of SEI. 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, 2014, 2013 and 2012 are gathering, processing and other revenue—affiliates of less than $0.1 million, less than $0.1 million, and $0.3 million, respectively, related to these transactions.
	The Partnership currently has in place a three-year fee-based commercial agreement with AES, requiring a minimum monthly volume commitment of 100 MMcf/d. This agreement became effective August 1, 2013. Included in the Partnership's results of operations for the year ended December 31, 2014 and 2013 are gathering, processing, transloading and other revenue—affiliates of $22.7 million and $7.2 million, respectively, 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, 2014 and 2013 related to this agreement were $12.6 million and $2.5 million, respectively.
	In connection with the IPO, the Partnership entered into three-year transloading services agreements with AES, requiring minimum monthly volume commitments for crude oil transloading services. In connection with the East New Mexico dropdown (see Note 5, "Property, Plant and Equipment"), the Partnership entered into a three-year transloading services agreement with AES, requiring minimum monthly volume commitments for transloading services. Included in the Partnership's results of operations for the year ended December 31, 2014 and 2013 are gathering, processing, transloading and other revenue—affiliates of $15.3 million and $5.8 million, respectively, 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 prior to the IPO.
	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, currently 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, 2014, 2013 and 2012 was $6.7 million, $3.5 million and $0.8 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, 2014, 2013 and 2012 was $5.1 million, $4.2 million and $1.0 million, respectively. Amounts incurred by the Partnership for the years ended 2014 and 2013 include expense for the Marlin Midstream Partners, LP 2013 Long-Term Incentive Plan ("LTIP").
	Capital Contributions
	During the seven months prior to the IPO on July 31, 2013 and for the twelve months ended December 31, 2012, the Partnership received capital contributions of $3.6 million and $4.4 million, respectively, from its sole member.

EQUITY_BASED_COMPENSATION

EQUITY BASED COMPENSATION	12 Months Ended
	Dec. 31, 2014
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. On December 5, 2014, phantom units, with distribution equivalent rights, of 215,000 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. At December 31, 2014 and 2013, a liability of approximately $48,000 and $32,000, respectively, was recorded for distributions associated with unvested phantom units under our LTIP plan.
	For those employees of NuDevco Midstream Development or its affiliates who had attained five or more years of service at the grant date of August 1, 2013, the phantom units awarded fully vested on February 15, 2014. For those employees of NuDevco Midstream Development who had not attained five or more years of service with NuDevco Midstream Development or its affiliates at the grant date of August 1, 2013, the phantom units awarded will vest in five equal annual installments. The first installment vested on June 30, 2014. The phantom units awarded on August 1, 2013 to board members of the Partnership’s general partner fully vested on February 15, 2014.
	The phantom units awarded to employees of NuDevco Midstream Development or its affiliates on December 5, 2014 will vest in three equal annual installments with the first installment vesting on June 30, 2015. The phantom units awarded on December 5, 2014 to board members of the Partnership’s general partner fully vested on February 15, 2015.
	For the years ended December 31, 2014 and 2013, approximately $1.3 million and $2.1 million, respectively, in compensation expense was recorded in general and administrative expenses - affiliates and approximately $0.7 million and $0.9 million, respectively, 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, 2014 is presented below:
		Number of shares		Weighted Average Grant-Date Fair Value
	Total Non-vested at January 1, 2014	312,000		$	20
	Granted	235,000		19.42
	Vested	(222,600	)	20
	Forfeited or canceled	(26,000	)	20
	Total Outstanding at December 31, 2014	298,400		$	19.54
	Unrecognized compensation expense associated with the unvested phantom units at December 31, 2014 was approximately $4.5 million and is expected to be recognized over a weighted average period of approximately 2.5 years.

CONCENTRATIONS_OF_CREDIT_RISK

CONCENTRATIONS OF CREDIT RISK	12 Months Ended
	Dec. 31, 2014
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, 2014 and 2013.
	Prior to the IPO, 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% of total revenues for the years ended December 31, 2012. 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 one to five years.

INCOME_TAX

INCOME TAX	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
INCOME TAX	INCOME TAX
	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 current income tax expense was $0.2 million, $0.1 million and $0.1 million for the years ended December 31, 2014, 2013 and 2012, and deferred income tax expense was $0.4 million for the year ended December 31, 2014. At December 31, 2014 and 2013, there was $0.4 million and $0.1 million, respectively, of non-current deferred income tax liabilities related to property, plant and equipment. The Partnership does not do business in any other state where a similar tax is applied.

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS
	Fourth Quarter 2014 Distribution
	On January 23, 2015, the Partnership announced that the board of directors of its general partner declared a quarterly cash distribution of $0.365 per unit, or $1.46 on an annualized basis, to unitholders of record as of February 6, 2015. The Partnership paid the quarterly distribution to unitholders on February 11, 2015.
	Sale of General Partner Interest and Contribution of the Legacy Gathering System
	On February 27, 2015, the Partnership consummated a Transaction Agreement (the “Transaction Agreement”) by and among the Partnership, Azure Midstream Energy LLC, a Delaware limited liability company that is wholly owned by Azure Midstream Holdings LLC (collectively “Azure”), the General Partner, NuDevco, and Marlin IDR Holdings (“IDRH”).
	The consummation of the Transaction Agreement resulted in the Partnership acquiring the Legacy System from Azure and Azure receiving $92.5 million in cash and acquiring 100% of the equity interests in the GP and 90% of the Partnership’s incentive distribution rights (“IDRs”).
	The Transaction Agreement occurred in the following steps:
	•	The Partnership (i) amended and restated its partnership agreement to reflect the unitization of all of the Partnership’s incentive distribution rights (as unitized, the “IDR Units”) and (ii) recapitalize the incentive distribution rights owned by IDRH into 100 IDR Units.
	•	The Partnership redeemed 90 IDR Units held by IDRH in exchange for a payment by the Partnership of $63.0 million to IDRH (the “Redemption”).
	•	Azure contributed the Legacy System to the Partnership through the contribution, indirectly or directly, of (i) all of the outstanding general and limited partner interests in Talco Midstream Assets, Ltd., a Texas limited liability company and subsidiary of Azure (“Talco”), and (ii) certain assets (the “TGG Assets”) owned by TGG Pipeline, Ltd., a Texas limited liability company and subsidiary of Azure (“TGG”), in exchange for aggregate consideration of $162.5 million, which was paid to Azure in the form of a cash payment of $99.5 million and in the form of the issuance of 90 IDR Units (the foregoing transaction, collectively, the “Contribution”).
	•	Azure purchased from NuDevco (i) all of the outstanding membership interests in the GP (the “GP Purchase,”) for $7.0 million and (ii) an option to acquire up to 20% of each of the common units and subordinated units of the Partnership held by NuDevco as of the execution date of the Transaction Agreement (the “Option,” together with the Redemption, Contribution and GP Purchase, the “Transactions”). As a result, NuDevco no longer controls the Partnership.
	The Legacy System consists of approximately 658 miles of high-and low-pressure gathering lines and serves approximately 100,000 dedicated acres within Harrison, Panola and Rusk counties in Texas and Caddo parish in Louisiana and currently serves the Cotton Valley formation, the Haynesville shale formation and the shallower producing sands in the Travis Peak formation. The Legacy System has access to seven major downstream markets, three third-party processing plants and the Panola County processing plants. The combination of the Partnership's natural gas processing assets and the Legacy System's gathering assets creates a diverse platform of midstream services and establishes the Partnership as one of the largest gathering and processing systems in the Cotton Valley formation in east Texas and north Louisiana.
	Because the financial information associated with this transaction has not been finalized as of the date that our consolidated financial statements were available to be issued, the related unaudited supplemental pro forma information has not been provided.
	New Senior Secured Revolving Credit Facility
	Contemporaneously with the Transactions, the Partnership entered into a new senior secured revolving credit facility (the “Senior Credit Facility”) with Wells Fargo Bank, National Association, as administrative agent, Wells Fargo Securities, LLC, Merrill Lynch, Pierce, Fenner & Smith Incorporated and SG Americas Securities, LLC (collectively, the “Lenders”). The Senior Credit Facility has a maturity date of February 25, 2018 and up to $250 million in commitments.
	The Partnership immediately borrowed $180.8 million under the Senior Credit Facility, of which $99.5 million was paid in connection with the Contribution, $63.0 million was paid in connection with the Redemption, $15 million was used to repay the outstanding balance as of February 27, 2015 under the Partnership’s existing senior secured revolving credit facility and $3.3 million was used to pay fees and expenses associated with the Senior Credit Facility.
	The Senior Credit Facility requires that (a) all domestic restricted subsidiaries of the Partnership guarantee the obligations of the Partnership and the subsidiary guarantors under (i) the Senior Credit Facility and other loan documents and (ii) certain hedging agreements and cash management agreements with lenders and affiliates of lenders, and (b) all such obligations be secured by a security interest in substantially all of the assets of the Partnership, including the contributed Legacy System. and the subsidiary guarantors, in each case, subject to certain customary exceptions.
	The Senior Credit Facility provides for a $15 million sublimit for letters of credit and a $15 million sublimit for swingline loans. Borrowings under the Credit Agreement bear interest at (a) the LIBOR Rate (as defined in the Senior Credit Facility) plus an applicable margin of 2.75% - 3.75% or (b) the Base Rate (as defined in the Senior Credit Facility) plus an applicable margin of 1.75% - 2.75%, in each case, based on the Consolidated Total Leverage Ratio (as defined in the Senior Credit Facility). Until such time as the Partnership receives gross cash proceeds of not less than $50 million from the consummation of a single issuance of common equity and prepays the loans under the Senior Credit Facility in an amount not less than $50 million (the “Availability Period”), the amount the Partnership may borrow under the Senior Credit Facility is limited to an amount (the “Availability”) equal to the sum of (a) the product of (i) 4.5 and (ii) Eligible Gas Gathering EBITDA (as defined in the Senior Credit Facility); plus (b) the lesser of (i) $15 million and (ii) Eligible Transloading EBITDA (as defined in the Senior Credit Facility). During the Availability Period, the Availability shall be determined periodically in connection with the Partnership’s delivery of annual and quarterly financial statements pursuant to the Senior Credit Facility and upon the occurrence of certain other events described in the Senior Credit Facility.
	The Senior Credit Facility contains affirmative and negative covenants customary for credit facilities of its size and nature that, among other things, limit or restrict the ability of the Partnership and its subsidiaries to (a) incur additional debt; (b) grant certain liens; (c) make certain investments; (d) engage in certain mergers or consolidations; (e) dispose of certain assets; (f) enter into certain types of transactions with affiliates; (g) make distributions, with certain exceptions, including the distribution of Available Cash (as defined in the Partnership Agreement) if no default or event of default exists and, during the Availability Period, if an Availability deficiency exists, the aggregate amount of distributions of Available Cash made during such deficiency shall not exceed $10 million (h) enter into certain restrictive agreements or amend certain material agreements and (i) prepay certain debt.
	The Senior Credit Facility requires that the Partnership’s ratio of Consolidated Funded Indebtedness (as defined in the Senior Credit Facility) on the date of determination to Adjusted Consolidated EBITDA (as defined in the Senior Credit Facility) for a trailing four fiscal quarter period not exceed 4.50 to 1.00 (or 5.00 to 1.00 for the period commencing on the date that a certain acquisition is consummated through the last day of the second full fiscal quarter following the date of such acquisition). In addition, the Credit Agreement requires the Partnership’s ratio of Adjusted Consolidated EBITDA for a trailing four fiscal quarter period to Consolidated Interest Expense (as defined in the Senior Credit Facility) for such period to be at least 2.50 to 1.00.
	Termination of Existing Omnibus Agreement and Entering into New Omnibus Agreement
	In connection with the closing of the Transactions, the Partnership terminated its Omnibus Agreement, dated July 31, 2013 (the “Existing Omnibus Agreement”), by and between NuDevco and its affiliates, the General Partner and the Partnership (together with the General Partner, the “Partnership Parties”). NuDevco and its affiliates released each of the Partnership Parties, and each of the Partnership Parties released NuDevco and its affiliates, from any claims or liabilities arising from or under the terms of the Omnibus Agreement (other than any obligations under the Transaction Agreement).
	Also in connection with the closing of the Transactions, the Partnership entered into an omnibus agreement (the “New Omnibus Agreement”) with the General Partner and Azure, pursuant to which, among other things:
	•	Azure will provide corporate, general and administrative services (the “Services”) on behalf of the General Partner for the benefit of the Partnership and its subsidiaries;
	•	The Partnership is obligated to reimburse Azure and its affiliates for costs and expenses incurred by Azure and its affiliates in providing the Services on behalf of the Partnership, including, but not limited to, administrative costs and the compensation costs of the employees of Azure and its affiliates that provide Services to the Partnership;
	•	The General Partner or Azure may at any time temporarily or permanently exclude any particular Service from the scope of the New Omnibus Agreement upon 90 days’ notice;
	•	The Partnership or Azure may terminate the New Omnibus Agreement in the event that Azure ceases to control the General Partner. Azure may also terminate the New Omnibus Agreement if the General Partner is removed without cause and the units held by the General Partner were not voted in favor of the removal; and
	•	The Partnership will have a right of first offer on any proposed transfer of any assets owned by Azure or its subsidiaries as of January 14, 2015.
	Amendment to Transloading Services Agreements
	Upon the closing of the Transactions, the Partnership entered into amendments to its (i) Wildcat Transloading Services Agreement associated with its transloading facility located in Carbon County, Utah, (ii) Big Horn Transloading Services Agreement associated with its transloading facility located in Big Horn County, Wyoming and (iii) Ladder Transloading Services Agreement, all of which are transloading services agreements with AES. The amendments extend the minimum volume commitments associated with these services agreements until February 27, 2020, or an additional five years from the date of the amendment.

SUPPLEMENTAL_QUARTERLY_FINANCI

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited)	12 Months Ended
	Dec. 31, 2014
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, 2014 is as follows:
		For the year ending December 31, 2014
	in thousands except volume and per unit amounts	Q1			Q2			Q3			Q4			TOTAL
	Revenues	$	18,818		$	22,445		$	17,219		$	16,746		$	75,228
	Cost of revenues	4,208			7,240			2,762			3,138			17,348
	Gross margin	14,610			15,205			14,457			13,608			57,880
	Operating expenses	4,316			4,000			3,637			3,614			15,567
	G&A expenses	2,497			2,036			1,729			2,407			8,669
	Other operating expenses	2,443			2,577			2,601			2,572			10,193
	Operating income	5,354			6,592			6,490			5,015			23,451
	Other income(expense)	(155		)	(182		)	(212		)	(217		)	(766		)
	Net income before income taxes	$	5,199		$	6,410		$	6,278		$	4,798		$	22,685
	Net income per limited partner common unit - basic (1)	$	0.28		$	0.35		$	0.33		$	0.25		$	1.23
	Net income per limited subordinated unit - basic (1)	$	0.29		$	0.36		$	0.33		$	0.25		$	1.22
	Net income per limited partner common unit - diluted (1)	$	0.28		$	0.35		$	0.33		$	0.25		$	1.21
	Net income per limited subordinated unit - diluted (1)	$	0.29		$	0.36		$	0.33		$	0.25		$	1.22
	Weighted average limited partner units outstanding - basic	17,601,902			17,602,034			17,673,561			17,703,793			17,626,840
	Weighted average limited partner units outstanding - diluted	17,711,652			17,711,652			17,771,140			17,837,813			17,751,279
		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 income taxes	$	(3,924	)	$	(1,193	)	$	1,933		$	4,458		$	1,274
	Net income per limited partner unit - basic (1)							$	0.16		$	0.24		$	0.4
	Net income per limited partner unit - diluted (1)							$	0.15		$	0.24		$	0.39
	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
	(1) The sum of the quarterly net income per limited partner unit (basic and diluted) may not agree to the net income per limited partner unit for the year due to the timing of limited partner unit issuances.
	Adjusted quarterly EBITDA for the years ended December 31, 2014 and 2013 is as follows:
		For the year ending December 31, 2014
		Q1		Q2		Q3		Q4		Total
	Net income (loss)	5,130		6,342		6,140		4,520		22,132
	Interest expense, net of amounts capitalized	155		182		212		217		766
	Income tax expense	69		68		138		278		553
	Equity-based compensation	1,246		222		53		442		1,963
	Depreciation expense	2,144		2,186		2,238		2,249		8,817
	Adjusted EBITDA	8,744		9,000		8,781		7,706		34,231
		For the year ending December 31, 2013
		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
	Income 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_AND_ACCO1

BASIS OF PRESENTATION AND ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2014
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, 2014 and 2013, respectively, the Partnership recorded $45,000 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.
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	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, 2014 and 2013, 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, 2014 and 2013 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 $0.6 million, $0.1 million and $0.1 million for the years ended December 31, 2014, 2013 and 2012, 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 for the year ending December 31, 2013 are 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 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. 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. On December 5, 2014, phantom units, with distribution equivalent rights, of 215,000 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 May 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014-09 will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective on January 1, 2017. Early application is not permitted. The standard permits the use of either the retrospective or cumulative effect transition method. We are evaluating the effect that ASU 2014-09 will have on our consolidated financial statements and related disclosures. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.

ORGANIZATION_Tables

ORGANIZATION (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014
Equity [Abstract]
Schedule of Cash Distributions to Unitholders	The Partnership declared the following cash distributions to its general and limited partners of record for the periods presented
	In Thousands, except per-unit amounts		Total Quarterly		Total		Date of
	Quarter ended:		Distribution per Unit		Distribution (2)		Distribution
	December 31, 2014		$	0.365	$	6,593	11-Feb-15
	September 30, 2014		$	0.365	$	6,593	4-Nov-14
	30-Jun-14		$	0.36	$	6,469	5-Aug-14
	March 31, 2014		$	0.355	$	6,375	6-May-14
	December 31, 2013		$	0.35	$	6,232	3-Feb-14
	September 30, 2013	-1	$	0.23	$	4,095	4-Nov-13
	(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) Total distribution amount includes the distribution paid to our general partner and does not include the distribution equivalent rights ("DER") payments that accrue on all unvested phantom units that have been issued under our LTIP.

NET_INCOME_PER_UNIT_Tables

NET INCOME PER UNIT (Tables)	12 Months Ended
	Dec. 31, 2014
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. Net income attributable to the East New Mexico Dropdown for the period July 2, 2014 through July 31, 2014 is not allocated to the limited partners for purposes of calculating net income per limited partner unit.
		For the year ending December 31,
		2014			2013
	Net income (1)	$	22,132		$	7,190
	Less: allocation of East New Mexico dropdown net income prior to acquisition	(160		)	—
	Less: general partner interest in net income	(435		)	(144		)
	Limited partner interest in net income	$	21,537		$	7,046
	Net income allocable to common units	$	10,923		$	3,523
	Net income allocable to subordinated units	10,614			3,523
	Limited partner interest in net income	$	21,537		$	7,046
	Net income per limited partner common unit - basic	$	1.23		$	0.4
	Net income per limited subordinated unit - basic	$	1.22		$	0.4
	Net income per limited partner unit - basic	$	1.22		$	0.4
	Net income per limited partner common unit - diluted	$	1.21		$	0.39
	Net income per limited subordinated unit - diluted	$	1.22		$	0.4
	Net income per limited partner unit - diluted	$	1.21		$	0.4
	Weighted average limited partner units outstanding - basic
	Common units	8,902,295			8,724,545
	Subordinated units	8,724,545			8,724,545
	Total	17,626,840			17,449,090
	Weighted average limited partner units outstanding - diluted
	Common units	9,026,734			9,036,545
	Subordinated units	8,724,545			8,724,545
	Total	17,751,279			17,761,090
	(1) Post-IPO, August 1, 2013 to December 31, 2013 for the year ended December 31, 2013.

PROPERTY_PLANT_AND_EQUIPMENT_T

PROPERTY, PLANT AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2014
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)	2014			2013
	Gas processing plants (1)	5 – 40	$	136,638		$	133,859
	Gathering pipelines and related equipment	5 – 40	52,591			47,728
	Land and rights of way	—	11,818			11,043
	Construction-in-progress	—	1,955			2,594
	Information technology and other	2 – 10	2,065			1,548
	Office building	15	306			306
	Autos	5	472			357
	Total		205,845			197,435
	Accumulated depreciation		(43,687		)	(34,887		)
	Property, plant and equipment, net		$	162,158		$	162,548
	-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, 2014
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	Long-term debt consists of the following:
	In Thousands		31-Dec-14			31-Dec-13
	Revolving credit facility		11,000			4,000
	Total long-term debt		$	11,000		$	4,000
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, 2014, 2013 and 2012 is as follows:
	In Thousands	Years Ended December 31,
		2014			2013			2012
	Interest expense on long-term debt	$	526		$	3,312		$	4,599
	Interest expense from amortization of deferred financing costs	285			508			365
	Interest expense from write-off of unamortized deferred financing costs	—			761			177
	Less interest expense capitalized	(45		)	(232		)	(214		)
	Total interest expense, net of amounts capitalized	$	766		$	4,349		$	4,927

DERIVATIVE_FINANCIAL_INSTRUMEN1

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 Location	Years Ended December 31,
			2014		2013			2012
	Natural gas option contracts	Cost of revenues—affiliates	$	—	$	—		$	(87	)
	Interest rate swap contracts	Gain (loss) on interest rate swap	$	—	$	(48	)	$	(851	)
	Total loss recognized in income		$	—	$	(48	)	$	(938	)
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,
			2014		2013			2012
	Gain recognized in accumulated other comprehensive income		$	—	$	—		$	689
		Accumulated other
		comprehensive income
	Gain reclassified from accumulated other comprehensive income to income	Cost of revenues—affiliates	$	—	$	—		$	(752	)

SEGMENT_INFORMATION_Tables

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables present financial information by segment for the years ended December 31, 2014 and 2013. Our crude oil logistics segment had no material assets, liabilities, or operations prior to the Partnership's IPO.
	Year ended December 31, 2014
		Gathering &		Logistics		Corporate and			Marlin Midstream
	In Thousands	Processing				Consolidation			Partners, LP
	Total revenues	$	59,926	$	15,302	$	—		$	75,228
	Cost of revenues	17,348		—		—			17,348
	Gross margin	42,578		15,302		—			57,880
	Operation and maintenance	12,828		2,087		652			15,567
	General and administrative	—		—		8,669			8,669
	Other operating expenses	10,097		96		—			10,193
	Operating income	19,653		13,119		(9,321		)	23,451
	Interest expense, net of amounts capitalized	—		—		(766		)	(766		)
	Gain (loss) on interest rate swap	—		—		—			—
	Net income before tax	19,653		13,119		(10,087		)	22,685
	Income tax expense	—		—		553			553
	Net income (loss)	$	19,653	$	13,119	$	(10,640	)	$	22,132
	Year ended December 31, 2013
		Gathering &		Logistics		Corporate and			Marlin Midstream
	In Thousands	Processing				Consolidation			Partners, LP
	Total revenues	$	47,052	$	5,808	$	—		$	52,860
	Cost of revenues	13,999		—		—			13,999
	Gross margin	33,053		5,808		—			38,861
	Operation and maintenance	14,424		613		854			15,891
	General and administrative	—		—		7,886			7,886
	Other operating expenses	9,390		23		—			9,413
	Operating income	9,239		5,172		(8,740		)	5,671
	Interest expense, net of amounts capitalized	—		—		(4,349		)	(4,349		)
	Gain (loss) on interest rate swap	—		—		(48		)	(48		)
	Net income before tax	9,239		5,172		(13,137		)	1,274
	Income tax expense	—		—		88			88
	Net income (loss)	$	9,239	$	5,172	$	(13,225	)	$	1,186
	The following table presents financial information by segment at December 31, 2014 and 2013, respectively:
	Balance Sheet at December 31, 2014
	In Thousands	Gathering &		Logistics		Corporate and			Marlin Midstream
		Processing				Consolidation			Partners, LP
	Assets:
	Current assets	$	4,268	$	1,733	$	3,064		$	9,065
	Property, plant and equipment, net	161,389		769		—			162,158
	Other assets	163		—		452			615
	Total Assets	$	165,820	$	2,502	$	3,516		$	171,838
	Liabilities and Partners’ Capital
	Total current liabilities	$	1,323	$	132	$	4,085		$	5,540
	Total long-term liabilities	—		—		11,868			11,868
	Total Liabilities	1,323		132		15,953			17,408
	Partners’ Capital	164,497		2,370		(12,437		)	154,430
	Total Liabilities and Partners’ Capital	$	165,820	$	2,502	$	3,516		$	171,838
	Balance Sheet at December 31, 2013
	In Thousands	Gathering &		Logistics		Corporate and			Marlin Midstream
		Processing				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, 2014
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, 2014 is presented below:
		Number of shares		Weighted Average Grant-Date Fair Value
	Total Non-vested at January 1, 2014	312,000		$	20
	Granted	235,000		19.42
	Vested	(222,600	)	20
	Forfeited or canceled	(26,000	)	20
	Total Outstanding at December 31, 2014	298,400		$	19.54

SUPPLEMENTAL_QUARTERLY_FINANCI1

SUPPLEMENTAL QUARTERLY FINANCIAL DATA (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	Summarized quarterly financial data for the year ended December 31, 2014 is as follows:
		For the year ending December 31, 2014
	in thousands except volume and per unit amounts	Q1			Q2			Q3			Q4			TOTAL
	Revenues	$	18,818		$	22,445		$	17,219		$	16,746		$	75,228
	Cost of revenues	4,208			7,240			2,762			3,138			17,348
	Gross margin	14,610			15,205			14,457			13,608			57,880
	Operating expenses	4,316			4,000			3,637			3,614			15,567
	G&A expenses	2,497			2,036			1,729			2,407			8,669
	Other operating expenses	2,443			2,577			2,601			2,572			10,193
	Operating income	5,354			6,592			6,490			5,015			23,451
	Other income(expense)	(155		)	(182		)	(212		)	(217		)	(766		)
	Net income before income taxes	$	5,199		$	6,410		$	6,278		$	4,798		$	22,685
	Net income per limited partner common unit - basic (1)	$	0.28		$	0.35		$	0.33		$	0.25		$	1.23
	Net income per limited subordinated unit - basic (1)	$	0.29		$	0.36		$	0.33		$	0.25		$	1.22
	Net income per limited partner common unit - diluted (1)	$	0.28		$	0.35		$	0.33		$	0.25		$	1.21
	Net income per limited subordinated unit - diluted (1)	$	0.29		$	0.36		$	0.33		$	0.25		$	1.22
	Weighted average limited partner units outstanding - basic	17,601,902			17,602,034			17,673,561			17,703,793			17,626,840
	Weighted average limited partner units outstanding - diluted	17,711,652			17,711,652			17,771,140			17,837,813			17,751,279
		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 income taxes	$	(3,924	)	$	(1,193	)	$	1,933		$	4,458		$	1,274
	Net income per limited partner unit - basic (1)							$	0.16		$	0.24		$	0.4
	Net income per limited partner unit - diluted (1)							$	0.15		$	0.24		$	0.39
	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
	(1) The sum of the quarterly net income per limited partner unit (basic and diluted) may not agree to the net income per limited partner unit for the year due to the timing of limited partner unit issuances.
Adjusted quarterly EBITDA	Adjusted quarterly EBITDA for the years ended December 31, 2014 and 2013 is as follows:
		For the year ending December 31, 2014
		Q1		Q2		Q3		Q4		Total
	Net income (loss)	5,130		6,342		6,140		4,520		22,132
	Interest expense, net of amounts capitalized	155		182		212		217		766
	Income tax expense	69		68		138		278		553
	Equity-based compensation	1,246		222		53		442		1,963
	Depreciation expense	2,144		2,186		2,238		2,249		8,817
	Adjusted EBITDA	8,744		9,000		8,781		7,706		34,231
		For the year ending December 31, 2013
		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
	Income 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_Schedule_of_Commo

ORGANIZATION - Schedule of Common, Subordinate, and General Partner Units (Details)	0 Months Ended		12 Months Ended	5 Months Ended
	Aug. 01, 2014	Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013
Limited Partners' Capital Account [Line Items]
General partner units		356,104	357,935	356,104
General partner ownership interest	2.00%	2.00%	2.00%
Partners' Capital Account, Units		17,805,194
Total Ownership Percentage		100.00%
Units Held By NuDevco
Limited Partners' Capital Account [Line Items]
Subordinted untis held by NuDevco, Percentage of ownership			100.00%	100.00%
General partner ownership interest			2.00%	2.00%
Common Units
Limited Partners' Capital Account [Line Items]
Limited partner's capital, units outstanding			8,979,248	8,724,545
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%	11.00%	10.00%
Subordinted untis held by NuDevco, Percentage of ownership			22.00%	21.00%
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%
Subordinate Units | Units Held By NuDevco
Limited Partners' Capital Account [Line Items]
Limited partner's, Ownership percentage			48.00%	49.00%
Subordinated units held by NuDevco		8,724,545
Subordinted untis held by NuDevco, Percentage of ownership		49.00%	100.00%	100.00%

ORGANIZATION_Schedule_of_FeeBa

ORGANIZATION - Schedule of Fee-Based Commercial Agreements (Details)	0 Months Ended
	Jul. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Supply Commitment, Term	3 years

ORGANIZATION_TextualInitial_Pu

ORGANIZATION - Textual-Initial Public Offering (Details) (USD $)	0 Months Ended		12 Months Ended
In Millions, except Share data, unless otherwise specified	Aug. 01, 2014	Jul. 31, 2013	Dec. 31, 2014
Line of Credit Facility [Line Items]
Common units sold in IPO, price per unit		$20
Underwriting discount per share		$1.20
General partner ownership interest	2.00%	2.00%	2.00%
Percentage of quarterly distributions of available cash from operating surplus for distributions		23.00%	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
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%	13.00%
Maximum
Line of Credit Facility [Line Items]
Percentage of quarterly distributions of available cash from operating surplus for distributions		48.00%	48.00%

ORGANIZATION_TextualCredit_Fac

ORGANIZATION Textual-Credit Facility (Details) (USD $)	0 Months Ended
	Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2012
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	25,000,000	$11,000,000	$1,500,000
Minimum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of credit facility, covenant, interest coverage ratio	2.5
Maximum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Line of credit facility, covenant, senior secured leverage ratio	4
Eurodollar | Minimum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	3.00%
Eurodollar | Maximum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	3.75%
Alternate Base Rate | Minimum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Alternate Base Rate | Maximum | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	2.75%
Alternate Base Rate - Federal Funds Rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	0.50%
Alternate Base Rate - Federal Funds Rate | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	0.50%
Alternate Base Rate - Eurodollar Rate
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	1.00%
Alternate Base Rate - Eurodollar Rate | Revolving Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	1.00%

ORGANIZATION_TextualOther_Tran

ORGANIZATION - Textual-Other Transactions (Details) (USD $)	0 Months Ended		12 Months Ended	5 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Aug. 01, 2014	Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Jul. 31, 2013
Limited Partners' Capital Account [Line Items]
General partner ownership interest	2.00%	2.00%	2.00%
Common Units
Limited Partners' Capital Account [Line Items]
Limited partner's capital, units outstanding			8,979,248	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			8,724,545
Subordinted untis held by NuDevco, Percentage of ownership		49.00%
Units Held By NuDevco
Limited Partners' Capital Account [Line Items]
General partner ownership interest			2.00%	2.00%
Subordinted untis held by NuDevco, Percentage of ownership			100.00%	100.00%
Units Held By NuDevco | Common Units
Limited Partners' Capital Account [Line Items]
Limited partner's capital, units outstanding		1,849,545			1,849,545
Subordinted untis held by NuDevco, Percentage of ownership			22.00%	21.00%
Units Held By NuDevco | Subordinate Units
Limited Partners' Capital Account [Line Items]
Subordinated units held by NuDevco		8,724,545			8,724,545
Subordinted untis held by NuDevco, Percentage of ownership		49.00%	100.00%	100.00%
Release of Accounts Payable Obligation
Limited Partners' Capital Account [Line Items]
Amounts of related party transaction		11.7
Processing Facility | Monell, Wyoming | Collaborative Arrangement
Limited Partners' Capital Account [Line Items]
Investment in Joint Venture, Interest Percentage					50.00%

BASIS_OF_PRESENTATION_AND_ACCO2

BASIS OF PRESENTATION AND ACCOUNTING POLICIES - Textual (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 05, 2014

Aug. 01, 2013

Aug. 01, 2014

segment

Related Party Transaction [Line Items]

Percentage of interests acquired

100.00%

Accounts receivable written off

$0

$0

Capitalized interest

45,000

232,000

214,000

Property, plant and equipment, scheduled maintenance frequency

5 years

Asset impairment charges

0

0

Number of operating segments

2

Imbalance receivables

0

100,000

0

100,000

Income tax expense

278,000

138,000

68,000

69,000

53,000

11,000

13,000

11,000

553,000

88,000

101,000

Unrecognized Tax Benefits

0

0

Allocation percentage of net income related to acquisition from affiliates under common control prior to acquisition

100.00%

Long Term Incentive Plan | Phantom Share Units (PSUs)

Related Party Transaction [Line Items]

Units awarded (in shares)

235,000

Employee of related party | Long Term Incentive Plan | Phantom Share Units (PSUs)

Related Party Transaction [Line Items]

Units awarded (in shares)

215,000

292,000

Board members | Long Term Incentive Plan | Phantom Share Units (PSUs)

Related Party Transaction [Line Items]

Units awarded (in shares)

20,000

20,000

Minimum

Related Party Transaction [Line Items]

Property, plant and equipment, Estimated useful lives

5 years

Maximum

Related Party Transaction [Line Items]

Property, plant and equipment, Estimated useful lives

40 years

Management Services | Principal Owner

Related Party Transaction [Line Items]

Amount of annual fee for executive management services

$600,000

PARTNERSHIP_EQUITY_AND_DISTRIB2

PARTNERSHIP EQUITY AND DISTRIBUTIONS Textual (Details) (USD $)	0 Months Ended		2 Months Ended	3 Months Ended						12 Months Ended	5 Months Ended
	Aug. 01, 2014	Jul. 31, 2013	Sep. 30, 2013	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2014	Dec. 31, 2013
				Period						Period
				Quarter						Quarter
Limited Partners' Capital Account [Line Items]
General partner ownership interest	2.00%	2.00%								2.00%
Maximum number of days after quarter-end to distribute all available cash to unitholders										45 days
Percentage of quarterly distributions of available cash from operating surplus for distributions		23.00%								23.00%
Quarterly distribution per unit			$0.35	$0.37	$0.37	$0.36	$0.36	$0.35	$0.23	$0.35
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
Minimum
Limited Partners' Capital Account [Line Items]
Percentage of quarterly distributions of available cash from operating surplus for distributions		13.00%								13.00%
Maximum
Limited Partners' Capital Account [Line Items]
Percentage of quarterly distributions of available cash from operating surplus for distributions		48.00%								48.00%
Units Held By NuDevco
Limited Partners' Capital Account [Line Items]
Subordinted untis held by NuDevco, Percentage of ownership										100.00%	100.00%
General partner ownership interest										2.00%	2.00%
Common Units
Limited Partners' Capital Account [Line Items]
Limited partner's capital, units outstanding				8,979,248				8,724,545		8,979,248	8,724,545
Common Units | Units Held By NuDevco
Limited Partners' Capital Account [Line Items]
Limited partner's capital, units outstanding		1,849,545
Subordinted untis held by NuDevco, Percentage of ownership										22.00%	21.00%
Limited partner's, Ownership percentage		10.40%								11.00%	10.00%
Subordinate Units
Limited Partners' Capital Account [Line Items]
Limited partner's capital, units outstanding				8,724,545				8,724,545		8,724,545	8,724,545
Subordinted untis held by NuDevco, Percentage of ownership		49.00%
Subordinate Units | Units Held By NuDevco
Limited Partners' Capital Account [Line Items]
Subordinted untis held by NuDevco, Percentage of ownership		49.00%								100.00%	100.00%
Limited partner's, Ownership percentage										48.00%	49.00%

PARTNERSHIP_EQUITY_AND_DISTRIB3

PARTNERSHIP EQUITY AND DISTRIBUTIONS Schedule of Cash Distributions to Unitholders (Details) (USD $)	2 Months Ended	3 Months Ended						12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2014
Equity [Abstract]
Quarterly distribution per unit	$0.35	$0.37	$0.37	$0.36	$0.36	$0.35	$0.23	$0.35
Distribution Made to Unitholders, Cash Distributions Declared		$6,593	$6,593	$6,469	$6,375	$6,232	$4,095
Distribution Made to Unitholders, Distribution Date		11-Feb-15	4-Nov-14	5-Aug-14	6-May-14	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, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013		Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Net income (loss)	$4,520	$6,140	$6,342	$5,130	$4,405	$1,922	($1,206)	($3,935)	$7,190	[1]	($6,003)	$22,132	$1,186	($4,306)
Less: Allocation of East New Mexico Dropdown net income prior to acquisition (see Note 5)									0			-160
Less: general partner interest in net income									-144			-435
Limited partner interest in net income									7,046			21,537
Net income per limited partner unit - basic (in dollars per share)					$0.24	$0.16			$0.40				$0.40
Net income per limited partner unit - diluted (in dollars per share)					$0.24	$0.15			$0.40			$1.21	$0.39
Weighted average limited partner units outstanding - basic	17,703,793	17,673,561	17,602,034	17,601,902	17,449,090	17,449,090			17,449,090			17,626,840	17,449,090
Weighted average limited partner units outstanding - diluted	17,837,813	17,771,140	17,711,652	17,711,652	17,761,090	17,761,090			17,761,090			17,751,279	17,761,090
Common Units
Limited partner interest in net income									3,523			10,923
Net income per limited partner unit - basic (in dollars per share)	$0.25	$0.33	$0.35	$0.28					$0.40			$1.23
Net income per limited partner unit - diluted (in dollars per share)	$0.25	$0.33	$0.35	$0.28					$0.39			$1.21
Weighted average limited partner units outstanding - basic									8,724,545			8,902,295
Weighted average limited partner units outstanding - diluted									9,036,545			9,026,734
Subordinate Units
Limited partner interest in net income									$3,523			$10,614
Net income per limited partner unit - basic (in dollars per share)	$0.25	$0.33	$0.36	$0.29					$0.40			$1.22
Net income per limited partner unit - diluted (in dollars per share)	$0.25	$0.33	$0.36	$0.29					$0.40			$1.22
Weighted average limited partner units outstanding - basic									8,724,545			8,724,545
Weighted average limited partner units outstanding - diluted									8,724,545			8,724,545
[1]	Post-IPO, August 1, 2013 to December 31, 2013 for the year ended December 31, 2013.

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, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$205,845	$197,435
Accumulated depreciation	-43,687	-34,887
Property, plant and equipment, net	162,158	162,548
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	136,638	133,859
Gas processing plants | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, Estimated useful lives	5 years
Gas processing plants | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, Estimated useful lives	40 years
Gathering pipelines and related equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	52,591	47,728
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	11,818	11,043
Construction-in-progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	1,955	2,594
Information technology and other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,065	1,548
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	$472	$357
Property, plant and equipment, Estimated useful lives	5 years

PROPERTY_PLANT_AND_EQUIPMENT_T1

PROPERTY, PLANT AND EQUIPMENT Textual (Details) (USD $)	0 Months Ended		3 Months Ended								5 Months Ended	12 Months Ended			1 Months Ended
	Aug. 01, 2014	Jul. 31, 2013	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jul. 31, 2014	Jul. 31, 2013
Property, Plant and Equipment [Line Items]
Natural gas, NGLs and condensate revenue												$13,569,000	$15,792,000	$34,708,000
Operation and maintenance												15,567,000	15,891,000
Depreciation expense			2,249,000	2,238,000	2,186,000	2,144,000	2,105,000	2,058,000	2,050,000	1,984,000		8,817,000	8,197,000	7,689,000
Issuance of common units for assets acquired from affiliate (Note 5)												257,000	0	0
Proceeds from issuance of general partner units												-38,000	0	0
General partner ownership interest	2.00%	2.00%										2.00%
Less: Allocation of East New Mexico Dropdown net income prior to acquisition (see Note 5)											0	-160,000
East New Mexico Transloading Facility
Property, Plant and Equipment [Line Items]
Business Combination, Consideration Transferred	7,400,000
Payments to Acquire Businesses, Gross	5,500,000
Issuance of common units for assets acquired from affiliate (Note 5)	300,000
Number of skid transloaders acquired	1
Proceeds from issuance of general partner units	38,000
Less: Allocation of East New Mexico Dropdown net income prior to acquisition (see Note 5)															200,000
East New Mexico Transloading Facility | Common Units
Property, Plant and Equipment [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	89,720
Transloading services agreement | Affiliated Entity
Property, Plant and Equipment [Line Items]
Length of period of related party agreement		3 years
Transloading services agreement | AES | East New Mexico Transloading Facility
Property, Plant and Equipment [Line Items]
Length of period of related party agreement	3 years
Natural gas and liquid transportation pipelines
Property, Plant and Equipment [Line Items]
Number of facilities			2									2
Panola County, Texas | Natural gas processing
Property, Plant and Equipment [Line Items]
Number of facilities			2									2
Panola County, Texas | Natural gas gathering
Property, Plant and Equipment [Line Items]
Number of facilities			2									2
Tyler County, Texas | Natural gas processing
Property, Plant and Equipment [Line Items]
Number of facilities			1									1
Monell, Wyoming | Processing Facility | Collaborative Arrangement
Property, Plant and Equipment [Line Items]
Percentage interest in processing facility																50.00%
Natural gas, NGLs and condensate revenue												200,000	1,200,000
Operation and maintenance												300,000	400,000
Monell, Wyoming | Processing Facility | Collaborative Arrangement | Affiliated Entity
Property, Plant and Equipment [Line Items]
Property, plant and equipment transferred out		-3,200,000

LONGTERM_DEBT_AND_INTEREST_EXP2

LONG-TERM DEBT AND INTEREST EXPENSE Long-term Debt (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
Total debt	$11,000	$4,000	$126,500
Revolving Credit Facility
Debt Instrument [Line Items]
Total debt	$11,000	$4,000

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, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Debt Disclosure [Abstract]
Interest expense on long-term debt									$526	$3,312	$4,599
Interest expense from amortization of deferred financing costs									285	508	365
Interest expense from write-off of unamortized deferred financing costs									0	761	177
Less interest expense capitalized									-45	-232	-214
Total interest expense, net of amounts capitalized	$217	$212	$182	$155	$178	$1,382	$1,426	$1,363	$766	$4,349	$4,927

LONGTERM_DEBT_AND_INTEREST_EXP4

LONG-TERM DEBT AND INTEREST EXPENSE Textual (Details) (USD $)	0 Months Ended	12 Months Ended			0 Months Ended	1 Months Ended
	Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 17, 2012	Dec. 31, 2012	30-May-08	Jan. 24, 2011	Dec. 31, 2011
Debt Instrument [Line Items]
Proceeds from the term loan and the revolving credit facility		$11,000,000	$4,000,000	$126,500,000		$126,500,000
Repayment of credit facility	131,900,000
Senior secured leverage ratio (not more than)		4
Consolidated interest coverage ratio (not less than)		2.5
Deferred finance costs		700,000	1,000,000
Deferred finance costs included in current assets		300,000	300,000
Deferred finance costs included in other assets		400,000	700,000
Amortization of deferred financing costs		285,000	1,269,000	542,000
Financing costs paid		0	1,141,000	932,000
Alternate Base Rate - Federal Funds Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	0.50%
Alternate Base Rate - Eurodollar Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.00%
Term Loan
Debt Instrument [Line Items]
Repayment of credit facility	121,900,000
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity	50,000,000
Proceeds from the term loan and the revolving credit facility		11,000,000	4,000,000
Amount outstanding	25,000,000	11,000,000		1,500,000		1,500,000
Debt Instrument, Interest Rate, Effective Percentage				3.96%		3.96%
Unused capacity, commitment fee percentage					0.50%
Maximum borrowing capacity, in case of non-default	150,000,000
Repayment of credit facility	10,000,000
Revolving Credit Facility | Eurodollar | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	3.00%
Revolving Credit Facility | Eurodollar | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	3.75%
Revolving Credit Facility | Alternate Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Revolving Credit Facility | Alternate Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	2.75%
Revolving Credit Facility | Alternate Base Rate - Federal Funds Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	0.50%
Revolving Credit Facility | Alternate Base Rate - Eurodollar Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate	1.00%
Interest Expense
Debt Instrument [Line Items]
Amortization of deferred financing costs		300,000	500,000	400,000
Amended Credit Agreement | Working Capital Facility
Debt Instrument [Line Items]
Maximum borrowing capacity							177,500,000
Amended Credit Agreement | Term Loan
Debt Instrument [Line Items]
Maximum borrowing capacity							100,000,000
Amended Credit Agreement | Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity							35,000,000
Fifth Amended Credit Agreement | Working Capital Facility
Debt Instrument [Line Items]
Maximum borrowing capacity								150,000,000
Fifth Amended Credit Agreement | Term Loan
Debt Instrument [Line Items]
Maximum borrowing capacity								130,000,000	130,000,000
Fifth Amended Credit Agreement | Interest Expense
Debt Instrument [Line Items]
Financing costs expensed						200,000
Sixth Amended Credit Agreement
Debt Instrument [Line Items]
Capitalized finance costs				900,000		900,000
Sixth Amended Credit Agreement | Working Capital Facility
Debt Instrument [Line Items]
Maximum borrowing capacity					70,000,000
Sixth Amended Credit Agreement | Term Loan
Debt Instrument [Line Items]
Maximum borrowing capacity					125,000,000
Amount outstanding				125,000,000		125,000,000
Credit facility, quarterly principal payments till maturity		1,600,000
Credit facility, balance due on maturity		112,500,000
Debt Instrument, Interest Rate, Effective Percentage				3.96%		3.96%
Sixth Amended Credit Agreement | Term Loan | Eurodollar | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		3.50%
Sixth Amended Credit Agreement | Term Loan | Eurodollar | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		4.25%
Sixth Amended Credit Agreement | Term Loan | Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		2.50%
Sixth Amended Credit Agreement | Term Loan | Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		3.25%
Sixth Amended Credit Agreement | Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity					30,000,000
Financing costs paid	1,100,000					1,000,000
Sixth Amended Credit Agreement | Interest Expense
Debt Instrument [Line Items]
Financing costs expensed	800,000
Sixth Amended Credit Agreement | General and Administrative Expense
Debt Instrument [Line Items]
Financing costs expensed						$100,000

DERIVATIVE_FINANCIAL_INSTRUMEN2

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, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on interest rate swap	$0	($48)	($938)
Option contract | Naturgal gas contract | Cost of revenues - affiliates
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on interest rate swap	0	0	-87
Swap contract | Interest rate contract | Gain (loss) on interest rate swap
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on interest rate swap	$0	($48)	($851)

DERIVATIVE_FINANCIAL_INSTRUMEN3

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, 2014	Dec. 31, 2013	Dec. 31, 2012
Cost of revenues - affiliates
Derivative Instruments, Gain (Loss) [Line Items]
Gain reclassified from accumulated other comprehensive income to income	$0	$0	($752)
Accumulated other comprehensive income
Derivative Instruments, Gain (Loss) [Line Items]
Gain recognized in accumulated other comprehensive income	$0	$0	$689

DERIVATIVE_FINANCIAL_INSTRUMEN4

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, 2014	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_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS Textual (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Fair Value Disclosures [Abstract]
Financial instruments owned	$0	$0

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, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013		Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
												segment
Segment Reporting Information [Line Items]
Number of operating segments												2
Total Revenues	$16,746	$17,219	$22,445	$18,818	$16,108	$18,950	$10,298	$7,504				$75,228	$52,860	$51,049
Cost of revenues	3,138	2,762	7,240	4,208	2,312	6,479	2,680	2,528				17,348	13,999
Gross margin	13,608	14,457	15,205	14,610	13,796	12,471	7,618	4,976				57,880	38,861
Operation and maintenance												15,567	15,891
General and administrative	2,407	1,729	2,036	2,497	2,672	2,482	1,321	1,411				8,669	7,886
Other operating expenses	2,572	2,601	2,577	2,443	2,476	2,349	2,369	2,219				10,193	9,413
Operating income	5,015	6,490	6,592	5,354	4,636	3,357	228	-2,550				23,451	5,671	1,550
Interest expense, net of amounts capitalized	-217	-212	-182	-155	-178	-1,382	-1,426	-1,363				-766	-4,349	-4,927
Gain (loss) on interest rate swap					0	-43	5	-10				0	-48	-851
Net income before tax	4,798	6,278	6,410	5,199	4,458	1,933	-1,193	-3,924				22,685	1,274	-4,205
Income tax expense	278	138	68	69	53	11	13	11				553	88	101
Net income (loss)	4,520	6,140	6,342	5,130	4,405	1,922	-1,206	-3,935	7,190	[1]	-6,003	22,132	1,186	-4,306
Assets:
Current assets	9,065				10,694				10,694			9,065	10,694
Property, plant and equipment, net	162,158				162,548				162,548			162,158	162,548
Other assets	615				900				900			615	900
Total Assets	171,838				174,142				174,142			171,838	174,142
Liabilities and Partners’ Capital
Total current liabilities	5,540				9,226				9,226			5,540	9,226
Total long-term liabilities	11,868				4,366				4,366			11,868	4,366
Total liabilities	17,408				13,592				13,592			17,408	13,592
Partners’ Capital	154,430				160,550				160,550			154,430	160,550
Total Liabilities and Partners’ Capital	171,838				174,142				174,142			171,838	174,142
Gathering and Processing
Segment Reporting Information [Line Items]
Total Revenues												59,926	47,052
Cost of revenues												17,348	13,999
Gross margin												42,578	33,053
Operation and maintenance												12,828	14,424
General and administrative												0	0
Other operating expenses												10,097	9,390
Operating income												19,653	9,239
Interest expense, net of amounts capitalized												0	0
Gain (loss) on interest rate swap												0	0
Net income before tax												19,653	9,239
Income tax expense												0	0
Net income (loss)												19,653	9,239
Assets:
Current assets	4,268				5,727				5,727			4,268	5,727
Property, plant and equipment, net	161,389				162,029				162,029			161,389	162,029
Other assets	163				163				163			163	163
Total Assets	165,820				167,919				167,919			165,820	167,919
Liabilities and Partners’ Capital
Total current liabilities	1,323				2,796				2,796			1,323	2,796
Total long-term liabilities	0				0				0			0	0
Total liabilities	1,323				2,796				2,796			1,323	2,796
Partners’ Capital	164,497				165,123				165,123			164,497	165,123
Total Liabilities and Partners’ Capital	165,820				167,919				167,919			165,820	167,919
Crude Oil Logistics
Segment Reporting Information [Line Items]
Total Revenues												15,302	5,808
Cost of revenues												0	0
Gross margin												15,302	5,808
Operation and maintenance												2,087	613
General and administrative												0	0
Other operating expenses												96	23
Operating income												13,119	5,172
Interest expense, net of amounts capitalized												0	0
Gain (loss) on interest rate swap												0	0
Net income before tax												13,119	5,172
Income tax expense												0	0
Net income (loss)												13,119	5,172
Assets:
Current assets	1,733				1,195				1,195			1,733	1,195
Property, plant and equipment, net	769				519				519			769	519
Other assets	0				0				0			0	0
Total Assets	2,502				1,714				1,714			2,502	1,714
Liabilities and Partners’ Capital
Total current liabilities	132				353				353			132	353
Total long-term liabilities	0				0				0			0	0
Total liabilities	132				353				353			132	353
Partners’ Capital	2,370				1,361				1,361			2,370	1,361
Total Liabilities and Partners’ Capital	2,502				1,714				1,714			2,502	1,714
Corporate and Consolidation
Segment Reporting Information [Line Items]
Total Revenues												0	0
Cost of revenues												0	0
Gross margin												0	0
Operation and maintenance												652	854
General and administrative												8,669	7,886
Other operating expenses												0	0
Operating income												-9,321	-8,740
Interest expense, net of amounts capitalized												-766	-4,349
Gain (loss) on interest rate swap												0	-48
Net income before tax												-10,087	-13,137
Income tax expense												553
Net income (loss)												-10,640	-13,225
Assets:
Current assets	3,064				3,772				3,772			3,064	3,772
Property, plant and equipment, net	0				0				0			0	0
Other assets	452				737				737			452	737
Total Assets	3,516				4,509				4,509			3,516	4,509
Liabilities and Partners’ Capital
Total current liabilities	4,085				6,077				6,077			4,085	6,077
Total long-term liabilities	11,868				4,366				4,366			11,868	4,366
Total liabilities	15,953				10,443				10,443			15,953	10,443
Partners’ Capital	-12,437				-5,934				-5,934			-12,437	-5,934
Total Liabilities and Partners’ Capital	$3,516				$4,509				$4,509			$3,516	$4,509
[1]	Post-IPO, August 1, 2013 to December 31, 2013 for the year ended December 31, 2013.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES Textual - Supply Commitment (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	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, maximum fee obligation	$2,200,000
Inventory delivery supply commitment, deficiency fee payable	$900,000	$500,000	$0
Supply Commitment
Supply Commitment [Line Items]
Inventory delivery commitment, reserve capacity, per day (bbl)	3,500

TRANSACTIONS_WITH_AFFILIATES_D

TRANSACTIONS WITH AFFILIATES (Details) (USD $)	7 Months Ended	12 Months Ended			0 Months Ended
	Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 28, 2013	Jul. 31, 2013
Related Party Transaction [Line Items]
Accounts receivable—affiliates		$3,963,000	$3,632,000
Accounts Payable, Related Parties		1,438,000
Accounts payable—affiliates		1,438,000	1,552,000
Cost of natural gas, NGLs and condensate revenue—affiliates		12,558,000	5,515,000	7,668,000
Gathering, processing, transloading and other revenue—affiliates		38,024,000	13,015,000	254,000
Operation and maintenance—affiliates		6,668,000	3,490,000	793,000
General and administrative—affiliates		5,067,000	4,187,000	1,021,000
Capital contributions	3,574,000			4,374,000
SEV
Related Party Transaction [Line Items]
Cost of natural gas, NGLs and condensate revenue—affiliates			3,000,000	7,700,000
Principal Owner | Management Services
Related Party Transaction [Line Items]
Amounts of related party transaction		600,000
Gas transportation agreement | SEV
Related Party Transaction [Line Items]
Extension Period of current transportation agreement					3 years
Gathering, processing, transloading and other revenue—affiliates				300,000
Fee-based commercial agreement | SEV
Related Party Transaction [Line Items]
Cost of natural gas, NGLs and condensate revenue—affiliates		12,600,000	2,500,000
Gathering, processing, transloading and other revenue—affiliates		22,700,000	7,200,000
Length of period of related party agreement						3 years
Transloading services agreement | SEV
Related Party Transaction [Line Items]
Gathering, processing, transloading and other revenue—affiliates		15,300,000	5,800,000
Length of period of related party agreement						3 years
Maximum | Gas transportation agreement | SEV
Related Party Transaction [Line Items]
Gathering, processing, transloading and other revenue—affiliates		$100,000	$100,000
Minimum | Fee-based commercial agreement | SEV
Related Party Transaction [Line Items]
Monthly volume commitment in service agreement						100

EQUITY_BASED_COMPENSATION_Deta

EQUITY BASED COMPENSATION (Details) (USD $)	12 Months Ended	0 Months Ended		12 Months Ended
	Dec. 31, 2014	Dec. 05, 2014	Aug. 01, 2013	Dec. 31, 2013	Dec. 31, 2012
	Installment
Long Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of common units issuable	1,750,000
Long Term Incentive Plan | Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of annual vesting installment	5
Liability recorded for distributions associated with unvested grants	$48,000			$32,000
Number of Shares
Total Non-vested at January 1, 2014	312,000
Granted	235,000
Vested	-222,600
Forfeited or canceled	-26,000
Total Outstanding at December 31, 2014	298,400
Weighted Average Grant-Date Fair Value (usd per share)
Total Non-vested at January 1, 2014	$20
Granted	$19.42
Vested	$20
Forfeited or canceled	$20
Total Outstanding at December 31, 2014	$19.54
Unrecognized compensation expense associated with the unvested phantom units	4,500,000
Nonvested awards, compensation cost not yet recognized, period for recognition	2 years 6 months
Employee of related party | Long Term Incentive Plan | Phantom Share Units (PSUs)
Number of Shares
Granted		215,000	292,000
Board members | Long Term Incentive Plan | Phantom Share Units (PSUs)
Number of Shares
Granted		20,000	20,000
General and Administrative Expense - Affiliate
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated share based compensation expense	1,300,000			2,100,000	0
Operation and Maintenance - Affiliates
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated share based compensation expense	$700,000			$900,000	$0

CONCENTRATIONS_OF_CREDIT_RISK_

CONCENTRATIONS OF CREDIT RISK (Details) (Customer Concentration Risk)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
		Customer
Two third-party customers | Minimum
Concentration Risk [Line Items]
Contractual arrangements remaining terms	1 year
Two third-party customers | Maximum
Concentration Risk [Line Items]
Contractual arrangements remaining terms	5 years
Revenues
Concentration Risk [Line Items]
Concentration risk, number of third-party customer	2	2
Concentration risk, number of affiliate customer	1
Revenues | Two third-party customer and one affiliate customer
Concentration Risk [Line Items]
Concentration risk, percentage	98.00%
Revenues | Two third-party customers
Concentration Risk [Line Items]
Concentration risk, percentage			93.00%

INCOME_TAX_Details

INCOME TAX (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Contingency [Line Items]
Deferred income tax	$399	$75
Texas Margin Tax
Income Tax Contingency [Line Items]
Current State and Local Tax Expense (Benefit)	200	88	101
Deferred income tax	$400

SUBSEQUENT_EVENTS_First_Quarte

SUBSEQUENT EVENTS - First Quarter 2014 Distribution (Details) (Subsequent Event, USD $)	0 Months Ended
	Jan. 23, 2015
Cash Distribution - Quarterly [Member]
Subsequent Event [Line Items]
Cash distribution per unit (in dollars per share)	$0.37
Cash Distribution - Annualized [Member]
Subsequent Event [Line Items]
Cash distribution per unit (in dollars per share)	$1.46

SUBSEQUENT_EVENTS_Sale_of_Gene

SUBSEQUENT EVENTS - Sale of General Partner Interest and Contribution of the Legacy Gathering System (Details) (USD $)	0 Months Ended
In Millions, except Share data, unless otherwise specified	Feb. 27, 2015	Aug. 01, 2014
Subsequent Event [Line Items]
Percentage of interests acquired		100.00%
Subsequent Event
Subsequent Event [Line Items]
Payments for redemption of IDR units	$63
Payments to acquire business, gross	99.5
Subsequent Event | IDRH [Member]
Subsequent Event [Line Items]
Number of IDR Units redeemed	90
Payments for redemption of IDR units	63
Subsequent Event | Azure
Subsequent Event [Line Items]
Percent of incentive distribution rights acquired	90.00%
Subsequent Event | Azure | NuDevco [Member]
Subsequent Event [Line Items]
Payments to acquire GP interests	7
Purchase of GP interests, option to acquire common and subordinated units held by NuDevco, percent of units	20.00%
Subsequent Event | IDRH [Member]
Subsequent Event [Line Items]
Number of IDR units recapitalized	100
Subsequent Event | General Partner | Azure
Subsequent Event [Line Items]
Percentage of interests acquired	100.00%
Subsequent Event | Legacy System [Member]
Subsequent Event [Line Items]
Payments to acquire business, net	92.5
Aggregate consideration transferred	162.5
Payments to acquire business, gross	$99.50
Distance of high and low pressure gathering lines	658
Subsequent Event | Legacy System [Member] | Cotton Valley and Haynesville Shale in East Texas and Northern Louisiana [Member]
Subsequent Event [Line Items]
Area of land	100,000
Subsequent Event | Legacy System [Member] | Incentive Distribution Rights [Member]
Subsequent Event [Line Items]
Number of units issued	90

SUBSEQUENT_EVENTS_New_Senior_S

SUBSEQUENT EVENTS - New Senior Secured Revolving Credit Facility (Details) (USD $)	0 Months Ended
	Feb. 27, 2015	Dec. 31, 2014	Jul. 31, 2013	Dec. 31, 2012
Revolving Credit Facility
Subsequent Event [Line Items]
Maximum borrowing capacity			$50,000,000
Amount outstanding		11,000,000	25,000,000	1,500,000
Subsequent Event
Subsequent Event [Line Items]
Payments to acquire business, gross	99,500,000
Payments for redemption of IDR units	63,000,000
Repayment of existing senior secured revolving credit facility	15,000,000
Subsequent Event | Revolving Credit Facility
Subsequent Event [Line Items]
Maximum borrowing capacity	250,000,000
Amount outstanding	180,800,000
Payments for fees and expenses associated with the Senior Credit Facility	3,300,000
Minimum proceeds from single issuance of common equity required to lift restrictions on current borrowing capacity	50,000,000
Minimum prepayment of loans under the Senior Credit Facility required to lift restrictions on current borrowing capacity	50,000,000
Calculation of current borrowing capacity, multiplier	4.5
Calculation of current borrowing capacity, amount	15,000,000
Maximum distributions of Available Cash if Availability deficiency exists	10,000,000
Maximum Consolidated Funded Indebtedness to Adjusted Consolidated EBITDA ratio during trailing four fiscal quarter period	4.5
Maximum Consolidated Funded Indebtedness to Adjusted Consolidated EBITDA ratio during two fiscal quarters following the date of acquisition	5
Minimum Adjusted Consolidated EBITDA to Consolidated Interest Expense during trailing four fiscal quarters	2.5
Subsequent Event | Revolving Credit Facility | LIBOR | Minimum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate	2.75%
Subsequent Event | Revolving Credit Facility | LIBOR | Maximum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate	3.75%
Subsequent Event | Revolving Credit Facility | Base Rate | Minimum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate	1.75%
Subsequent Event | Revolving Credit Facility | Base Rate | Maximum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate	2.75%
Subsequent Event | Letter of Credit [Member]
Subsequent Event [Line Items]
Maximum borrowing capacity	15,000,000
Subsequent Event | Swingline Loans [Member]
Subsequent Event [Line Items]
Maximum borrowing capacity	$15,000,000

SUBSEQUENT_EVENTS_Omnibus_Agre

SUBSEQUENT EVENTS - Omnibus Agreement and Transloading Services Agreement (Details) (Subsequent Event)	0 Months Ended
	Feb. 27, 2015
Subsequent Event
Subsequent Event [Line Items]
Notice period for temporarily or permanently excluding any particular Service from the scope of the New Omnibus Agreement	90 days
Extension period for volume commitments	5 years

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, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2013		Jul. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues	$16,746	$17,219	$22,445	$18,818	$16,108	$18,950	$10,298	$7,504				$75,228	$52,860	$51,049
Cost of revenues	3,138	2,762	7,240	4,208	2,312	6,479	2,680	2,528				17,348	13,999
Gross margin	13,608	14,457	15,205	14,610	13,796	12,471	7,618	4,976				57,880	38,861
Operating expenses	3,614	3,637	4,000	4,316	4,012	4,283	3,700	3,896				15,567	15,891
G&A expenses	2,407	1,729	2,036	2,497	2,672	2,482	1,321	1,411				8,669	7,886
Other operating expenses	2,572	2,601	2,577	2,443	2,476	2,349	2,369	2,219				10,193	9,413
Operating income	5,015	6,490	6,592	5,354	4,636	3,357	228	-2,550				23,451	5,671	1,550
Other income(expense)	-217	-212	-182	-155	-178	-1,424	-1,421	-1,374				-766	-4,397
Net income (loss) before tax	4,798	6,278	6,410	5,199	4,458	1,933	-1,193	-3,924				22,685	1,274	-4,205
Net income per limited partner unit or limited subordinated unit - basic (in dollars per share)					$0.24	$0.16			$0.40				$0.40
Net income per limited partner common unit or limited subordinated unit - diluted (in dollars per share)					$0.24	$0.15			$0.40			$1.21	$0.39
Weighted average limited partner units outstanding - basic	17,703,793	17,673,561	17,602,034	17,601,902	17,449,090	17,449,090			17,449,090			17,626,840	17,449,090
Weighted average limited partner units outstanding - diluted	17,837,813	17,771,140	17,711,652	17,711,652	17,761,090	17,761,090			17,761,090			17,751,279	17,761,090
Net income (loss)	4,520	6,140	6,342	5,130	4,405	1,922	-1,206	-3,935	7,190	[1]	-6,003	22,132	1,186	-4,306
Total interest expense, net of amounts capitalized	217	212	182	155	178	1,382	1,426	1,363				766	4,349	4,927
Income tax expense	278	138	68	69	53	11	13	11				553	88	101
Equity-based compensation	442	53	222	1,246	1,728	1,284	0	0				1,963	3,012	0
Loss on interest rate swap					0	43	-5	10				0	48	851
Depreciation expense	2,249	2,238	2,186	2,144	2,105	2,058	2,050	1,984				8,817	8,197	7,689
Adjusted EBITDA	$7,706	$8,781	$9,000	$8,744	$8,469	$6,700	$2,278	($567)				$34,231	$16,880
Common Units
Net income per limited partner unit or limited subordinated unit - basic (in dollars per share)	$0.25	$0.33	$0.35	$0.28					$0.40			$1.23
Net income per limited partner common unit or limited subordinated unit - diluted (in dollars per share)	$0.25	$0.33	$0.35	$0.28					$0.39			$1.21
Weighted average limited partner units outstanding - basic									8,724,545			8,902,295
Weighted average limited partner units outstanding - diluted									9,036,545			9,026,734
Subordinate Units
Net income per limited partner unit or limited subordinated unit - basic (in dollars per share)	$0.25	$0.33	$0.36	$0.29					$0.40			$1.22
Net income per limited partner common unit or limited subordinated unit - diluted (in dollars per share)	$0.25	$0.33	$0.36	$0.29					$0.40			$1.22
Weighted average limited partner units outstanding - basic									8,724,545			8,724,545
Weighted average limited partner units outstanding - diluted									8,724,545			8,724,545
[1]	Post-IPO, August 1, 2013 to December 31, 2013 for the year ended December 31, 2013.