New Source Energy Partners (NSLP) 10-K 4 Apr 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jun. 30, 2013	Apr. 03, 2014	Apr. 03, 2014	Apr. 03, 2014
			Subordinated Units	General Partnership Units	Common Stock Units
Entity Registrant Name	'New Source Energy Partners L.P.	'	'	'	'
Document Type	'10-K	'	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'	'
Entity Common Stock, Shares Outstanding	'	'	2,205,000	155,102	10,088,245
Entity Public Float	'	$86,700,000,000	'	'	'
Amendment Flag	'false	'	'	'	'
Entity Central Index Key	'0001560443	'	'	'	'
Entity Current Reporting Status	'Yes	'	'	'	'
Entity Voluntary Filers	'No	'	'	'	'
Entity Filer Category	'Non-accelerated Filer	'	'	'	'
Entity Well-known Seasoned Issuer	'No	'	'	'	'
Document Period End Date	31-Dec-13	'	'	'	'
Document Fiscal Year Focus	'2013	'	'	'	'
Document Fiscal Period Focus	'FY	'	'	'	'

Balance_Sheets

Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash	$7,291	$0
Accounts receivable	12,609	5,663
Other current assets	1,114	25
Total current assets	21,014	5,688
Property and equipment, net	8,166	0
Oil and natural gas properties, at cost, using full cost method:	'	'
Proved oil and natural gas properties	291,829	202,795
Accumulated depreciation, depletion, and amortization	-128,961	-112,372
Total oil and natural gas properties, net	162,868	90,423
Prepaid drilling and completion costs	1,455	1,000
Intangible asset - customer relationships, net	35,009	0
Goodwill	23,974	0
Other assets	2,224	2,823
Total assets	254,710	99,934
Current liabilities:	'	'
Accounts payable	2,268	0
Accounts payablebrelated parties	8,221	1,564
Accrued liabilities	999	259
Factoring payable	1,907	0
Accrued income taxes	0	103
Current derivative obligations	3,167	47
Current portion of long-term debt	719	0
Total current liabilities	17,281	1,973
Contingent consideration payable to related parties	6,320	0
Other long-term related party payables	350	345
Credit facility	78,500	68,000
Long-term debt, net of current portion	1,514	0
Derivative obligations	37	107
Asset retirement obligations	3,455	1,510
Deferred tax liability	0	12,024
Total liabilities	107,457	83,959
Commitments and contingencies (See Note 16)	'	'
Parent net investment	0	15,975
Common units (9,599,578 units issued and outstanding as of December 31, 2013)	151,773	0
Subordinated units (2,205,000 units issued and outstanding as of December 31, 2013)	-17,334	0
General partner units (155,102 units issued and outstanding as of December 31, 2013)	-1,174	0
Total New Source Energy Partner L.P. partners' capital	133,265	0
Non-controlling interests in subsidiary	13,988	0
Total partners' capital	147,253	0
Total liabilities, parent net investment and partners' capital	$254,710	$99,934

Balance_Sheets_Balance_Sheet_P

Balance Sheets Balance Sheet (Parenthetical)	Dec. 31, 2013
Statement of Financial Position [Abstract]	'
Common Stock, Shares, Issued	9,599,578
Common units outstanding (in shares)	9,599,578
Subordinated Units Issued	2,205,000
Subordinated units outstanding (in shares)	2,205,000
General Partners' Capital Account, Units Issued	155,102
General partner's capital units outstanding (in shares)	155,102

Statements_of_Operations

Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES:	'	'	'
Oil sales	$8,090	$5,570	$4,489
Natural gas sales	10,000	6,030	8,713
Natural gas liquids sales	28,847	23,996	33,058
Service and rentals	3,738	0	0
Total revenues	50,675	35,596	46,260
OPERATING COSTS AND EXPENSES:	'	'	'
Oil and natural gas production expenses	12,631	6,217	7,875
Oil and natural gas production taxes	2,669	1,144	2,155
Cost of providing service and rentals	2,040	0	0
General and administrative	14,760	12,660	6,928
Depreciation, depletion, and amortization	18,556	14,409	14,738
Accretion expense	209	116	55
Total operating costs and expenses	50,865	34,546	31,751
Operating (loss) income	-190	1,050	14,509
OTHER INCOME (EXPENSE):	'	'	'
Interest expense	-4,078	-3,202	-3,735
Net gain (loss) on commodity derivatives (Note 11)	-5,548	7,057	-1,349
Gain on investment in acquired business	22,709	0	0
Other income	1,603	0	0
Income before income taxes	14,496	4,905	9,425
Income tax benefit (expense)	12,126	-1,796	-10,502
Net income (loss)	26,622	3,109	-1,077
Net income prior to purchase of properties from New Source Energy on February 13, 2013	5,303	'	'
Net income subsequent to purchase of properties from New Source Energy on February 13, 2013	$21,319	'	'
Net income per weighted average common units outstanding from February 13, 2013 to December 31, 2013 (in Dollars per share)	$2.42	'	'

Statements_of_Partners_Capital

Statements of Partner's Capital (USD $)

12 Months Ended

11 Months Ended

12 Months Ended

11 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

11 Months Ended

12 Months Ended

11 Months Ended

12 Months Ended

12 Months Ended

In Thousands, except Share data, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Feb. 11, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Feb. 13, 2013

Dec. 31, 2013

Dec. 31, 2013

General Partnership Units

General Partnership Units

New Source Energy Partners LP

New Source Energy Partners LP

Parent Net Investment

Parent Net Investment

Parent Net Investment

Parent Net Investment

Parent Net Investment

Parent Net Investment

Parent Net Investment

Parent Net Investment

Noncontrolling Interest

Common Stock Units

Common Stock Units

Subordinated Units

Subordinated Units

Subordinated Units

Select MCE Employees

David Chernicky

Subordinated Note Transferred to Parent

Cash Paid to Parent at Closing

Distributions of Accounts Receivable to Parent

Accounts Payable Assumed by Parent

Common Stock Units

Subordinated Units

Increase (Decrease) in Parent Net Investment [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance

$15,975

'

'

'

'

'

'

'

$27,574

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

26,622

291

'

21,319

'

5,303

'

3,109

-1,077

'

'

'

'

'

16,929

'

4,099

'

'

'

'

Stock-based compensation

'

'

'

'

'

'

'

8,204

4,470

'

'

'

'

'

'

'

'

'

'

'

'

Distribution to parent

-18,295

'

'

'

'

'

'

-13,758

-12,547

'

'

'

'

'

'

'

'

'

'

'

'

Partners' Capital

133,265

-1,174

-1,174

133,265

133,265

'

'

15,975

18,420

'

'

'

'

13,988

151,773

151,773

-17,334

-17,334

'

'

'

Allocated equity-based compensation of parent

'

'

'

'

'

'

'

388

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash distributions

-12,780

'

-217

'

-12,780

-2,495

'

'

'

'

'

'

'

'

'

-9,477

'

-3,086

'

'

'

Increase (Decrease) in Partners' Capital

'

'

'

'

'

'

'

'

'

-25,000

-15,800

-7,014

1,742

'

'

'

'

'

'

'

'

Purchase of oil and natural gas properties from New Source in exchange for units

26,901

'

-1,248

'

-26,901

'

26,901

'

'

'

'

'

'

'

'

-7,306

'

-18,347

'

'

'

Purchase of oil and natural gas properties from New Source in exchange for units (in Shares)

9,599,578

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Subordinated Units Issued (in Shares)

2,205,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,205,000

'

'

Stock Issued During Period, Shares, Other

'

'

150,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of common units in initial public offering, net of offering costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,250,000

'

'

'

'

'

Issuance of common units in initial public offering, net of offering costs (in shares)

76,565

'

'

'

76,565

'

'

'

'

'

'

'

'

'

'

76,565

'

'

'

'

'

Issuance to general partner from overallotment exercised

'

'

5,102

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity-based compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

367,500

'

'

'

'

'

Equity-based compensation (in shares)

7,350

'

'

'

7,350

'

'

'

'

'

'

'

'

'

'

7,350

'

'

'

'

'

Purchases of oil and natural gas properties in exchange for units (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,792,545

'

'

'

'

'

Purchase of oil and natural gas properties in exchange for units

36,406

'

'

'

36,406

'

'

'

'

'

'

'

'

'

'

36,406

'

'

'

'

'

Acquisition of MCE (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,947,033

'

0

'

'

'

Acquisition of MCE

35,360

'

0

'

21,372

'

'

'

'

'

'

'

'

13,988

'

21,372

'

'

'

'

'

Private Placement (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

465,000

'

'

'

'

'

Private Placement

9,833

'

'

'

9,833

'

'

'

'

'

'

'

'

'

'

9,833

'

'

'

'

'

Unit compensation funded by unitholders

101

'

'

'

101

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101

'

Partners' Capital Account, Units

'

155,102

155,102

'

'

'

'

'

'

'

'

'

'

'

9,599,578

9,599,578

'

'

'

'

'

Subordinate Units, Units, Owned by Principal Stockholder

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,205,000

Partners' Capital, Including Portion Attributable to Noncontrolling Interest

147,253

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Balance

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Statements_of_Cash_Flows

Statements of Cash Flows (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'	'
Net income (loss)	$26,622,000	$3,109,000	($1,077,000)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'
Depreciation, depletion, and amortization	18,556,000	14,409,000	14,738,000
Gain on investment in acquired business	-22,709,000	0	0
Equity-based compensation	7,839,000	8,204,000	4,470,000
Write-off of loan fees due to debt refinancing	1,436,000	0	771,000
Change in fair value of contingent consideration	-1,600,000	0	0
Amortization of loan fees	479,000	603,000	501,000
Accretion expense	209,000	116,000	55,000
Deferred income tax expense (benefit)	-12,024,000	1,694,000	10,330,000
Unrealized (gain) loss on derivatives	3,619,000	-1,070,000	-150,000
Payments for derivative option premiums	-1,334,000	0	0
Changes in operating assets and liabilities, net of business acquired:	'	'	'
Accounts receivable	-10,595,000	881,000	-421,000
Other assets	333,000	0	0
Accounts payable	7,355,000	-124,000	531,000
Accrued liabilities	281,000	46,000	213,000
Accrued income taxes	-103,000	-69,000	172,000
Net cash provided by operating activities	18,364,000	27,799,000	30,133,000
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'	'
Acquisition of oilfield services segment, net of MCE cash on hand	-2,259,000	0	0
Acquisition of oil and natural gas properties	-19,843,000	0	0
Additions to oil and natural gas properties and equipment	-28,921,000	-12,162,000	-23,818,000
Net cash used in investing activities	-51,023,000	-12,162,000	-23,818,000
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'	'
Proceeds from issuance of common units in initial public offering, net of deferred offering costs	77,880,000	0	0
Proceeds from issuance of common units in private placement, net of offering costs	9,833,000	0	0
Proceeds from borrowings on credit facility	78,500,000	3,000,000	68,500,000
Proceeds from borrowings on credit facility (pre IPO)	2,000,000	0	0
Payments on credit facility on credit facility (pre IPO)	-70,000,000	-3,500,000	-60,000,000
Payment on subordinated note payable to parent	-25,000,000	'	'
Proceeds from factoring payable	229,000	0	0
Payment on MCE long-term debt	-102,000	0	0
Distributions to unitholders	-12,780,000	0	0
Payments for deferred loan costs	-1,954,000	-64,000	-2,268,000
Distribution to parent	-18,295,000	-13,758,000	-12,547,000
Abandoned offerings costs	-361,000	0	0
Payments for offering costs	0	-1,315,000	0
Net cash provided by (used in) financing activities	39,950,000	-15,637,000	-6,315,000
Net change in cash and cash equivalents	7,291,000	0	0
Cash and cash equivalents at beginning of period	0	0	0
Cash and cash equivalents at end of period	7,291,000	0	0
SUPPLEMENTAL CASH FLOW INFORMATION:	'	'	'
Cash paid for interest expense	2,061,000	2,553,000	2,250,000
NON-CASH INVESTING AND FINANCING ACTIVITIES:	'	'	'
Capitalized asset retirement obligation	1,735,000	-17,000	499,000
Change in accrued capital expenditures	3,030,000	-780,000	-1,160,000
Income taxes assumed by parent	0	172,000	0
Accounts receivable distributed to parent	-7,014,000	0	0
Accounts payable assumed by parent	-1,742,000	0	0
Purchase of oil and natural gas properties in exchange for units	-36,406,000	0	0
Subordinated note given to parent in exchange for oil and gas properties	25,000,000	0	'
Acquisition of MCE in exchange for units	($21,372,000)	$0	$0

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
SignificantAccountingPoliciesTextBlockAbstract	'
Summary of Significant Accounting Policies	'
	Summary of Significant Accounting Policies
	Organization
	New Source Energy Partners L.P. (the “Partnership” or “NSLP”) is a Delaware limited partnership formed in October 2012 by New Source Energy Corporation (“New Source”) to own and acquire oil and natural gas properties in the United States in addition to converting the Partnership from a pure play exploration and production company to a more fully integrated oil and gas partnership that over time can provide more services and infrastructure to enhance safety and efficiencies in developing and producing natural resources. The Partnership is engaged in the development and production of its oil and natural gas properties portfolio that extends across conventional resource reservoirs in east-central Oklahoma ("Exploration and Production Segment"). In addition, the Partnership is engaged in oilfield services that specialize in increasing efficiencies and safety in drilling and completion processes ("Oilfield Services Segment") through its wholly owned subsidiary, MidCentral Energy Services, LLC ("MCE" or "MCE Entities"), which, on November 12, 2013, it acquired through the acquisition 100% of the equity interests in MCE, LP, a Delaware limited partnership, and its general partner, MCE GP, LLC, other than Class B units in MCE, LP that were retained by certain of the sellers. See Note 15 for further discussion regarding the Partnership’s reportable segments.
	On February 13, 2013, the Partnership completed its initial public offering (the “Offering”) of 4,000,000 common units representing limited partner interests in the Partnership at a price to the public of $20.00 per common unit. The Partnership received net proceeds of approximately $71.9 million from the Offering, after deducting underwriting discounts. The Partnership made a cash distribution of $15.8 million to New Source as consideration (together with its issuance to New Source of what then constituted approximately 50% of New Source Energy GP, LLC, which owns all of the Partnership general partner units, 777,500 common units, 2,205,000 subordinated units and a $25.0 million note payable) in exchange for the contribution by New Source of certain oil and gas natural properties (the “IPO Properties”) and certain commodity derivative contracts. Additionally, the Partnership assumed approximately $70.0 million of New Source's indebtedness previously secured by the IPO Properties, and used a portion of the net proceeds from the Offering to repay in full such assumed debt at the closing of the Offering. The Partnership also borrowed $15.0 million under a new revolving credit facility on February 13, 2013. On March 12, 2013, the Partnership received net proceeds of $4.7 million from the partial exercise, in the amount of 250,000 common units, of the underwriters’ overallotment option.
	The IPO Properties consist of interests in wells producing oil, natural gas and NGLs from the Misener-Hunton (the “Hunton”) formation in East-Central Oklahoma. The IPO Properties represent New Source’s working interest in certain Hunton formation producing wells located in Pottawatomie, Seminole and Okfuskee Counties, Oklahoma (the “Golden Lane Area”), which equates to approximately a 38% weighted average working interest in the Golden Lane Area.
	MCE is a limited liability company formed in June 2010 and is headquartered in and operates from Oklahoma City, Oklahoma. MCE offers full service blowout prevention installation and pressure testing services throughout the Mid-Continent region and has recently opened an additional field office in South Texas to focus on the Eagle Ford shale and in West Texas to focus on the Permian Basin. In addition, MCE offers short-term rentals out of Oklahoma City, Oklahoma of American Petroleum Institute (API) Certified irons such as: spacer spools; double-studded adapters; blowout preventers; ram blocks; choke manifolds; accumulators; and various other pressure components.
	Basis of Presentation
	The accompanying consolidated financial statements are prepared on a consolidated basis and present the financial position of the Partnership at December 31, 2013 and December 31, 2012 and the Partnership’s results of operations, partners' capital, and cash flows for the years ended December 31, 2013, 2012 and 2011. These consolidated financial statements include all adjustments, consisting of normal and recurring adjustments, which, in the opinion of management, are necessary for a fair presentation of the financial position and the results of operations for the indicated periods in accordance with accounting principles generally accepted in the United States of America, or “GAAP,” for financial reporting. All intercompany transactions are eliminated during the consolidation process. These consolidated financial statements include all accounts of the Partnership and those related to the "Non-Controlling Interest" owner (See "Note 12 - Unitholders' Equity").
	The acquisition of the IPO Properties discussed above was a transaction between businesses under common control. The accounts relating to the IPO Properties have been reflected retroactively in the Partnership’s financial statements at carryover basis. As such, for periods prior to the Offering, the accompanying financial statements have been prepared on a "carve-out" basis from New Source's financial statements and reflect the historical accounts directly attributable to the IPO Properties together with allocations of expenses from New Source. Therefore, for periods prior to February 13, 2013, the accompanying consolidated financial statements may not be indicative of the Partnership’s future performance and may not reflect what its financial position, results of operations, and cash flows would have been had it been operated as an independent company during the periods presented. Prior to February 13, 2013, New Source performed certain corporate functions on behalf of the IPO Properties, and the consolidated financial statements reflect an allocation of the costs New Source incurred. These functions included executive management, information technology, tax, insurance, accounting, legal and treasury services. The costs of such services were allocated based on the most relevant allocation method to the service provided, primarily based on relative book value of assets, among other factors. Management believes such allocations are reasonable; however, they may not be indicative of the actual expense that would have been incurred had the Partnership been operated as an independent company for all of the periods presented. The charges for these functions are included primarily in general and administrative expenses.
	New Source became the owner of the IPO Properties on August 12, 2011 and reflected the IPO Properties in its financial statements retroactively because the acquisition of the IPO Properties was a transaction between businesses under common control. Prior to that date, the IPO Properties were owned by a nontaxable entity. New Source was a taxable entity. Accordingly, on August 12, 2011, New Source accrued deferred income taxes attributable to differences in the book and tax bases in the IPO Properties and subsequent to the August 12, 2011 acquisition has accounted for income taxes using the asset and liability method until the Offering. The Partnership will not be a taxable entity. Accordingly, when New Source contributed the IPO Properties to the Partnership in 2013, the Partnership reversed the related deferred income taxes, and subsequently the Partnership will not reflect income taxes in its financial statements.
	As part of the MCE Acquisition on November 12, 2103, certain owners of MCE retained Class B Units in MCE ("Class B Units"), which entitle the holders to receive incentive distributions of cash distributed by MCE above specified thresholds. Distributions to the Class B Units will be recognized in the period earned and recorded as a reduction to net income attributable to New Source Energy Partners L.P. on the Consolidated Statements of Operations.
	Use of Estimates in the Preparation of the Consolidated Financial Statements
	Preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from these estimates. Depletion of oil and natural gas properties is determined using estimates of proved oil and natural gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and natural gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves. Other significant estimates include, but are not limited to: the valuation of commodity derivatives; the allocation of general and administrative expenses; asset retirement obligations; goodwill/intangible impairment analysis; valuation of the consideration transferred for the MCE Acquisition; and the valuation of assets acquired and liabilities assumed in business combinations.
	Acquisitions
	The Partnership accounts for acquired businesses using the acquisition method of accounting, which requires that the assets acquired, liabilities assumed, contractual contingencies and contingent consideration be recorded at the date of acquisition at their respective fair values. Goodwill represents the excess of the purchase price, including any contingent consideration, over the fair value of the identifiable net assets acquired. It further requires acquisition related costs to be recognized separately from the acquisition and expensed as incurred.
	The fair value of identifiable long-lived assets is based on significant judgments made by management of the Partnership. The Partnership typically engages third party valuation appraisal firms to assist in determining the fair values and useful lives of the identifiable long-lived assets acquired in the Oilfield Services Segment. Such valuations and useful life determinations require the Partnership to make significant estimates and assumptions. These estimates and assumptions are based on historical experience and information obtained from management, and also include, but are not limited to, future expected cash flows and discount rates applied in determining the present value of those cash flows. Unanticipated events and circumstances may occur that could affect the accuracy or validity of such assumptions, estimates or actual results. Acquired identifiable intangible assets are amortized on a pattern that is consistent with the net cash flows they are expected to produce over their estimated economic lives.
	Accounts Receivable
	Accounts receivable consist of the following as of December 31, (in thousands):
		2013			2012
	Oil and natural gas sales receivables	$	8,417		$	5,621
	Oil and natural gas sales receivables - related parties	228			42
	Oilfield services receivables	3,964			—
	Total accounts receivable	$	12,609		$	5,663
	Accounts receivable are customer obligations due under normal trade terms and are presented on the Consolidated Balance Sheets net of allowances for doubtful accounts. Customers are granted credit in the ordinary course of business and generally do not require collateral. Based on management’s best estimate of the amount of probable credit losses in the Partnership's existing accounts receivable, it has concluded that realization of losses on balances outstanding at December 31, 2013 and 2012 will be immaterial; therefore, no allowance for doubtful accounts is deemed necessary. However, actual write-offs may occur. As part of the factoring payable mentioned below, certain of MCE's accounts receivable are pledged as collateral.
	Property and Equipment
	Property and equipment are capitalized and recorded at cost, while maintenance and repairs are expensed. Depreciation of property and equipment is provided when assets are placed in service using the straight-line method based on estimated useful lives ranging from three to ten years. Depreciation expense for property and equipment was $0.2 million for the year ended December 31, 2013. The Partnership did not incur any depreciation expense for property and equipment for the years ended December 31, 2012 and 2011.
	Oil and Natural Gas Properties
	The Partnership utilizes the full cost method of accounting for oil and natural gas properties whereby productive and nonproductive costs incurred in connection with the acquisition, exploration, and development of oil and natural gas reserves are capitalized. All capitalized costs of oil and natural gas properties and equipment, including the estimated future costs to develop proved reserves, are amortized to depreciation, depletion and amortization ("DD&A") expense using the units-of-production method based on total proved reserves. Historically, full cost pool amortization was recorded on a carve-out basis based on relative production from the Partnership compared to total production of New Source. No gains or losses are recognized upon the sale or other disposition of oil and natural gas properties except in transactions that would significantly alter the relationship between capitalized costs and proved reserves. Under the full cost method, the net book value of oil and natural gas properties may not exceed the estimated after-tax future net revenues from proved oil and natural gas properties, discounted at 10% (the ceiling limitation). In arriving at estimated after-tax future net revenues, estimated lease operating expenses, development costs, and certain production-related and ad valorem taxes are deducted. In calculating future net revenues, prices and costs in effect at the time of the calculation are held constant indefinitely, except for changes that are fixed and determinable by existing contracts. The net book value is compared to the ceiling limitation on a quarterly and yearly basis. The excess, if any, of the net book value above the ceiling limitation is charged to expense in the period in which it occurs and is not subsequently reinstated. Reserve estimates used in determining estimated future net revenues have been prepared by an external petroleum engineering firm. Future net revenues were computed based on reserves using prices calculated as the unweighted arithmetical average oil and natural gas prices on the first day of each month within the latest twelve-month period. Subsequent to February 13, 2013, the ceiling limitation computation is determined without regard to income taxes due to the Partnership being a non-income tax paying entity. There were no full cost ceiling write-downs recorded for the years ended December 31, 2013, 2012 and 2011.
	Intangible Asset - Customer Relationships
	As part of the MCE Acquisition on November 12, 2013, $36.8 million of customer relationships intangible assets were recognized as part of the purchase price allocation (see Note 2). The amortization of customer relationships reflects a pattern in which the economic benefits of the assets will be consumed or used up. Amortization was estimated by using an accelerated method over 7 years similar to the expected cash flow pattern of the acquired customer relationships, estimated for each of the five succeeding years ending December 31, as follows (in thousands):
			Total
	2014		$	12,366
	2015		8,689
	2016		5,264
	2017		3,425
	2018		1,839
	Thereafter		3,426
			$	35,009
	Amortization expense was $1.8 million for the year ended December 31, 2013. The Partnership did not incur any amortization expense for customer relationships for the years ended December 31, 2012 and 2011.
	The Partnership evaluates for potential impairment of long-lived assets, including intangible assets, subject to amortization when indicators of impairment are present. Circumstances that could indicate a potential impairment include losses of significant customers, significant adverse changes in industry trends, economic climate, legal factors, and an adverse action or assessment by a regulator. More specifically, significant adverse changes in industry trends, including oil and natural gas market prices could indicate a potential impairment. In performing an impairment evaluation, the Partnership estimates the future undiscounted net cash flows from the use and eventual disposition of the intangible asset grouped at the lowest level that cash flows can be identified. If the sum of the estimated future undiscounted net cash flows is less than the carrying amount, an impairment charge would be measured as the difference between the carrying amount and the fair value of these assets. The assumptions used in the impairment evaluation for long-lived assets are inherently uncertain and require management judgment. The Partnership did not record any impairment of long-lived assets for the years ended December 31, 2013, 2012 or 2011.
	Goodwill
	Goodwill represents consideration paid in excess of the fair value of the identifiable assets acquired in a business combination. In connection with the acquisition of MCE on November 12, 2013 (see Note 2), the Partnership recorded $24.0 million of goodwill, which represents the goodwill balance at December 31, 2013. Goodwill is not amortized, but is reviewed for impairment annually based on the carrying values as of November 1, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered.
	In evaluating possible impairment of goodwill, the Partnership performs a qualitative assessment to determine whether it is more likely than not that the fair value of the reporting unit is impaired. Management uses all available information to make these determinations, including evaluating the macroeconomic environment, industry specific conditions, cost factors, overall financial performance and unit price, at the assessment date. The Partnership did not record any impairment of goodwill for the years ended December 31, 2013, 2012 or 2011.
	Contingent Consideration Payable to Related Parties
	Contingent consideration, which includes earnout payments in connection with the Partnership’s acquisitions, is recognized at fair value on the acquisition date and remeasured each reporting period with subsequent adjustments recognized in our Consolidated Statements of Operations. The Partnership estimates the fair value of contingent consideration liabilities based on certain performance milestones of the acquired companies or properties, and estimated probabilities of achievement, then discounts the liabilities to present value using the Partnership’s cost of debt. Contingent consideration is valued using significant inputs that are not observable in the market which are defined as Level 3 inputs pursuant to fair value measurement accounting. The Partnership believes its estimates and assumptions are reasonable, however, there is significant judgment involved. At each reporting date, the contingent consideration liability is revalued to estimated fair value.
	Changes in the fair value of contingent consideration liabilities may result from changes in discount periods, changes in the timing and amount of sales and/or other specific milestone estimates and changes in probability assumptions with respect to the likelihood of achieving the various earnout criteria. These changes could cause a material impact to, and volatility in our operating results. Earnout payments, if any, will be reflected in cash flows from financing activities and the changes in fair value are reflected in cash flows from operating activities in our Consolidated Statements of Cash Flows. See Note 10 for contingent consideration activity.
	Environmental
	Oil and natural gas properties are subject to extensive federal, state and local environmental laws and regulations. These laws, which are often changing, regulate the discharge of materials into the environment and may require the removal or mitigation of the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Liabilities for expenditures of a noncapital nature are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable.
	Revenue Recognition
	Oil and natural gas sales are recognized when production is sold to a purchaser at a fixed or determinable price, delivery has occurred, title has transferred, and collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a pipeline, railcar or truck, or a tanker lifting has occurred. The sales method of accounting is used for oil and natural gas sales such that revenues are recognized based on the actual proceeds from the oil and natural gas sold to purchasers. Oil and natural gas imbalances are generated on properties for which two or more owners have the right to take production “in-kind” and, in doing so, take more or less than their respective entitled percentage. For the years ended December 31, 2013, 2012 and 2011 there were no significant oil and natural gas imbalances.
	The Oilfield Services Segment's service and rental revenue is recognized when persuasive evidence of an arrangement exists, the product or service has been provided, the price is fixed or determinable and collection is reasonably assured, which is generally at the time the service is provided.
	Asset Retirement Obligations
	Liabilities associated with asset retirement obligations are recorded at fair value in the period in which they are incurred or when properties are acquired with a corresponding increase in the carrying amount of the related oil and natural gas properties. Subsequently, the asset retirement cost included in the carrying amount of the oil and natural gas properties and is allocated to expense through DD&A. Changes in the liability due to passage of time are recognized as an increase in the carrying amount of the liability and as corresponding accretion expense.
	Equity-Based Compensation
	Awards under the Partnership’s long-term incentive plan may consist of restricted stock grants, equity option awards, and other awards issuable to employees and non-employee directors. The Partnership recognizes in its consolidated financial statements the cost of employee services received in exchange for awards of equity instruments based on the fair value of those awards at their grant date. If an award has a fixed vesting date, the cost is recognized over the period from the grant date to the vesting date(s) of the award. If an award does not have a fixed vesting date, the cost is recognized at the time it vests.
	Income Taxes
	Income taxes are reflected in these consolidated financial statements during the periods in which the IPO Properties were owned by a taxable entity. Since the Partnership is not a taxable entity, no income taxes have been provided for the periods following completion of the Offering. Upon the Partnership becoming a non-taxable entity, the Partnership recognized a tax benefit related to the change in tax status of approximately $12.1 million for the year ended December 31, 2013.
	The Company is a limited partnership for federal and state income tax purposes, with the exception of the state of Texas, in which income tax liabilities and/or benefits of the Company are passed through to its unitholders. Limited partnerships are subject to Texas margin tax.
	In accordance with the applicable accounting standards, the Partnership recognizes only the impact of income tax positions that, based on their merits, are more likely than not to be sustained upon audit by a taxing authority. To evaluate its current tax positions in order to identify any material uncertain tax positions, the Partnership developed a policy of identifying and evaluating uncertain tax positions that considers support for each tax position, industry standards, tax return disclosures and schedules and the significance of each position. It is the Partnership’s policy to recognize interest and penalties, if any, related to unrecognized tax benefits in income tax expense. The Partnership had no material uncertain tax positions at December 31, 2013, and December 31, 2012. The tax years 2010 – 2012 remain open to examination for federal income tax purposes.
	Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax bases and financial reporting bases of assets and liabilities and the taxable income allocation requirements under the partnership agreement. In addition, individual unitholders have different investment bases depending upon the timing and price of acquisition of their common units, and each unitholder’s tax accounting, which is partially dependent upon the unitholder’s tax position, differs from the accounting followed in the consolidated financial statements. As a result, the aggregate difference in the basis of net assets for financial and tax reporting purposes cannot be readily determined as the Partnership does not have access to information about each unitholder’s tax attributes in the Partnership. However, with respect to the Partnership, the Partnership's book basis in its net assets exceeds the Partnership's net tax basis by $118.9 million at December 31, 2013.
	Fair Value of Financial Instruments
	The fair value of a financial instrument is the amount at which the instrument could be exchanged in an orderly transaction between two willing parties. The carrying amount of cash, accounts receivable, prepaid expenses, accounts payable, accrued expenses reported on the balance sheet approximates fair value. The carrying amount of the borrowings under the credit facility and our other borrowings reported on the balance sheets approximates fair value (level 2) because the debt instruments carry a variable interest rate based on market interest rates.
	Derivatives
All derivative instruments are recognized as either assets or liabilities in the balance sheet at fair value. None of such instruments have been designated as cash flow hedges. Accordingly, changes in the fair value of all derivative instruments have been recorded in the consolidated statements of operations.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Acquisitions	'
	Acquisitions
	The Partnership completed six acquisitions during 2013. Five of those acquisitions broaden the Partnership's growing portfolio of oil and natural gas properties. The acquisition of MCE contributes to the Partnership's long-term goals of converting the Partnership from a pure play Exploration and Production company to a more fully integrated oil and gas partnership that over time can provide more services and infrastructure to enhance safety and efficiencies in developing and producing natural resources. All acquisitions in 2013 were of a related party nature with exception of the "Orion Acquisition." Each of the acquisitions were accounted for under FASB ASC 805, "Business Combinations."
	March Acquired Properties
	On March 29, 2013, we completed an acquisition with an effective date of March 1, 2013, of certain oil and natural gas properties located in Oklahoma (the “March Acquired Properties”) from New Source, Scintilla, and W.K. Chernicky, LLC, an Oklahoma limited liability company for an aggregate adjusted price of $28.0 million. As consideration for the properties, the Partnership issued an aggregate of 1,378,500 common units valued at $20.30 per unit. The properties are located in the Golden Lane field, where the Partnership's existing properties are located, and in the Luther field, which is adjacent to the Golden Lane field.
	This transaction was unanimously approved by the board of directors of the Partnership's general partner, based on the approval and recommendation of its conflicts committee. The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		29-Mar-13
	Proved oil and natural gas properties	$	29,049
	Other assets acquired	754
	Fair value of assets acquired	29,804
	Asset retirement obligations	(1,333		)
	Other liabilities assumed	(488		)
	Fair value of net assets acquired	$	27,984
	May Acquired Properties
	On May 31, 2013, the Partnership completed an acquisition of certain oil and natural gas properties located in Oklahoma (the “May Acquired Properties”) from New Source, with an effective date of May 1, 2013. As consideration for the May Acquired Properties, the Partnership paid a total of $8.1 million in cash to New Source. After purchase price adjustments, the total consideration was $7.9 million.
	This transaction was unanimously approved by the board of directors of the Partnership's general partner, based on the approval and recommendation of its conflicts committee. The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		31-May-13
	Proved oil and natural gas properties	$	8,165
	Fair value of assets acquired	8,165
	Asset retirement obligations	(19		)
	Other liabilities assumed	(254		)
	Fair value of net assets acquired	$	7,893
	July Scintilla Acquired Properties
	On July 23, 2013, the Partnership completed an acquisition of a 10% working interest in certain oil and natural gas properties located in Oklahoma (the “July Scintilla Acquired Properties”) from Scintilla, with an effective date of May 1, 2013. As consideration for the July Scintilla Acquired Properties, the Partnership paid a total of $4.9 million in cash to Scintilla after purchase price adjustments.
	This transaction was unanimously approved by the board of directors of the Partnership's general partner, based on the approval and recommendation of its conflicts committee. The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		23-Jul-13
	Proved oil and natural gas properties	$	4,888
	Fair value of assets acquired	4,888
	Asset retirement obligations	(4		)
	Other liabilities assumed	(18		)
	Fair value of net assets acquired	$	4,866
	Orion Acquired Properties
	On July 25, 2013 the Partnership acquired certain oil and natural gas properties from, located in Oklahoma (the "Orion Acquired Properties") from Orion Exploration Partners, LLC, with an effective date of May 1, 2013. The Partnership paid $3.2 million in cash for the Orion Acquired Properties after purchase price adjustments.
	This transaction was unanimously approved by the board of directors of the Partnership's general partner. The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		25-Jul-13
	Proved oil and natural gas properties	$	3,274
	Fair value of assets acquired	3,274
	Asset retirement obligations	(24		)
	Other liabilities assumed	(20		)
	Fair value of net assets acquired	$	3,230
	Southern Dome Acquired Properties
	On October 4, 2013, the Partnership completed an acquisition of working interests in 25 producing wells and related undeveloped leasehold rights in the Southern Dome field in Oklahoma County, Oklahoma (the “Southern Dome Acquired Properties”) from Scintilla, with an effective date of August 1, 2013. As consideration for the working interests, the Partnership paid $5.0 million in cash to Scintilla at closing and issued 414,045 common units with a fair market value of $20.79 (closing price on the date of the transaction) or $8.6 million to Scintilla in November 2013. The Partnership also agreed to provide additional consideration to Scintilla in November 2014 if the production attributable to the working interests for the nine-month period ending September 30, 2014 exceeds the average daily production of 383.5 Boe/d ("Southern Dome Contingent Consideration"), which had an estimated fair value of $1.6 million on the acquisition date and was considered part of the purchase price, for a total consideration of $14.5 million after purchase price adjustments. As detailed in the Contribution Agreement, the additional consideration was calculated as the acquisition value of the production increase (applying the same valuation methodology as was used to determine the initial consideration with respect to the Current Production Average) less (i) the capital expenditures incurred attributable to the production growth (including an allowance for the cost of capital for such capital expenditures) and (ii) revenue attributable to any wells that were not producing in paying quantities as of the effective date of the acquisition. In addition, the fair value of the contingent consideration was based on the weighted probability of achievement of certain performance milestones. The Partnership may satisfy any such additional consideration in cash, common units, or a combination thereof at its discretion.
	This transaction was unanimously approved by the board of directors of the Partnership's general partner, including each member of its conflicts committee. The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		4-Oct-13
	Proved oil and natural gas properties	$	15,190
	Fair value of assets acquired	15,190
	Asset retirement obligations	(170		)
	Other liabilities assumed	(552		)
	Fair value of net assets acquired	$	14,469
	MCE Acquisition
	On November 12, 2013, the Partnership acquired 100% of the equity interests in the MCE Entities, other than Class B Units that were retained by certain of the sellers and are described below. MCE operates an oilfield services business headquartered in Oklahoma City, Oklahoma. MCE offers full service blowout prevention installation and pressure testing services throughout the Mid-Continent region, along with the rental of certain ancillary equipment necessary to perform such services. In addition to its presence in the Mid-Continent region, MCE recently opened field offices in South Texas to focus on the Eagle Ford Shale and in West Texas to focus on the Permian Basin.  The effective date of this acquisition was November 1, 2013.
	The Partnership acquired the MCE Entities in exchange for $68.2 million in total consideration, which consisted of approximately $3.8 million in cash, 1,847,265 Partnership common units, valued at $22.64 (closing price on the date of the transaction) per common unit, issued to the MCE Owners in exchange for their equity interests in MCE, 99,768 Partnership common units, valued at $22.64 per common unit, issued to certain employees of MCE under the Partnership’s long-term incentive plan, $6.3 million in contingent consideration and $14.0 million in Class B Units in MCE. The Partnership recorded acquisition-related costs of $0.8 million in general and administrative expense for the year ended December 31, 2013. The acquisition was accounted for using the acquisition method of accounting.
	The Partnership used a third-party valuation specialist to assist in determining the fair value for the total consideration, the assets acquired and the liabilities assumed as of the acquisition date. The fair value of the total consideration was allocated to the fair value of the assets acquired, the liabilities assumed, non-controlling interests and the resulting goodwill. Accordingly, the consolidated financial statements include an allocation of the purchase price based on assumptions and estimates. A summary of the purchase price allocation made in connection with the MCE Acquisition is as follows (in thousands):
			12-Nov-13
	Cash Paid		$	3,781
	Fair value of common units granted (1)		41,822
	Common units granted to MCE employees (2)		2,259
	Earn-out amount (contingent consideration) (3)		6,320
	MCE Class B units granted (4)		13,988
	Total fair value consideration transferred		$	68,170
	-1	1,847,265 common units valued at $22.64 per unit.
	-2	99,768 common units valued at $22.64 per unit. These common units were issued to certain employees of MCE, under the Partnership’s long-term incentive plan. If the recipients of the common units do not remain employed by MCE for three years, then they forfeit the units. The common units do not revert to the Partnership, but would be distributed to the former owners of MCE. The $2.3 million fair value of the common units is included in the consideration transferred for the MCE Acquisition, as the units do not revert back to the Partnership upon any circumstance. Since this compensation arrangement is funded by unitholders, the compensation will be reflected in the accompanying Consolidated Statements of Operations over the three-year straight-line vesting period. See Note 14, Equity-Based Compensation, for more information.
	-3	The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date and was considered as part of the purchase price of MCE. The Partnership determined the fair value of the MCE Contingent Consideration with the assistance of a third-party valuation specialist through the use of a Monte Carlo simulation, which allows for an open-form approach to allocate value. The simulation generates value based on probability distributions similar to those used under closed-form models.
	-4	Certain owners of MCE retained Class B Units, which entitle the holders to receive incentive distributions of cash distributed by MCE above specified thresholds in increasing amounts (see Note 12). The Class B units were valued at $14.0 million at the acquisition date and were considered as part of the purchase price of MCE. The Partnership determined the fair value of the Class B Units with the assistance of a third-party valuation specialist through the use of a Monte Carlo simulation, which allows for an open-form approach to allocate value. The simulation generates value based on probability distributions similar to those used under closed-form models.
The following table summarizes the assets acquired and the liabilities assumed as of the acquisition date at estimated fair value (in thousands):
		November 12, 2013
Assets
Cash		$	1,522
Accounts receivable		3,365
Other current assets		954
Property and Equipment		7,923
Intangible asset - customer relationship		36,772
Goodwill		23,974
Other assets		19
Liabilities
Accounts payable		(1,199		)
Accounts payable - related parties		(870		)
Accrued liabilities		(276		)
Factoring payable		(1,679		)
Current portion of long-term debt		(719		)
Long-term debt		(1,616		)
Net assets acquired		$	68,170
Since the MCE Acquisition was accounted for under FASB ASC 805, "Business Combinations." The fair values of the assets acquired and liabilities assumed were determined using the market, income, and cost approaches. The market approach, which indicates value for a subject asset based on available market pricing for comparable assets, was utilized to estimate the fair value of MCE property and equipment. The market approach used by the Company included prices and other relevant information generated by market transactions involving comparable assets. The income approach was primarily used to value customer relationships. The income approach indicates value for a subject asset based on the present value of future cash flows projected to be generated by the asset and applies the operating expenses required to support the forecasted revenue stream. Projected future cash flows are discounted at a required market rate of return that reflects the relative risk of achieving the cash flows and the time value of money. The cost approach, which estimates value by determining the current cost of replacing an asset with another of equivalent economic utility, was used, as appropriate, for certain assets for which the market and income approaches could not be applied due to the nature of the asset. The cost to replace a given asset reflects the estimated reproduction or replacement cost for the asset, less an allowance for loss in value due to depreciation.
Since the President and Chief Executive Officer of the Partnership's general partner, Kristian B. Kos ("Mr. Kos"), through his control over the Partnership’s general partner, controls the Partnership and Mr. Kos also owned 36% of the equity interest in MCE, the Partnership accounted for the acquisition as a business combination achieved in stages under FASB ASC 805-10. The Partnership initially recorded the 36% equity interest in MCE acquired from Mr. Kos at Mr. Kos’ equity method carrying basis, which was $1.8 million as of November 12, 2013, as this was a transaction between entities under common control. The Partnership remeasured the 36% interest acquired from Mr. Kos at its acquisition-date fair value and recognized a corresponding gain of $22.7 million, recorded as a gain on investment in acquired business in the accompanying Consolidated Statements of Operations for the year ended December 31, 2013. The acquisition of the remaining 64% of MCE was accounted for as a purchase at fair value.
Customer Relationships, an identifiable intangible asset was created as a result of the acquisition of MCE, which is being amortized by an accelerated amortization schedule to reflect the estimated free cash flows the customer relationships are expected to provide. See Note 1 for further information on intangible assets.
Goodwill in the amount of $24.0 million has been recorded for the acquisition of MCE. Goodwill is calculated as the excess of the consideration transferred over the fair value of net assets recognized and represents the estimated future economic benefits arising from other assets acquired that could not be individually identified and separately recognized. None of the goodwill is deductible for tax purposes. Specifically, the goodwill recorded as part of the acquisition of MCE includes any intangible assets that do not qualify for separate recognition, such as the MCE trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships and integrating new product offerings into MCE's business.
Pro forma for information for material acquisitions (unaudited)
The acquisition of the March Acquired Properties, the Southern Dome Acquired Properties and the MCE Acquisition (collectively, the "Material Acquisitions") were deemed material for purposes of the following pro forma disclosures. The Material Acquisitions were not included in the Partnership's consolidated results until their closing dates. For the periods after the closing date of each Material Acquisition to December 31, 2013, the Material Acquisitions contributed revenue of $11.5 million and operating income of $6.5 million for the year ended December 31, 2013.
The operating income attributable to the Material Acquisitions does not reflect certain expenses, such as general and administrative and interest expense; therefore, this information is not intended to report results as if these operations were managed on a stand-alone basis. The financial information was derived from the Partnership's audited historical consolidated financial statements for the years ended December 31, 2013 and 2012, the Material Acquisitions' audited and historical financial statements for the year ended December 31, 2012 and the Material Acquisitions' unaudited interim financial statements from January 1, 2013 to each closing date. The following unaudited pro forma consolidated financial information has been prepared as if the Material Acquisitions occurred on January 1, 2012 for the years ending December 31, (in thousands, except per unit data).
	Pro forma
	2013				2012
Revenue:
As reported	$	50,675			$	35,596
Pro forma	$	77,892			$	67,599
Net Income (loss):
As reported	$	26,622			$	3,109
Pro forma	$	(3,438	)		$	12,420
Basic net income (loss) per unit:
As reported	$	2.42
Pro forma	$	(0.36	)
Diluted net income (loss) per unit:
As reported	$	2.42
Pro forma	$	(0.36	)
These pro-forma adjustments have been calculated after applying the Partnership's accounting policies and adjusting the results to reflect additional depreciation and amortization that would have been charged assuming the properties and intangible assets were acquired and fair value adjustments to property and equipment and intangible assets had been applied. In addition, pro forma adjustments have been made for the interest that would have been incurred for financing the acquisitions with the Partnership's credit facility, and pro forma net income per unit amounts assume the units issued in these acquisitions had been outstanding since January 1, 2012. In computing pro forma net income, the $22.7 million gain on Mr. Kos' equity method investment in the acquired business mentioned above has been removed from 2013 net income and reflected in 2012. These pro forma results of operations have been prepared for comparative purposes only and they do not purport to be indicative of the results of operations that actually would have resulted had the acquisitions occurred on the date indicated or that may result in the future.
CEU Acquired Properties
On January 31, 2014, the Partnership completed an acquisition of working interests in 23 producing wells and related undeveloped leasehold rights in the Southern Dome field in Oklahoma County, Oklahoma from CEU Paradigm, LLC (“CEU Acquired Properties”). See Note 18, Subsequent Events regarding more details of this transaction.

Related_Parties

Related Parties	12 Months Ended
	Dec. 31, 2013
RelatedPartyTransactionsDisclosureTextBlockAbstract	'
Related Parties	'
	Related Parties
	Using ownership information as of December 31, 2013, the Partnership is controlled by the Partnership's general partner, which is owned 69.4% by Mr. Kos, and 25.0% by the Chairman and Senior Geologist of the Partnership, David J. Chernicky ("Mr. Chernicky"). Mr. Kos owns approximately 8.3% of the Partnership's outstanding common units, including units owned through the Partnership's long-term incentive plan, and units owned through Deylau, LLC, an entity he controls. Mr. Chernicky owns approximately 27.6% of the Partnership's outstanding common units, including units owned through the Partnership's long-term incentive plan, and units owned through New Source and Scintilla, entities which he controls. In addition, Mr. Chernicky owns 100% of the 2,205,000 subordinated units through New Source. Mr. Chernicky owns all of the membership interests in the entity that operates the Partnership's properties, New Dominion, LLC ("New Dominion").
	New Dominion, LLC
	New Dominion is an exploration and production operator based in Tulsa, Oklahoma and is wholly-owned by Mr. Chernicky. Pursuant to the Partnership’s development agreement, New Dominion is currently contracted to operate the Partnership’s existing wells. New Dominion has historically performed this service for New Source.
	New Dominion acquires leasehold acreage on behalf of the Partnership for which the Partnership is obligated to pay in varying amounts according to agreements applicable to particular areas of mutual interest. The leasehold cost for which the Partnership is obligated is approximately $0.3 million as of December 31, 2013, all of which is classified as a long-term liability, and $0.6 million as of December 31, 2012, of which $0.3 million was classified as a short-term liability and $0.3 million was classified as a long-term liability. The Partnership classifies these amounts as current or long-term liabilities based on the estimated dates of future development of the leasehold, which is customarily when New Dominion invoices the Partnership for these costs.
	The expenses incurred by the Partnership billed by New Dominion consist of the following:
	•Producing overhead charges included in the Partnership properties’ oil and natural gas expenses.
	•	Drilling and completion overhead charges included in the Partnership properties’ full cost pool of oil and natural gas properties.
	•	Saltwater disposal access fee charges included in the Partnership's capitalized oil and gas properties full cost pool and salt water disposal fees included in oil and natural gas production expenses.
	•	Administrative fees included in general and administrative expenses.
	The expense amount incurred for these charges are as follows for the years ended December 31, (in thousands):
		2013		2012		2011
	Access fee charges	$	250	$	2,615	$	196
	Producing overhead charges	980		599		581
	Drilling and completion overhead charges	101		27		26
	Saltwater disposal fees	696		1,642		1,612
	Administrative fees	9		—		—
	Total expenses incurred	$	2,035	$	4,883	$	2,415
	New Source
	On February 13, 2013, in connection with the closing of the Offering, the Partnership entered into an Omnibus Agreement (the “Omnibus Agreement”) by and among New Source, the Partnership and our general partner. Pursuant to the Omnibus Agreement, New Source provided management and administrative services for the Partnership and our general partner for the year ended December 31, 2013. From the closing of the Offering through December 31, 2013, the Partnership paid New Source Energy a quarterly fee of $0.7 million for the provision of such services, totaling $2.4 million for the year ended December 31, 2013, which included a prorated fee of $0.4 million for the period from February 13, 2013 through March 31, 2013 in its general and administrative expenses. After December 31, 2013, in lieu of the quarterly fee, our general partner will reimburse New Source, on a quarterly basis, for the actual direct and indirect expenses it incurs in its performance under the Omnibus Agreement, and the Partnership will reimburse our general partner for such payments it makes to New Source. Prior to February 13, 2013, the Partnership’s consolidated financial statements reflected an allocated portion of the general and administrative expenses of the owner of the IPO Properties.
	Oilfield Services Segment
	Mr. Kos was a 36% owner of the MCE Entities prior to the MCE Acquisition.
	Dikran Tourian, the President of the Oilfield Services Segment, was a 36% owner of the MCE Entities prior to the MCE Acquisition and was appointed to serve as a member of the board of directors of our general partner in February 2014.
	The conflicts committee of the board of directors of our general partner, which consists of two independent directors, reviewed the MCE Acquisition and related terms and agreements, engaged and consulted with independent financial and legal advisors with respect thereto, and granted “special approval” under our partnership agreement with respect to the “MCE Contribution Agreement." Based on this approval and recommendation from the conflicts committee, our general partner’s board of directors approved the MCE Acquisition.
	Transactions with Directors and Officers
	New Source, through the Omnibus Agreement, engaged Finley & Cook, PLLC to provide various accounting services during the year ended December 31, 2013. Richard Finley, our Chief Financial Officer, is an equity member of Finley & Cook, holding a 31.5% ownership interest. New Source paid Finley & Cook approximately $0.5 million, $0.5 million and $0.1 million, in fees for accounting services for the years ended December 31, 2013, 2012 and 2011, respectively.

Property_and_Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property and Equipment	'
	Property and equipment
	Major classes of property and equipment included the following at December 31, (in thousands):
		Useful life	2013
	Light-duty trucks	3 years	$	516
	Machinery and equipment	3-10 years	4,793
	Rental iron	20 years	2,971
	Other assets	3-7 years	88
	Less accumulated depreciation		(202		)
	Total Property and equipment, net		$	8,166
	Property and equipment only relates to our Oilfield Services Segment, which was acquired on November 12, 2013. Therefore, property and equipment is not presented as of December 31, 2012.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
AssetRetirementObligationDisclosureTextBlockAbstract	'
Asset Retirement Obligations	'
	Asset Retirement Obligations
	Asset retirement obligations represent the present value of the estimated cash flows expected to be incurred to plug, abandon and remediate producing properties at the end of their productive lives in accordance with applicable laws. There were no assets legally restricted for purposes of settling asset retirement obligations as of December 31, 2013 and 2012.
	The following table summarizes activity associated with asset retirement obligations for the years ending December 31, (in thousands):
		2013		2012			2011
	Asset retirement obligations, beginning of period	$	1,510	$	1,411		$	857
	Liabilities incurred from acquisitions and new wells drilled	1,585		34			499
	Revision of previous estimates	151		(51		)	—
	Accretion expense	209		116			55
	Asset retirement obligations, end of period	$	3,455	$	1,510		$	1,411

Major_Customers

Major Customers	12 Months Ended
	Dec. 31, 2013
ConcentrationRiskDisclosureTextBlockAbstract	'
Major Customers	'
	Major Customers
	The majority of the Partnership's oil and natural gas properties produce from the Hunton formation in east-central Oklahoma. The following table represents oil and natural gas sales by customer who purchased more than 10% of our production for the years ended December 31,:
	Purchaser	2013	2012	2011
	Scissortail	80%	84%	90%
	United Petroleum Purchasing	14%	16%	<10%
	This market is served by multiple oil and natural gas purchasers. As a result, the Partnership believes the loss of any one purchaser would not have a material adverse effect on the ability of the Partnership to sell its oil and natural gas production.

Credit_Facility_and_Factoring_

Credit Facility and Factoring Payable	12 Months Ended
	Dec. 31, 2013
DebtDisclosureTextBlockAbstract	'
Credit Facility and Factoring Payable	'
	Credit Facility and Factoring Payable
	Credit Facility:
	On February 13, 2013, in connection with the closing of the IPO, the Partnership entered into a Credit Agreement by and among the Partnership, as borrower, Bank of Montreal, as administrative agent for the lenders party thereto (the “Administrative Agent”), and the other lenders party thereto (the “Credit Agreement”).
	The Credit Agreement is a four-year, senior secured revolving credit facility. The borrowing base is subject to redetermination on a semi-annual basis based on an engineering report with respect to the estimated oil and natural gas reserves of the Partnership, which will take into account the prevailing oil and gas prices at such time, as adjusted for the impact of commodity derivative contracts. The Credit Agreement is available for working capital for exploration and production and for general partnership purposes.
	On February 28, 2013, the Partnership entered into a First Amendment (the “First Amendment”) to its Credit Agreement. The First Amendment (i) added a lender under the Credit Agreement, (ii) increased the Partnership’s borrowing base under the Credit Agreement from $30 million to $60 million, (iii) increased the lenders’ aggregate commitment under the Credit Agreement from $60 million to $150 million and (iv) removed references and provisions related to the $25 million subordinated promissory note (the “Subordinated Note”) issued by the Partnership to New Source in connection with the Partnership’s initial public offering. As a condition precedent to effectiveness of the First Amendment, the Partnership repaid the Subordinated Note in full.
	On June 25, 2013, the Partnership entered into a Second Amendment (the “Second Amendment”) to its Credit Agreement. The Second Amendment (i) added two lenders under the Credit Agreement, and (ii) increased the Partnership’s borrowing base under the Credit Agreement from $60 million to $75 million.
	On October 29, 2013, the Partnership entered into a Third Amendment (the “Third Amendment”) to its Credit Agreement. The Third Amendment (i) adds a lender under the Credit Agreement, and (ii) increases the Partnership’s borrowing base under the Credit Agreement from $75 million to $87.5 million.
	On November 12, 2013, the Partnership entered into a Fourth Amendment (the “Fourth Amendment”) to its Credit Agreement. The Fourth Amendment amends certain provisions of the Credit Agreement with respect to the MCE Acquisition. The Fourth Amendment, among other things, provides that (i) the MCE Entities are not a “Subsidiary” for the purposes of the Credit Agreement, (ii) the Partnership may include actual cash dividends paid by MCE to the Partnership in the Partnership’s calculation of financial covenants, (iii) the Partnership may use proceeds of the Credit Agreement to make permitted investments in the MCE Entities and (iv) future investments in the MCE Entities may be made (a) with proceeds of the sales of the Partnership’s common units or (b) in an amount not to exceed $5.0 million in any twelve month period (without regard to any investments made pursuant to clause (a)), in each case, subject to certain limitations.
	The Credit Agreement requires NSLP to maintain a ratio of EBITDA (earnings before interest, depletion, depreciation and amortization, and income taxes) to interest expense of not less than 2.5 to 1.0, a ratio of total debt to EBITDA of not more than 3.5 to 1.0 and a ratio of consolidated current assets to consolidated current liabilities of not less than 1.0 to 1.0, in each case as more fully described in the Credit Agreement.
	Additionally, the Credit Agreement contains various covenants and restrictive provisions that, among other things, limits the ability of the Partnership to incur additional debt, guarantees or liens; consolidate, merge or transfer all or substantially all of its assets; make certain investments, acquisitions or other restricted payments; modify certain material agreements; engage in certain types of transactions with affiliates; dispose of assets; incur commodity hedges exceeding a certain percentage of production; and prepay certain indebtedness. Notwithstanding the foregoing, the Credit Agreement permits the Partnership to make distributions to its common unit holders in an amount not to exceed “Available Cash” (as defined in the Partnership's limited partnership agreement) so long as (i) no default or event of default has occurred and is continuing or would result therefrom and (ii) borrowing base utilization under the Credit Agreement does not exceed 90%. At December 31, 2013, under the most restrictive terms of our covenants, partners’ capital of $7.5 million was available for distribution.
	Events of default under the Credit Agreement include, but are not limited to, the failure to make payments when due, breach of any covenants continuing beyond the cure period.
	Borrowings under the Credit Agreement bear interest at a base rate (a rate equal to the highest of (a) the Federal Funds Rate plus 0.5%, (b) the Administrative Agent’s prime rate or (c) LIBOR plus 1.00%) or LIBOR, in each case plus an applicable margin ranging from 1.50% to 2.25%, in the case of a base rate loan, or from 2.50% to 3.25%, in the case of a LIBOR loan (determined with reference to the borrowing base utilization). The unused portion of the borrowing base is subject to a commitment fee of 0.50% per annum. Accrued interest and commitment fees are payable quarterly, or in the case of certain LIBOR loans, at shorter intervals and the variable rate was approximately 3.25% per annum at December 31, 2013. The Credit Agreement does not require principal repayments, unless the outstanding balance exceeds the borrowing base, and matures on February 13, 2017. As of December 31, 2013, the Partnership had $78.5 million outstanding under the Credit Agreement and, as a result, had $9.0 million of available borrowing capacity.
	All of the partnership's oil and gas properties serve as collateral for borrowings under the credit agreement. The Partnership was in compliance with all covenants of the Credit Agreement as of December 31, 2013.
	Credit Facility (Pre IPO):
	As of December 31, 2012, the Partnership had approximately $68.0 million outstanding under its credit facility, which related to a $150.0 million four-year credit facility with the Bank of Montreal entered into in August, 2011 ("Credit Facility-Pre IPO"). The borrowing base was re-determined in August, 2012 and was reduced from $72.5 million to $70 million. The Credit Facility-Pre IPO was paid off in full with proceeds from the Offering in 2013.
	Factoring Payable:
	The Partnership is a party to a secured borrowing agreement to factor the accounts receivable of the Oilfield Services Segment. The Partnership receives 90% funding immediately, and 10% is held in a reserve account with the factoring company for each invoice that is factored. Customers remit payment directly to the factoring company. Based on the number of days until collection, there is a tiered interest schedule (rates increase each 15 day period up to a maximum of 5% or an annualized rate of 20%) that is charged against the Partnership’s reserve account. The remaining amount in the reserve account is then released to the Partnership on a weekly basis as collections occur. If a receivable is not collected within 90 days, the receivable is repurchased by the Partnership out of either the Partnership's reserve fund or current advances. Proceeds from the arrangement are reflected as borrowings in our financial statements.
	The outstanding balance was $1.9 million as of December 31, 2013. Fees of $39,888 were incurred for the period November 12, 2013 (date of acquisition) through December 31, 2013, and are included in interest expense. MCE paid all outstanding balances and terminated this agreement in February 2014.

Longterm_Debt

Long-term Debt	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Long-term Debt	'
	Long-Term Debt
	The Partnership has $2.2 million in debt as of December 31, 2013 related to financing notes with various lending institutions for certain property and equipment through its Oilfield Services Segment. These notes range from 36-48 months in duration with maturity dates from May 2016 through April 2018 and carry variable interest rates ranging from 5.75% to 10.29%. All notes are associated with specific capital assets of the MCE Entities and are secured by MCE assets.
	The following is a schedule by years of minimum principal payments required under the Long-Term Debt and Credit Facility as of December 31, 2013 (in thousands):
	Year ended December 31,	Amount
	2014	$	719
	2015	766
	2016	558
	2017 (1)	78,651
	2018	39
	Total	$	80,733
	(1) Includes Credit Facility borrowings of $78.5 million maturing in February, 2017.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	Measurements of fair value of derivative instruments are classified according to the fair value hierarchy, which prioritizes the inputs to the valuation techniques used to measure fair value. As defined in Financial Accounting Standards Board Accounting Standards Codification Topic (“ASC”) 820-10, fair value is the price that would be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories:
	Level 1: Measured based on unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. The Partnership considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
	Level 2: Measured based on quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that the Partnership values using observable market data. Substantially all of these inputs are observable in the marketplace throughout the term of the derivative instrument, can be derived from observable data, or supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange traded derivatives such as oil swaps.
	Level 3: Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e. supported by little or no market activity). The Partnership’s valuation models are primarily industry standard models that consider various inputs including: (a) quoted forward prices for commodities, (b) time value, and (c) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Level 3 instruments primarily include derivative instruments, such as NGLs swaps, natural gas swaps for those derivatives that are indexed to local and non-observable indices, and oil, NGL and natural gas collars. Although management utilizes third party broker quotes to assess the reasonableness of our prices and valuation techniques, management does not have sufficient corroborating evidence to support classifying these assets and liabilities as Level 2.
	As required by ASC 820-10, financial assets and liabilities are classified 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 measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
	Fair Value on a Recurring Basis
	The following table sets forth by level within the fair value hierarchy the Partnership’s financial assets and liabilities that were accounted for at fair value on a recurring basis and recorded in other assets and derivative obligations in our Consolidated Balance Sheets as of December 31, 2013 and 2012 (in thousands):
		Active Markets for Identical Assets			Observable Inputs (Level 2)			Unobservable Inputs (Level 3)			Total Carrying Value
		(Level 1)
	Oil puts	$	—		$	28		$	—		$	28
	Oil collars	—			(57		)	—			(57		)
	Natural gas collars	—			—			(9		)	(9		)
	Oil and natural gas swaps	—			132			—			132
	Natural gas and NGL puts	—			—			403			403
	NGL swaps	—			—			(2,911		)	(2,911		)
	Balance December 31, 2013	$	—		$	103		$	(2,517	)	$	(2,414	)
	Oil and natural gas swaps	$	—		$	(17	)	$	—		$	(17	)
	NGL swaps	—			—			(112		)	(112		)
	Balance December 31, 2012	$	—		$	(17	)	$	(112	)	$	(129	)
	The Partnership estimates the fair values of the swaps based on published forward commodity price curves for the underlying commodities as of the date of the estimate for those commodities for which published forward pricing is readily available. For those commodity derivatives for which forward commodity price curves are not readily available, the Partnership estimates, with the assistance of third-party pricing experts, the forward curves as of the date of the estimate. The Partnership validates the data provided by third parties by understanding the pricing models used, obtaining market values from other pricing sources, analyzing pricing data in certain situations and confirming, where applicable, that those securities trade in active markets. The Partnership estimates the option value of puts and calls combined into hedges, market prices, contract parameters and discount rates based on published LIBOR rates. The determination of the fair values above incorporates various factors including the impact of our non-performance risk and the credit standing of the counterparties involved in the Partnership’s derivative contracts. The risk of nonperformance by the Partnership’s counterparties is mitigated by the fact that such current counterparties (or their affiliates) are also current or former bank lenders under the Partnership’s revolving credit facility. In addition, the Partnership routinely monitors the creditworthiness of its counterparties. As the factors described above are based on significant assumptions made by management, these assumptions are the most sensitive to change.
	The following table sets forth a reconciliation of changes in the fair value of allocated derivative assets and liabilities classified as Level 3 in the fair value hierarchy and recorded in net gain (loss) on commodity derivatives in our Consolidated Statement of Operations for the years ended December 31, (in thousands):
		Significant Unobservable Inputs
		Level 3
		2013			2012			2011
	Beginning balance	$	(112	)	$	(1,198	)	$	(1,108	)
	Realized gains (losses)	(1,670		)	5,965			(1,130		)
	Unrealized gains (losses)	(2,405		)	1,086			(90		)
	Settlements paid (received)	1,670			(5,965		)	1,130
	Ending balance	$	(2,517	)	$	(112	)	$	(1,198	)
	Change in unrealized gains (losses) included in earnings related to derivatives still held at period end	$	(2,446	)	$	(112	)	$	(90	)
	During periods of market disruption, including periods of volatile oil and natural gas prices, rapid credit contraction or illiquidity, it may be difficult to value certain of the Partnerships’ derivative instruments if trading becomes less frequent and/or market data becomes less observable. There may be certain asset classes that were in active markets with observable data that become illiquid due to changes in the financial environment. In such cases, more derivative instruments may fall to Level 3 and thus require more subjectivity and management judgment. As such, valuations may include inputs and assumptions that are less observable or require greater estimation as well as valuation methods which are more sophisticated or require greater estimation thereby resulting in valuations with less certainty. Further, rapidly changing commodity and unprecedented credit and equity market conditions could materially impact the valuation of derivative instruments as reported within our consolidated financial statements and the period-to-period changes in value could vary significantly. Decreases in value may have a material adverse effect on our results of operations or financial condition.
	See discussion regarding derivative classifications at Note 11.
	Fair Value on a Non-Recurring Basis
	The Partnership follows the provisions of ASC 820-10 for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. As it relates to the Partnership, ASC 820-10, applies to common stock issued for compensation purposes, the initial recognition of asset retirement obligations for which fair value is used and the considerations exchanged and certain nonfinancial assets and liabilities as may be acquired in business combinations.
	The Partnership utilizes ASC Topic 718, “Compensation-Stock Compensation,” to value shares issued for compensation purposes. Measurement of share-based payment transactions with employees is generally based on the grant date fair value of the equity instruments issued.
	Asset retirement cost estimates are derived from historical costs as well as the Partnership’s expectation of future cost to retire assets. As there is no corroborating market activity to support the assumptions used, the Partnership has designated these measurements as Level 3.
	The carrying amount of the Credit Facility of $78.5 million as of December 31, 2013 approximates fair value because the Partnership's current borrowing rate does not materially differ from market rates for similar bank borrowings. The revolving Credit Facility is classified as a Level 2 item within the fair value hierarchy.
	The fair value of the consideration and assets acquired and liabilities assumed related to Acquisitions (See Note 2) are classified as a Level 3 item within the fair value hierarchy.

Contingent_Consideration

Contingent Consideration	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Contingent Consideration	'
	Contingent Consideration
	A reconciliation of the beginning and ending balances of acquisition related accrued earnouts using significant unobservable inputs (Level 3) for the year ended December 31, is as follows (in thousands):
		2013
	Accrued earnout liability as of December 31, 2012	$	—
	Acquisition date fair value of contingent consideration - MCE Acquisition	6,320
	Acquisition date fair value of contingent consideration - Southern Dome Acquired Properties	1,600
	Change in fair value of contingent consideration	(1,600		)
	Payment of contingent consideration	—
	Accrued earnout liability as of December 31, 2013	$	6,320
	The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap. The contingent consideration was valued at $6.3 million at the acquisition date and was considered as a part of the purchase price of MCE (See Note 2). The fair value of this liability will be valued quarterly and adjusted through earnings accordingly. The estimated fair value as of December 31, 2013 is $6.3 million and is presented in contingent consideration payable to related parties on the accompanying Consolidated Balance Sheets. The fair value of the contingent consideration was determined through the use of a Monte Carlo simulation, which takes a model with user-defined variables and runs it repeatedly, using a different value for each variable during each run, or trial. The simulation randomly generates the value used for each variable in each trial; however, the user defines permitted and most likely values of the variables through the use of probability distributions.
	The Partnership agreed to provide additional consideration to Scintilla in November 2014 if the production attributable to the Southern Dome Acquired Properties for the nine-month period ending September 30, 2014 exceeds the average daily production of 383.5 Boe/d during the period between January 1, 2014 and September 30, 2014. We may satisfy any such additional consideration in cash, Partnership common units, or a combination thereof at our discretion. The contingent consideration was valued at $1.6 million at the acquisition date and was considered as part of the purchase price of the Southern Dome Acquired Properties (See Note 2). The fair value of the contingent consideration of $1.6 million, which represents the probability weighted contingent payment as a percentage of high, mid, and low production projections, was recorded in long term related party payables. The fair value of this liability will be adjusted through earnings accordingly. Based on current estimated production levels for the nine-month period ending September 30, 2014, the Partnership estimated the fair value as of December 31, 2013 is $0. The change in fair value of $1.6 million recorded as other income on the accompanying Consolidated Statements of Operations.

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2013
DerivativesAndFairValueTextBlockAbstract	'
Derivative	'
	Derivatives
	Due to the volatility of oil and natural gas prices, the Partnership periodically enters into price-risk management transactions (e.g., swaps, collars or puts) for a portion of its oil, natural gas and NGL production to achieve a more predictable cash flow, as well as to reduce exposure from price fluctuations. While the use of these arrangements limits the Partnership’s ability to benefit from increases in the prices of oil, natural gas and NGLs, it also reduces the Partnership’s potential exposure to adverse price movements. The Partnership’s arrangements, to the extent it enters into any, apply to only a portion of its production, provide only partial price protection against declines in oil and natural gas prices and limit the Partnership’s potential gains from future increases in prices. None of these instruments are used for trading or speculative purposes.
	Under ASC Topic 815, "Derivatives and Hedging," all derivative instruments are recorded on the consolidated balance sheets at fair value as either short-term or long-term assets or liabilities based on their anticipated settlement date. The Company will net derivative assets and liabilities for counterparties where it has a legal right of offset. Changes in the derivatives' fair values are recognized currently in earnings since the Company has elected not to designate its current derivative contracts as hedges. . See discussion of fair value instruments at Note 9.
	By using derivative instruments to mitigate exposures to changes in commodity prices, the Partnership exposes 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 is positive, the counterparty owes the Partnership, which creates credit risk. The Partnership minimizes the credit or repayment risk in derivative instruments by entering into transactions with high-quality counterparties.
	The following table sets forth a reconciliation of the changes in fair value of the Partnership's commodity derivatives for the years ended December 31, 2013, 2012, and 2011 (in thousands).
		2013			2012			2011
	Beginning fair value of commodity derivatives	$	(129	)	$	(1,199	)	$	(1,349	)
	Total gain (loss) on commodity derivatives	(5,548		)	7,057			(1,349		)
	Commodity derivative premiums paid	1,334			—			—
	Commodity derivative cash settlements paid (received)	1,929			(5,987		)	1,499
	Ending fair value of commodity derivatives	$	(2,414	)	$	(129	)	$	(1,199	)
	Certain of our commodity derivatives are presented on a net basis on the Consolidated Balance Sheets. The following table summarizes the gross fair values of our commodity derivative instruments, presenting the impact of offsetting the derivative assets and liabilities recorded in other assets and derivative obligations on our Consolidated Balance Sheets as of December 31 for the periods indicated below (in thousands):
		December 31, 2013
		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts Presented in the Consolidated Balance Sheet
	Offsetting Derivative Assets:
	Commodity derivatives	$	2,980		$	(2,190	)	$	790
	Offsetting Derivative Liabilities:
	Commodity Derivatives	$	(5,394	)	$	2,190		$	(3,204	)
		December 31, 2012
		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts Presented in the Consolidated Balance Sheet
	Offsetting Derivative Assets:
	Commodity derivatives	$	52		$	(27	)	$	25
	Offsetting Derivative Liabilities:
	Commodity Derivatives	$	(181	)	$	27		$	(154	)
	The follow table presents the fair value of derivative instruments outstanding as of December 31, (in thousands):
	Oil collars:		Volumes (Bbls)		Floor Price			Ceiling Price
	2014		80,444		$	80		$	103.5
	2015		42,649		$	80		$	93.25
	Natural gas collars:		Volumes (MMBtu)		Floor Price			Ceiling Price
	2014		1,528,083		$	4		$	4.41
	2015		1,364,382		$	4		$	4.32
	Oil put options:		Volumes (Bbls)		Floor Price
	2014		24,547		$	80
	Natural gas put options:		Volumes (MMBtu)		Floor Price
	2014		445,768		$	3.5
	2015		798,853		$	3.5
	2016		930,468		$	3.5
	Natural gas liquids put options:		Volumes (Bbls)		Average Floor Price
	2014		59,423		$	28.66
	Oil swaps:		Volumes (Bbls)		Fixed Price per Bbl
	2014		14,634		$	90.2
	2015		39,411		$	88.9
	2016		36,658		$	86
	Natural gas swaps:		Volumes (MMBtu)		Average Price per MMBtu
	2014		1,102,183		$	4.09
	2015		800,573		$	4.25
	2016		629,301		$	4.37
	Natural gas liquid swaps:		Volumes (MMBtu)		Average Price
	2014		643,779		$	39.79
	2015		84,793		$	82.74
	Oil swaps:		Volumes (Bbls)		Fixed Price per Bbl
	2013		41,843		$	93.05
	2014		15,905		$	90.2
	Natural gas liquids put options:		Volumes (Bbls)		Average Floor Price
	2013		89,333		$	40.71
	2014		34,410		$	39.39
	Natural gas swaps:		Volumes (MMBtu)		Average Price per MMBtu
	2013		436,105		$	3.6

Unitholders_Equity

Unitholders' Equity	12 Months Ended
	Dec. 31, 2013
Equity [Abstract]	'
Unitholders' Equity	'
	Unitholders' Equity
	The Units
	The common units and the subordinated units are separate classes of limited partner interests. The holders of units are entitled to participate in partnership distributions and exercise the rights or privileges available to limited partners under our partnership agreement.
	Common Units
	The common units have limited voting rights as set forth in our partnership agreement.
	Subordinated Units
	All of the subordinated units are held by New Source. The partnership agreement provides that, during the subordination period, the common units have the right to receive distributions of Available Cash from Operating Surplus (each as defined in the Partnership’s agreement) each quarter in an amount equal to $0.525 per common unit (the “Minimum Quarterly Distribution”), plus any arrearages in the payment of the Minimum Quarterly Distribution from Operating Surplus on the common units from prior quarters, before any distributions of Available Cash from Operating Surplus may be made on the subordinated units. These units are deemed “subordinated” because for a period of time, referred to as the subordination period, the subordinated units will not be entitled to receive any distributions from Operating Surplus until the common units have received the Minimum Quarterly Distribution plus any arrearages from prior quarters. Additionally, beginning with the first quarter of 2014 and continuing through the fourth quarter of 2016, if our average production declines below 3,200 Boe/day for any preceding four quarter period, then holders of our subordinated units will not be entitled to receive the quarterly distributions otherwise payable on our subordinated units for such quarter. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be Available Cash from Operating Surplus to be distributed on the common units. The subordination period will end on the first business day after the Partnership has earned and paid at least (i) $2.10 (the Minimum Quarterly Distribution on an annualized basis) on each outstanding common unit, subordinated unit and general partner unit for each of twelve consecutive quarters ending on or after December 31, 2015 or (ii) $2.63 (125.0% of the annualized Minimum Quarterly Distribution) on each outstanding common unit, subordinated unit and general partner unit and the related distribution on the incentive distribution rights for the four-quarter period immediately preceding that date. When the subordination period ends, all subordinated units will convert into common units on a one-for-one basis, and all common units thereafter will no longer be entitled to arrearages. For purposes of the subordination period, any quarter in which holders of our subordinated units are not entitled to receive the distributions otherwise payable on the subordinated units pursuant to the minimum annual production requirement under the development agreement shall be included in any period of twelve consecutive quarters with respect to (i), so long as aggregate distributions equaling or exceeding the minimum quarterly distribution on all common, subordinated, general partner units and any other partnership interests that are senior or equal in right of distribution to the subordinated units were earned in respect of such quarter.
	Incentive Distribution Rights
	The General Partner currently holds the Incentive Distribution Rights (“IDRs”), but may transfer these rights separately from its general partner interest, subject to restrictions in the Partnership Agreement. The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and the General Partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of the General Partner and the unitholders in any available cash from operating surplus the Partnership distributes up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for the General Partner include its 2.0% general partner interest, assume the General Partner has contributed any additional capital necessary to maintain its 2.0% general partner interest and has not transferred its IDRs and there are no arrearages on common units.
			Total Quarterly		Marginal Percentage Interest in Distributions
			Distributions per Unit		Unitholders		General Partner
	Minimum Quarterly Distribution		$0.53		98%		2%
	First Target Distribution		up to $0.60375		98%		2%
	Second Target Distribution		above $0.60375 up to $0.65625		85%		15%
	Thereafter		above $0.65625		75%		25%
	Cash Distributions
	The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common, subordinated and general partner units during the year ended December 31, 2013, as shown in the following table (in thousands, except distribution per unit):
	2013 Distribution		Per Common Unit				Amount Paid to Common Unitholders		Amount Paid to Subordinated Unitholder		Amount Paid to General Unitholder		Total Distributions
	First Quarter		$	0.2742		-1	$	1,857	$	605	$	43	$	2,504
	Second Quarter		$	0.55			$	3,725	$	1,213	$	85	$	5,023
	Third Quarter		$	0.575			$	3,895	$	1,268	$	89	$	5,252
	Fourth Quarter		$	0.575		(2)(3)	$	4,400	$	1,268	$	89	$	5,757
	-1	Prorated to reflect 47 days of quarterly cash distribution rate of $0.525 per unit.
	-2	Distributions of $1.1 million were not paid on the 1,947,033 common units issued in conjunction with the MCE acquisition pursuant to an arrangement with sellers to forgo, with respect to such common units, their rights to distribution for the fourth quarter 2013 only.
	-3	Distribution was declared on January 21, 2014. Distributions of $0.3 million were paid on the 488,667 common units issued in conjunction with the CEU Acquisition in January 2014 due to the record date for the fourth quarter distribution being January 31, 2014. The fourth quarter distributions are not reflected in these financial statements.
	Future distributions are at the discretion of our board of directors and will depend on business conditions, earnings, our cash requirements and other relevant factors. The Partnership’s partnership agreement requires that, within 45 days after the end of each quarter, the Partnership distribute all of its available cash (as defined in the partnership agreement) to the partners of record on the applicable record date.
	Non-controlling Interest:
	As part of the MCE Acquisition mentioned, certain owners of MCE retained Class B Units in MCE LP. The MCE, LP partnership agreement provides that the Class B Units have the right to receive an increasing percentage (15%, 25% and 50%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels have been achieved at MCE. The Class B Units are classified as a separate equity classification titled non-controlling interest on the accompanying Consolidated Financial Statements. Any distribution to the Class B Units, will be recognized in the period earned and recorded as a reduction to net income attributable to New Source Energy Partners L.P. on the Consolidated Statements of Operations.
	The following table illustrates the percentage allocations of MCE's available cash from operating surplus between the Class A unitholders and the Class B unitholders based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of the Class A and Class B unitholders in any available cash from operating surplus the MCE Partnership distributes up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.”
					Marginal Percentage Interest in
					Distributions
			Total Quarterly Distributions per MCE Unit		MCE Class A Unitholders (the Partnership)		MCE Class B Unitholders
	Minimum Quarterly Distribution		$15,820		100%		—%
	First Target Distribution		Above $18,194 up to $19,776		85%		15%
	Second Target Distribution		Above $19,776 up to $23,731		75%		25%
	Third Target Distribution and Thereafter		Above $23,731		50%		50%

Earnings_Per_Common_and_Subord

Earnings Per Common and Subordinated Unit	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Common and Subordinated Unit	'
	Earnings Per Common and Subordinated Unit
	The computations of basic earnings per common unit and subordinated unit are based on the weighted average number of common units and subordinated units, respectively, outstanding during the applicable period. The Partnership’s subordinated units meet the definition of a participating security; therefore, the Partnership is required to use the two-class method in the computation of earnings per unit. Basic earnings per common unit and subordinated unit are determined by dividing net income allocated to the common units and subordinated units, respectively, after deducting the amount allocated to the Partnership’s general partner (including distributions to the general partner on its IDRs), by the weighted average number of outstanding common units and subordinated units, respectively, during the period. The Partnership has no potential common units outstanding. Therefore, the amounts of basic and diluted earnings per unit are the same.
	Pursuant to the partnership agreement, to the extent that the quarterly distributions exceed certain targets, the General Partner is entitled to receive certain incentive distributions that will result in more earnings proportionately being allocated to the General Partner than to the holders of common units and subordinated units. The Partnership’s earnings per unit calculations, which allocate 2% of earnings to the General Partner, reflect that, while such distribution to the General Partner with respect to its 2% general partner interest was made, no incentive distributions were permitted to be, or were, made to the General Partner because quarterly distributions declared by the board of directors for the fourth quarter of 2013 did not exceed the specified targets.
	Basic and diluted earnings per unit for the period from February 13, 2013 through December 31, 2013 were computed using the following components:
		Common Units		Subordinated Units		General Partner
	Numerator:
	Net income (in thousands)	$	16,929	$	4,099	$	291
	Denominator:
	Weighted average units outstanding	6,994,517		2,205,000		154,673
	Basic and diluted income per unit	$	2.42	$	1.86	$	1.88
	EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

EquityBased_Compensation

Equity-Based Compensation	12 Months Ended
	Dec. 31, 2013
DisclosureOfCompensationRelatedCostsShareBasedPaymentsTextBlockAbstract	'
Equity-Based Compensation	'
	Equity-Based Compensation
	On February 13, 2013, the Partnership granted 367,500 units of restricted common units to consultants, officers and other employees. Disposition of the units is restricted until the later of the termination of the subordination period or December 31, 2015. The award was valued at the IPO price of $20.00 per common unit and charged to equity-based compensation in general and administrative expenses at the date of the award. The restricted units do not contain a future service requirement from the recipients, so the amounts were fully vested as of February 13, 2013 and the Partnership recorded compensation expense of $7.4 million related to these awards as general and administrative expense in the accompanying Consolidated Statements of Operations for the year ended December 31, 2013.
	On November 12, 2013, as part of the MCE Acquisition, the Partnership granted 99,768 restricted common units to employees of MCE valued at $2.3 million that were included as part of the purchase price, which were all outstanding as of December 31, 2013. The units will vest over the period of three years, and are subject to vesting restrictions based on employment status. If such common units are forfeited for any reason prior to vesting, then within forty-five days of the end of each calendar year beginning on December 31, 2014, the Partnership will issue to those units forfeited by the employee to the former MCE owners. Equity-based compensation expense will be recognized straight-line over the three-year vesting period for fair value of these units. For the year ended December 31, 2013, the Partnership recognized $0.1 million in equity-based compensation expense and is presented as "Unit compensation funded by unitholders" on the accompanying Consolidated Statements of Partners' Capital and as general and administrative expense in the accompanying Consolidated Statements of Operations for the year ended December 31, 2013.
	Unamortized equity-based compensation expense related to these awards was $2.1 million as of December 31, 2013 and will be recognized on a straight line basis over 2.8 years.
	On August 18, 2011, New Source granted 2,900,000 shares of restricted common stock, with 1,000,000 shares vesting upon the first anniversary of the date of grant, 700,000 shares vesting on the second anniversary of the date of grant, and the remaining 1,200,000 shares vesting on the completion of the initial public offering of New Source's common stock pursuant to a filed prospectus provided that the employees remain employed by New Source on the applicable vesting dates subject to limited exceptions ("2011 Grant"). For periods January 1, 2013 to February 13, 2013, an allocated amount of New Source stock-based compensation related to these awards was recognized in the Partnership’s financial statements in the amount of $0.4 million as general and administrative expense in the accompanying Consolidated Statements of Operations for the year ended December 31, 2013.
	Equity-based compensation expense for the year ended December 31, 2012 and 2011 reflects an allocated amount of stock-based compensation expense from the 2011 Grant. Equity-based compensation expense for 2012 was the result of the amortization of the value to expense over the vesting periods for which there are fixed vesting terms of the awards. Accordingly, the Partnership recorded $8.2 million and $4.5 million of stock-based compensation as general and administrative expense in the accompanying Consolidated Statements of Operations for the years ended December 31, 2012 and 2011, respectively.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Information	'
	Segment Information
	In accordance with FASB ASC 280, Segment Reporting, the Partnership routinely evaluates whether it has separate operating and reportable segments. The Partnership has determined that it operates in two reportable operating segments, which are referred to as the Exploration and Production Segment and the Oilfield Services Segment. This determination is based on the following factors: (1) the Partnership’s chief operating decision maker is currently managing each segment as a separate business and evaluating the performance of each segment and making resource allocation decisions distinctly and expects to do so for the foreseeable future, and (2) discrete financial information for each segment is available. The following is a brief description of the Partnership’s operating segments:
	Exploration and Production Segment. The Exploration and Production Segment focuses on non-operated exploration, development and production of the Partnership’s onshore oil and natural gas properties portfolio of properties that extends across conventional resource reservoirs in east-central Oklahoma.
	Oilfield Services Segment. The Oilfield Services Segment offers full service blowout prevention installation and pressure testing services throughout the Mid-Continent region, along with the provision of certain ancillary equipment necessary to perform such services. The Oilfield Services Segment was acquired through the MCE Acquisition, which was completed on November 12, 2013.
	The following tables set forth certain financial information for our two operating segments as of and for the year ended December 31, 2013 (amounts in thousands):
		Exploration and Production Segment			Oilfield Services Segment			Total
	Identifiable assets	$	181,440		$	73,270		$	254,710
	Revenues	$	46,937		$	3,738		$	50,675
	Operating costs	(15,300		)	(2,040		)	(17,340		)
	Segment margin	$	31,637		$	1,698		$	33,335
	Depreciation and amortization	$	16,590		$	1,966		$	18,556
	Capital expenditures	$	48,319		$	445		$	48,764
	The following table reconciles the segment profits reported above to operating loss as reported on the Consolidated Statements of Operations for the year ended December 31, (amounts in thousands):
		2013
	Segment margin	$	33,335
	Depreciation and amortization	(18,556		)
	General and administrative	(14,760		)
	Accretion expense	(209		)
	Operating loss	$	(190	)

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
CommitmentsAndContingenciesDisclosureTextBlockAbstract	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Commitments
	The Partnership is a party to various agreements under which it has rights and obligations to participate in the acquisition and development of undeveloped properties held and to be acquired by Scintilla and New Dominion. These properties will be held by New Dominion for the benefit of the Partnership pending development of the properties. The Partnership is required by its underlying agreements with New Dominion to pay certain acreage fees to reimburse New Dominion for the cost of the acreage attributable to the Partnership’s working interest when invoiced by New Dominion. The Partnership recognizes an asset and corresponding liability as the acreage costs are incurred by New Dominion, as set forth in Note 3, Related Party Transactions.  The agreements require us to contribute capital for drilling and completing new wells and related project costs based on our proportionate ownership of each particular new well. There are significant penalties for a party’s election not to participate in a proposed well within the geographical areas covered by the agreements. The agreements also require us to pay New Dominion their proportionate share of maintenance and operating costs of New Dominion’s saltwater disposal wells.
	On February 13, 2013, in connection with the closing of the Offering, NSLP entered into a development agreement (the “Development Agreement”) by and among NSLP, New Source and New Dominion. Pursuant to the Development Agreement, during each of the fiscal years ending December 31, 2013 through December 31, 2016, NSLP has agreed to maintain an average annual maintenance drilling budget of at least $8.2 million to drill certain of NSLP’s proved undeveloped locations and maintain NSLP’s producing wells.
	Pursuant to the Development Agreement, the General Partner will, at least annually, at its discretion, determine NSLP’s maintenance drilling budget. The General Partner will also have the right to propose which wells are drilled based on NSLP’s maintenance drilling budget. Under the Development Agreement, New Dominion will use its commercially reasonable best efforts to (i) conduct its operations such that NSLP’s proportionate share of capital expenses that it would consider maintenance capital under the Participation Agreement is equal to the annual maintenance drilling budget set by the General Partner and (ii) cause the wells drilled pursuant to the Participation Agreement to be consistent with the maintenance drilling schedule proposed by the General Partner. The General Partner will also have the ability to approve deviations from either the maintenance drilling budget (upward or downward) or the drilling schedule (additions, deletions or substitutions) to the extent proposed by New Dominion.
	New Dominion serves as the operator for all of our properties. The successful operation of our exploration and production business depends on continued utilization of New Dominion’s oil and natural gas infrastructure and technical staff as the operator of our properties. Failure of New Dominion to perform its obligations could have a material adverse effect on our operations and our financial results.
	Legal Matters
	New Dominion is a defendant in a legal proceeding arising in the normal course of its business, which may impact the Partnership as described below.
	In the case of Mattingly v. Equal Energy, LLC, New Dominion is a named defendant. In this case, the plaintiffs assert claims on behalf of a class of royalty owners in wells operated by New Dominion and others from which natural gas is sold by New Dominion to Scissortail Energy, LLC. The plaintiffs assert that royalties to the class should be paid based upon the price received by Scissortail for the gas and its components at the tailgate of the plant, rather than the price paid by Scissortail at the wellhead where the gas is purchased. The plaintiffs assert a variety of breach of contract and tort claims. The case was originally filed in the District Court of Creek County, Oklahoma and was removed by the defendants to the federal court but was remanded to state court on August 1, 2011.
	If liability does attach to New Dominion as operator, New Dominion would look to the working interest owners to pay their proportionate share of any liability. While the outcome and impact on the Partnership of this proceeding cannot be predicted with certainty, management believes a range of loss from $10,000 to $250,000 may be reasonably possible.
	The Partnership may be involved in other various routine legal proceedings incidental to its business from time to time. However, there were no other material pending legal proceedings to which the Partnership is a party or to which any of its assets are subject.
	Lease Obligations
	The following is schedule by year of lease obligations and minimum lease payments for non-cancellable leases with a term of more than one year at December 31, 2013 (in thousands):
	Year	Operating Leases
	2014	$	175
	2015	88
	2016	3
	Total	$	266

Quarterly_Results_of_Operation

Quarterly Results of Operations (unaudited)	12 Months Ended
	Dec. 31, 2013
Selected Quarterly Financial Information [Abstract]	'
Quarterly Results of Operations (unaudited)	'
	Quarterly Results of Operations (unaudited)
	The following table summarizes quarterly financial data for the years ended December 31, 2013 and 2012 (in thousands, except per unit data):
		Quarter Ended
	2013	March 31 (1) (2)			30-Jun			30-Sep			31-Dec
	Revenues	$	9,360		$	10,649		$	12,431		$	18,235
	Income (loss) from operations	(6,118		)	2,456			2,121			1,351
	Income tax (expense) benefit	12,126			—			—			—
	Net income (loss)	$	(1,397	)	$	8,151		$	(1,986	)	$	21,854
	Earnings (loss) per unit
	Basic	$	(0.87	)	$	0.89		$	(0.22	)	$	2.05
	Diluted	$	(0.87	)	$	0.89		$	(0.22	)	$	2.05
	2012 (2)
	Revenues	$	10,031		$	8,156		$	8,262		$	9,147
	Income (loss) from operations	(354		)	(1,919		)	1,009			2,314
	Income tax (expense) benefit	144			(1,871		)	562			(631		)
	Net income (loss)	$	(108	)	$	2,921		$	(799	)	$	1,095
	-1	The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.
	-2	EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
SubsequentEventsTextBlockAbstract	'
Subsequent Events	'
	Subsequent Events
	CEU Acquired Properties
	On January 31, 2014, we completed the acquisition of the CEU Acquired Properties, which included working interests in 23 producing wells and related undeveloped leasehold rights in the Southern Dome field in Oklahoma County, Oklahoma from CEU Paradigm, LLC.
	As consideration for the working interests, we paid $6.9 million in cash to the seller at closing and issued 488,667 common units valued at $23.51 per common unit to the seller. We also agreed to provide additional consideration to the seller in November 2014 if the production attributable to the working interests for the nine-month period ending September 30, 2014 exceeds a certain production average, which was valued at $2.3 million on the acquisition date and is part of the purchase price. We may satisfy any such additional consideration in cash, common units, or a combination thereof at our discretion. Total consideration for the acquisition was $20.7 million.
	Other
	On January 8, 2013, MCE entered into five separate loan agreements with G.E. Financial. These notes are for five separate pieces of equipment with loan amounts ranging from $141,842 to $251,110. Each note begins payments in February 2014 and range of principal amounts from $4,303 to $7,613 monthly, with interest at 5.75% over 48 months, maturing in January 2018. Each of the notes is collateralized by specific pieces of equipment.
	On February 11, 2014, MCE entered into a loan agreement with Bank of Oklahoma. The note evidences a revolving line of credit of up to $4.0 million, based on a borrowing base related to the Oilfield Service Segment's accounts receivable, with interest only payments due monthly, maturing February 10, 2016.  The note replaced MCE's factoring agreement (See Note 7). The interest rate on this note is BOKF National Prime Rate. This note is secured by accounts receivable, inventory, chattel paper and general intangibles of MCE.
	On March 10, 2014, MCE entered into a loan agreement with Legacy Bank. The note is for $2,484,703 with payments of $58,173 over 48 months at an interest rate of 5.75%, and it matures March 10, 2018.  The note is secured by certain vehicles owned by MCE.
	On January 21, 2014, our general partner's board of directors approved a cash distribution of $0.575 per unit payable on February 14, 2014 to unitholders of record on January 31, 2014.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Significant Accounting Policies (Abstract)	'
Use of Estimates, Policy	'
	Use of Estimates in the Preparation of the Consolidated Financial Statements
	Preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from these estimates. Depletion of oil and natural gas properties is determined using estimates of proved oil and natural gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and natural gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves. Other significant estimates include, but are not limited to: the valuation of commodity derivatives; the allocation of general and administrative expenses; asset retirement obligations; goodwill/intangible impairment analysis; valuation of the consideration transferred for the MCE Acquisition; and the valuation of assets acquired and liabilities assumed in business combinations.
Consolidation, Policy	'
	Acquisitions
	The Partnership accounts for acquired businesses using the acquisition method of accounting, which requires that the assets acquired, liabilities assumed, contractual contingencies and contingent consideration be recorded at the date of acquisition at their respective fair values. Goodwill represents the excess of the purchase price, including any contingent consideration, over the fair value of the identifiable net assets acquired. It further requires acquisition related costs to be recognized separately from the acquisition and expensed as incurred.
	The fair value of identifiable long-lived assets is based on significant judgments made by management of the Partnership. The Partnership typically engages third party valuation appraisal firms to assist in determining the fair values and useful lives of the identifiable long-lived assets acquired in the Oilfield Services Segment. Such valuations and useful life determinations require the Partnership to make significant estimates and assumptions. These estimates and assumptions are based on historical experience and information obtained from management, and also include, but are not limited to, future expected cash flows and discount rates applied in determining the present value of those cash flows. Unanticipated events and circumstances may occur that could affect the accuracy or validity of such assumptions, estimates or actual results. Acquired identifiable intangible assets are amortized on a pattern that is consistent with the net cash flows they are expected to produce over their estimated economic lives.
Receivables, Policy	'
	Accounts Receivable
	Accounts receivable consist of the following as of December 31, (in thousands):
		2013			2012
	Oil and natural gas sales receivables	$	8,417		$	5,621
	Oil and natural gas sales receivables - related parties	228			42
	Oilfield services receivables	3,964			—
	Total accounts receivable	$	12,609		$	5,663
	Accounts receivable are customer obligations due under normal trade terms and are presented on the Consolidated Balance Sheets net of allowances for doubtful accounts. Customers are granted credit in the ordinary course of business and generally do not require collateral. Based on management’s best estimate of the amount of probable credit losses in the Partnership's existing accounts receivable, it has concluded that realization of losses on balances outstanding at December 31, 2013 and 2012 will be immaterial; therefore, no allowance for doubtful accounts is deemed necessary. However, actual write-offs may occur. As part of the factoring payable mentioned below, certain of MCE's accounts receivable are pledged as collateral.
Property, Plant and Equipment, Policy	'
	Property and Equipment
	Property and equipment are capitalized and recorded at cost, while maintenance and repairs are expensed. Depreciation of property and equipment is provided when assets are placed in service using the straight-line method based on estimated useful lives ranging from three to ten years.
Oil and Gas Properties, Policy	'
	Oil and Natural Gas Properties
	The Partnership utilizes the full cost method of accounting for oil and natural gas properties whereby productive and nonproductive costs incurred in connection with the acquisition, exploration, and development of oil and natural gas reserves are capitalized. All capitalized costs of oil and natural gas properties and equipment, including the estimated future costs to develop proved reserves, are amortized to depreciation, depletion and amortization ("DD&A") expense using the units-of-production method based on total proved reserves. Historically, full cost pool amortization was recorded on a carve-out basis based on relative production from the Partnership compared to total production of New Source. No gains or losses are recognized upon the sale or other disposition of oil and natural gas properties except in transactions that would significantly alter the relationship between capitalized costs and proved reserves. Under the full cost method, the net book value of oil and natural gas properties may not exceed the estimated after-tax future net revenues from proved oil and natural gas properties, discounted at 10% (the ceiling limitation). In arriving at estimated after-tax future net revenues, estimated lease operating expenses, development costs, and certain production-related and ad valorem taxes are deducted. In calculating future net revenues, prices and costs in effect at the time of the calculation are held constant indefinitely, except for changes that are fixed and determinable by existing contracts. The net book value is compared to the ceiling limitation on a quarterly and yearly basis. The excess, if any, of the net book value above the ceiling limitation is charged to expense in the period in which it occurs and is not subsequently reinstated. Reserve estimates used in determining estimated future net revenues have been prepared by an external petroleum engineering firm. Future net revenues were computed based on reserves using prices calculated as the unweighted arithmetical average oil and natural gas prices on the first day of each month within the latest twelve-month period. Subsequent to February 13, 2013, the ceiling limitation computation is determined without regard to income taxes due to the Partnership being a non-income tax paying entity.
Goodwill and Intangible Assets, Goodwill, Policy	'
	Intangible Asset - Customer Relationships
	As part of the MCE Acquisition on November 12, 2013, $36.8 million of customer relationships intangible assets were recognized as part of the purchase price allocation (see Note 2). The amortization of customer relationships reflects a pattern in which the economic benefits of the assets will be consumed or used up. Amortization was estimated by using an accelerated method over 7 years similar to the expected cash flow pattern of the acquired customer relationships, estimated for each of the five succeeding years ending December 31, as follows (in thousands):
			Total
	2014		$	12,366
	2015		8,689
	2016		5,264
	2017		3,425
	2018		1,839
	Thereafter		3,426
			$	35,009
	Amortization expense was $1.8 million for the year ended December 31, 2013. The Partnership did not incur any amortization expense for customer relationships for the years ended December 31, 2012 and 2011.
	The Partnership evaluates for potential impairment of long-lived assets, including intangible assets, subject to amortization when indicators of impairment are present. Circumstances that could indicate a potential impairment include losses of significant customers, significant adverse changes in industry trends, economic climate, legal factors, and an adverse action or assessment by a regulator. More specifically, significant adverse changes in industry trends, including oil and natural gas market prices could indicate a potential impairment. In performing an impairment evaluation, the Partnership estimates the future undiscounted net cash flows from the use and eventual disposition of the intangible asset grouped at the lowest level that cash flows can be identified. If the sum of the estimated future undiscounted net cash flows is less than the carrying amount, an impairment charge would be measured as the difference between the carrying amount and the fair value of these assets. The assumptions used in the impairment evaluation for long-lived assets are inherently uncertain and require management judgment. The Partnership did not record any impairment of long-lived assets for the years ended December 31, 2013, 2012 or 2011.
	Goodwill
	Goodwill represents consideration paid in excess of the fair value of the identifiable assets acquired in a business combination. In connection with the acquisition of MCE on November 12, 2013 (see Note 2), the Partnership recorded $24.0 million of goodwill, which represents the goodwill balance at December 31, 2013. Goodwill is not amortized, but is reviewed for impairment annually based on the carrying values as of November 1, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered.
	In evaluating possible impairment of goodwill, the Partnership performs a qualitative assessment to determine whether it is more likely than not that the fair value of the reporting unit is impaired. Management uses all available information to make these determinations, including evaluating the macroeconomic environment, industry specific conditions, cost factors, overall financial performance and unit price, at the assessment date. The Partnership did not record any impairment of goodwill for the years ended December 31, 2013, 2012 or 2011.
Business Combinations, Policy	'
	Contingent Consideration Payable to Related Parties
	Contingent consideration, which includes earnout payments in connection with the Partnership’s acquisitions, is recognized at fair value on the acquisition date and remeasured each reporting period with subsequent adjustments recognized in our Consolidated Statements of Operations. The Partnership estimates the fair value of contingent consideration liabilities based on certain performance milestones of the acquired companies or properties, and estimated probabilities of achievement, then discounts the liabilities to present value using the Partnership’s cost of debt. Contingent consideration is valued using significant inputs that are not observable in the market which are defined as Level 3 inputs pursuant to fair value measurement accounting. The Partnership believes its estimates and assumptions are reasonable, however, there is significant judgment involved. At each reporting date, the contingent consideration liability is revalued to estimated fair value.
	Changes in the fair value of contingent consideration liabilities may result from changes in discount periods, changes in the timing and amount of sales and/or other specific milestone estimates and changes in probability assumptions with respect to the likelihood of achieving the various earnout criteria. These changes could cause a material impact to, and volatility in our operating results. Earnout payments, if any, will be reflected in cash flows from financing activities and the changes in fair value are reflected in cash flows from operating activities in our Consolidated Statements of Cash Flows. See Note 10 for contingent consideration activity.
Environmental Costs, Policy	'
	Environmental
	Oil and natural gas properties are subject to extensive federal, state and local environmental laws and regulations. These laws, which are often changing, regulate the discharge of materials into the environment and may require the removal or mitigation of the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Liabilities for expenditures of a noncapital nature are recorded when environmental assessment and/or remediation is probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable.
Revenue Recognition, Policy	'
	Revenue Recognition
	Oil and natural gas sales are recognized when production is sold to a purchaser at a fixed or determinable price, delivery has occurred, title has transferred, and collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a pipeline, railcar or truck, or a tanker lifting has occurred. The sales method of accounting is used for oil and natural gas sales such that revenues are recognized based on the actual proceeds from the oil and natural gas sold to purchasers. Oil and natural gas imbalances are generated on properties for which two or more owners have the right to take production “in-kind” and, in doing so, take more or less than their respective entitled percentage. For the years ended December 31, 2013, 2012 and 2011 there were no significant oil and natural gas imbalances.
	The Oilfield Services Segment's service and rental revenue is recognized when persuasive evidence of an arrangement exists, the product or service has been provided, the price is fixed or determinable and collection is reasonably assured, which is generally at the time the service is provided.
Asset Retirement Obligations, Policy	'
	Asset Retirement Obligations
	Liabilities associated with asset retirement obligations are recorded at fair value in the period in which they are incurred or when properties are acquired with a corresponding increase in the carrying amount of the related oil and natural gas properties. Subsequently, the asset retirement cost included in the carrying amount of the oil and natural gas properties and is allocated to expense through DD&A. Changes in the liability due to passage of time are recognized as an increase in the carrying amount of the liability and as corresponding accretion expense.
Share-based Compensation, Option and Incentive Plans Policy	'
	Equity-Based Compensation
	Awards under the Partnership’s long-term incentive plan may consist of restricted stock grants, equity option awards, and other awards issuable to employees and non-employee directors. The Partnership recognizes in its consolidated financial statements the cost of employee services received in exchange for awards of equity instruments based on the fair value of those awards at their grant date. If an award has a fixed vesting date, the cost is recognized over the period from the grant date to the vesting date(s) of the award. If an award does not have a fixed vesting date, the cost is recognized at the time it vests.
Income Tax, Policy	'
	Income Taxes
	Income taxes are reflected in these consolidated financial statements during the periods in which the IPO Properties were owned by a taxable entity. Since the Partnership is not a taxable entity, no income taxes have been provided for the periods following completion of the Offering. Upon the Partnership becoming a non-taxable entity, the Partnership recognized a tax benefit related to the change in tax status of approximately $12.1 million for the year ended December 31, 2013.
	The Company is a limited partnership for federal and state income tax purposes, with the exception of the state of Texas, in which income tax liabilities and/or benefits of the Company are passed through to its unitholders. Limited partnerships are subject to Texas margin tax.
	In accordance with the applicable accounting standards, the Partnership recognizes only the impact of income tax positions that, based on their merits, are more likely than not to be sustained upon audit by a taxing authority. To evaluate its current tax positions in order to identify any material uncertain tax positions, the Partnership developed a policy of identifying and evaluating uncertain tax positions that considers support for each tax position, industry standards, tax return disclosures and schedules and the significance of each position. It is the Partnership’s policy to recognize interest and penalties, if any, related to unrecognized tax benefits in income tax expense. The Partnership had no material uncertain tax positions at December 31, 2013, and December 31, 2012. The tax years 2010 – 2012 remain open to examination for federal income tax purposes.
	Net income for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax bases and financial reporting bases of assets and liabilities and the taxable income allocation requirements under the partnership agreement. In addition, individual unitholders have different investment bases depending upon the timing and price of acquisition of their common units, and each unitholder’s tax accounting, which is partially dependent upon the unitholder’s tax position, differs from the accounting followed in the consolidated financial statements. As a result, the aggregate difference in the basis of net assets for financial and tax reporting purposes cannot be readily determined as the Partnership does not have access to information about each unitholder’s tax attributes in the Partnership. However, with respect to the Partnership, the Partnership's book basis in its net assets exceeds the Partnership's net tax basis by $118.9 million at December 31, 2013.
Fair Value of Financial Instruments, Policy	'
	Fair Value of Financial Instruments
	The fair value of a financial instrument is the amount at which the instrument could be exchanged in an orderly transaction between two willing parties. The carrying amount of cash, accounts receivable, prepaid expenses, accounts payable, accrued expenses reported on the balance sheet approximates fair value. The carrying amount of the borrowings under the credit facility and our other borrowings reported on the balance sheets approximates fair value (level 2) because the debt instruments carry a variable interest rate based on market interest rates.
Derivatives, Policy	'
	Derivatives
	All derivative instruments are recognized as either assets or liabilities in the balance sheet at fair value. None of such instruments have been designated as cash flow hedges. Accordingly, changes in the fair value of all derivative instruments have been recorded in the consolidated statements of operation

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of Accounts, Notes, Loans and Financing Receivable	'
	Accounts receivable consist of the following as of December 31, (in thousands):
		2013			2012
	Oil and natural gas sales receivables	$	8,417		$	5,621
	Oil and natural gas sales receivables - related parties	228			42
	Oilfield services receivables	3,964			—
	Total accounts receivable	$	12,609		$	5,663
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense	'
	Amortization was estimated by using an accelerated method over 7 years similar to the expected cash flow pattern of the acquired customer relationships, estimated for each of the five succeeding years ending December 31, as follows (in thousands):
			Total
	2014		$	12,366
	2015		8,689
	2016		5,264
	2017		3,425
	2018		1,839
	Thereafter		3,426
			$	35,009

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2013
Business Acquisition [Line Items]	'
Schedule of Business Acquisitions, by Acquisition	'
	A summary of the purchase price allocation made in connection with the MCE Acquisition is as follows (in thousands):
			12-Nov-13
	Cash Paid		$	3,781
	Fair value of common units granted (1)		41,822
	Common units granted to MCE employees (2)		2,259
	Earn-out amount (contingent consideration) (3)		6,320
	MCE Class B units granted (4)		13,988
	Total fair value consideration transferred		$	68,170
	-1	1,847,265 common units valued at $22.64 per unit.
	-2	99,768 common units valued at $22.64 per unit. These common units were issued to certain employees of MCE, under the Partnership’s long-term incentive plan. If the recipients of the common units do not remain employed by MCE for three years, then they forfeit the units. The common units do not revert to the Partnership, but would be distributed to the former owners of MCE. The $2.3 million fair value of the common units is included in the consideration transferred for the MCE Acquisition, as the units do not revert back to the Partnership upon any circumstance. Since this compensation arrangement is funded by unitholders, the compensation will be reflected in the accompanying Consolidated Statements of Operations over the three-year straight-line vesting period. See Note 14, Equity-Based Compensation, for more information.
	-3	The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date and was considered as part of the purchase price of MCE. The Partnership determined the fair value of the MCE Contingent Consideration with the assistance of a third-party valuation specialist through the use of a Monte Carlo simulation, which allows for an open-form approach to allocate value. The simulation generates value based on probability distributions similar to those used under closed-form models.
	-4	Certain owners of MCE retained Class B Units, which entitle the holders to receive incentive distributions of cash distributed by MCE above specified thresholds in increasing amounts (see Note 12). The Class B units were valued at $14.0 million at the acquisition date and were considered as part of the purchase price of MCE.
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The following table summarizes the assets acquired and the liabilities assumed as of the acquisition date at estimated fair value (in thousands):
			November 12, 2013
	Assets
	Cash		$	1,522
	Accounts receivable		3,365
	Other current assets		954
	Property and Equipment		7,923
	Intangible asset - customer relationship		36,772
	Goodwill		23,974
	Other assets		19
	Liabilities
	Accounts payable		(1,199		)
	Accounts payable - related parties		(870		)
	Accrued liabilities		(276		)
	Factoring payable		(1,679		)
	Current portion of long-term debt		(719		)
	Long-term debt		(1,616		)
	Net assets acquired		$	68,170
Business Acquisition, Pro Forma Information	'
	The following unaudited pro forma consolidated financial information has been prepared as if the Material Acquisitions occurred on January 1, 2012 for the years ending December 31, (in thousands, except per unit data).
		Pro forma
		2013				2012
	Revenue:
	As reported	$	50,675			$	35,596
	Pro forma	$	77,892			$	67,599
	Net Income (loss):
	As reported	$	26,622			$	3,109
	Pro forma	$	(3,438	)		$	12,420
	Basic net income (loss) per unit:
	As reported	$	2.42
	Pro forma	$	(0.36	)
	Diluted net income (loss) per unit:
	As reported	$	2.42
	Pro forma	$	(0.36	)
March Acquired Properties	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		29-Mar-13
	Proved oil and natural gas properties	$	29,049
	Other assets acquired	754
	Fair value of assets acquired	29,804
	Asset retirement obligations	(1,333		)
	Other liabilities assumed	(488		)
	Fair value of net assets acquired	$	27,984
May Acquired Properties	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		31-May-13
	Proved oil and natural gas properties	$	8,165
	Fair value of assets acquired	8,165
	Asset retirement obligations	(19		)
	Other liabilities assumed	(254		)
	Fair value of net assets acquired	$	7,893
July Acquired Properties	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		23-Jul-13
	Proved oil and natural gas properties	$	4,888
	Fair value of assets acquired	4,888
	Asset retirement obligations	(4		)
	Other liabilities assumed	(18		)
	Fair value of net assets acquired	$	4,866
Orion Acquisition	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		25-Jul-13
	Proved oil and natural gas properties	$	3,274
	Fair value of assets acquired	3,274
	Asset retirement obligations	(24		)
	Other liabilities assumed	(20		)
	Fair value of net assets acquired	$	3,230
Southern Dome	'
Business Acquisition [Line Items]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The total purchase price allocated to the assets purchased and liabilities assumed based upon fair value on the date of acquisition as follows (in thousands):
		4-Oct-13
	Proved oil and natural gas properties	$	15,190
	Fair value of assets acquired	15,190
	Asset retirement obligations	(170		)
	Other liabilities assumed	(552		)
	Fair value of net assets acquired	$	14,469

Related_Parties_Tables

Related Parties (Tables)	12 Months Ended
	Dec. 31, 2013
RelatedPartyTransactionsDisclosureTextBlockAbstract	'
Schedule of Related Party Transactions	'
	The expense amount incurred for these charges are as follows for the years ended December 31, (in thousands):
		2013		2012		2011
	Access fee charges	$	250	$	2,615	$	196
	Producing overhead charges	980		599		581
	Drilling and completion overhead charges	101		27		26
	Saltwater disposal fees	696		1,642		1,612
	Administrative fees	9		—		—
	Total expenses incurred	$	2,035	$	4,883	$	2,415

Property_and_Equipment_Tables

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	Major classes of property and equipment included the following at December 31, (in thousands):
		Useful life	2013
	Light-duty trucks	3 years	$	516
	Machinery and equipment	3-10 years	4,793
	Rental iron	20 years	2,971
	Other assets	3-7 years	88
	Less accumulated depreciation		(202		)
	Total Property and equipment, net		$	8,166

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
AssetRetirementObligationDisclosureTextBlockAbstract	'
Schedule of Asset Retirement Obligations	'
	The following table summarizes activity associated with asset retirement obligations for the years ending December 31, (in thousands):
		2013		2012			2011
	Asset retirement obligations, beginning of period	$	1,510	$	1,411		$	857
	Liabilities incurred from acquisitions and new wells drilled	1,585		34			499
	Revision of previous estimates	151		(51		)	—
	Accretion expense	209		116			55
	Asset retirement obligations, end of period	$	3,455	$	1,510		$	1,411

Major_Customers_Tables

Major Customers (Tables)	12 Months Ended
	Dec. 31, 2013
ConcentrationRiskDisclosureTextBlockAbstract	'
Schedule of Revenue by Major Customers by Reporting Segments	'
	The following table represents oil and natural gas sales by customer who purchased more than 10% of our production for the years ended December 31,:
	Purchaser	2013	2012	2011
	Scissortail	80%	84%	90%
	United Petroleum Purchasing	14%	16%	<10%

Longterm_Debt_Tables

Long-term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Debt Disclosure [Abstract]	'
Schedule of Maturities of Long-term Debt	'
	The following is a schedule by years of minimum principal payments required under the Long-Term Debt and Credit Facility as of December 31, 2013 (in thousands):
	Year ended December 31,	Amount
	2014	$	719
	2015	766
	2016	558
	2017 (1)	78,651
	2018	39
	Total	$	80,733
	(1) Includes Credit Facility borrowings of $78.5 million maturing in February, 2017.

Fair_Value_Measurements_Fair_V

Fair Value Measurements Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	he following table sets forth a reconciliation of changes in the fair value of allocated derivative assets and liabilities classified as Level 3 in the fair value hierarchy and recorded in net gain (loss) on commodity derivatives in our Consolidated Statement of Operations for the years ended December 31, (in thousands):
		Significant Unobservable Inputs
		Level 3
		2013			2012			2011
	Beginning balance	$	(112	)	$	(1,198	)	$	(1,108	)
	Realized gains (losses)	(1,670		)	5,965			(1,130		)
	Unrealized gains (losses)	(2,405		)	1,086			(90		)
	Settlements paid (received)	1,670			(5,965		)	1,130
	Ending balance	$	(2,517	)	$	(112	)	$	(1,198	)
	Change in unrealized gains (losses) included in earnings related to derivatives still held at period end	$	(2,446	)	$	(112	)	$	(90	)
	The following table sets forth by level within the fair value hierarchy the Partnership’s financial assets and liabilities that were accounted for at fair value on a recurring basis and recorded in other assets and derivative obligations in our Consolidated Balance Sheets as of December 31, 2013 and 2012 (in thousands):
		Active Markets for Identical Assets			Observable Inputs (Level 2)			Unobservable Inputs (Level 3)			Total Carrying Value
		(Level 1)
	Oil puts	$	—		$	28		$	—		$	28
	Oil collars	—			(57		)	—			(57		)
	Natural gas collars	—			—			(9		)	(9		)
	Oil and natural gas swaps	—			132			—			132
	Natural gas and NGL puts	—			—			403			403
	NGL swaps	—			—			(2,911		)	(2,911		)
	Balance December 31, 2013	$	—		$	103		$	(2,517	)	$	(2,414	)
	Oil and natural gas swaps	$	—		$	(17	)	$	—		$	(17	)
	NGL swaps	—			—			(112		)	(112		)
	Balance December 31, 2012	$	—		$	(17	)	$	(112	)	$	(129	)

Contingent_Consideration_Table

Contingent Consideration (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Business Acquisitions by Acquisition, Contingent Consideration [Table Text Block]	'
	A reconciliation of the beginning and ending balances of acquisition related accrued earnouts using significant unobservable inputs (Level 3) for the year ended December 31, is as follows (in thousands):
		2013
	Accrued earnout liability as of December 31, 2012	$	—
	Acquisition date fair value of contingent consideration - MCE Acquisition	6,320
	Acquisition date fair value of contingent consideration - Southern Dome Acquired Properties	1,600
	Change in fair value of contingent consideration	(1,600		)
	Payment of contingent consideration	—
	Accrued earnout liability as of December 31, 2013	$	6,320

Derivatives_Tables

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2013
DerivativesAndFairValueTextBlockAbstract	'
Schedule of Derivative Instruments	'
	The following table sets forth a reconciliation of the changes in fair value of the Partnership's commodity derivatives for the years ended December 31, 2013, 2012, and 2011 (in thousands).
		2013			2012			2011
	Beginning fair value of commodity derivatives	$	(129	)	$	(1,199	)	$	(1,349	)
	Total gain (loss) on commodity derivatives	(5,548		)	7,057			(1,349		)
	Commodity derivative premiums paid	1,334			—			—
	Commodity derivative cash settlements paid (received)	1,929			(5,987		)	1,499
	Ending fair value of commodity derivatives	$	(2,414	)	$	(129	)	$	(1,199	)
	Certain of our commodity derivatives are presented on a net basis on the Consolidated Balance Sheets. The following table summarizes the gross fair values of our commodity derivative instruments, presenting the impact of offsetting the derivative assets and liabilities recorded in other assets and derivative obligations on our Consolidated Balance Sheets as of December 31 for the periods indicated below (in thousands):
		December 31, 2013
		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts Presented in the Consolidated Balance Sheet
	Offsetting Derivative Assets:
	Commodity derivatives	$	2,980		$	(2,190	)	$	790
	Offsetting Derivative Liabilities:
	Commodity Derivatives	$	(5,394	)	$	2,190		$	(3,204	)
		December 31, 2012
		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts Presented in the Consolidated Balance Sheet
	Offsetting Derivative Assets:
	Commodity derivatives	$	52		$	(27	)	$	25
	Offsetting Derivative Liabilities:
	Commodity Derivatives	$	(181	)	$	27		$	(154	)
	The follow table presents the fair value of derivative instruments outstanding as of December 31, (in thousands):
	Oil collars:		Volumes (Bbls)		Floor Price			Ceiling Price
	2014		80,444		$	80		$	103.5
	2015		42,649		$	80		$	93.25
	Natural gas collars:		Volumes (MMBtu)		Floor Price			Ceiling Price
	2014		1,528,083		$	4		$	4.41
	2015		1,364,382		$	4		$	4.32
	Oil put options:		Volumes (Bbls)		Floor Price
	2014		24,547		$	80
	Natural gas put options:		Volumes (MMBtu)		Floor Price
	2014		445,768		$	3.5
	2015		798,853		$	3.5
	2016		930,468		$	3.5
	Natural gas liquids put options:		Volumes (Bbls)		Average Floor Price
	2014		59,423		$	28.66
	Oil swaps:		Volumes (Bbls)		Fixed Price per Bbl
	2014		14,634		$	90.2
	2015		39,411		$	88.9
	2016		36,658		$	86
	Natural gas swaps:		Volumes (MMBtu)		Average Price per MMBtu
	2014		1,102,183		$	4.09
	2015		800,573		$	4.25
	2016		629,301		$	4.37
	Natural gas liquid swaps:		Volumes (MMBtu)		Average Price
	2014		643,779		$	39.79
	2015		84,793		$	82.74
	Oil swaps:		Volumes (Bbls)		Fixed Price per Bbl
	2013		41,843		$	93.05
	2014		15,905		$	90.2
	Natural gas liquids put options:		Volumes (Bbls)		Average Floor Price
	2013		89,333		$	40.71
	2014		34,410		$	39.39
	Natural gas swaps:		Volumes (MMBtu)		Average Price per MMBtu
	2013		436,105		$	3.6

Unitholders_Equity_Tables

Unitholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2013
Incentive Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions Made to Limited Partner, by Distribution	'
	The following table illustrates the percentage allocations of MCE's available cash from operating surplus between the Class A unitholders and the Class B unitholders based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of the Class A and Class B unitholders in any available cash from operating surplus the MCE Partnership distributes up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.”
					Marginal Percentage Interest in
					Distributions
			Total Quarterly Distributions per MCE Unit		MCE Class A Unitholders (the Partnership)		MCE Class B Unitholders
	Minimum Quarterly Distribution		$15,820		100%		—%
	First Target Distribution		Above $18,194 up to $19,776		85%		15%
	Second Target Distribution		Above $19,776 up to $23,731		75%		25%
	Third Target Distribution and Thereafter		Above $23,731		50%		50%
			Total Quarterly		Marginal Percentage Interest in Distributions
			Distributions per Unit		Unitholders		General Partner
	Minimum Quarterly Distribution		$0.53		98%		2%
	First Target Distribution		up to $0.60375		98%		2%
	Second Target Distribution		above $0.60375 up to $0.65625		85%		15%
	Thereafter		above $0.65625		75%		25%
Cash Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions Made to Limited Partner, by Distribution	'
	The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common, subordinated and general partner units during the year ended December 31, 2013, as shown in the following table (in thousands, except distribution per unit):
	2013 Distribution		Per Common Unit				Amount Paid to Common Unitholders		Amount Paid to Subordinated Unitholder		Amount Paid to General Unitholder		Total Distributions
	First Quarter		$	0.2742		-1	$	1,857	$	605	$	43	$	2,504
	Second Quarter		$	0.55			$	3,725	$	1,213	$	85	$	5,023
	Third Quarter		$	0.575			$	3,895	$	1,268	$	89	$	5,252
	Fourth Quarter		$	0.575		(2)(3)	$	4,400	$	1,268	$	89	$	5,757
	-1	Prorated to reflect 47 days of quarterly cash distribution rate of $0.525 per unit.
	-2	Distributions of $1.1 million were not paid on the 1,947,033 common units issued in conjunction with the MCE acquisition pursuant to an arrangement with sellers to forgo, with respect to such common units, their rights to distribution for the fourth quarter 2013 only.
	-3	Distribution was declared on January 21, 2014. Distributions of $0.3 million were paid on the 488,667 common units issued in conjunction with the CEU Acquisition in January 2014 due to the record date for the fourth quarter distribution being January 31, 2014.

Earnings_Per_Common_and_Subord1

Earnings Per Common and Subordinated Unit Earnings Per Common and Subordinated Unit (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Schedule of Earnings Per Share, Basic and Diluted	'
	Basic and diluted earnings per unit for the period from February 13, 2013 through December 31, 2013 were computed using the following components:
		Common Units		Subordinated Units		General Partner
	Numerator:
	Net income (in thousands)	$	16,929	$	4,099	$	291
	Denominator:
	Weighted average units outstanding	6,994,517		2,205,000		154,673
	Basic and diluted income per unit	$	2.42	$	1.86	$	1.88

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	The following tables set forth certain financial information for our two operating segments as of and for the year ended December 31, 2013 (amounts in thousands):
		Exploration and Production Segment			Oilfield Services Segment			Total
	Identifiable assets	$	181,440		$	73,270		$	254,710
	Revenues	$	46,937		$	3,738		$	50,675
	Operating costs	(15,300		)	(2,040		)	(17,340		)
	Segment margin	$	31,637		$	1,698		$	33,335
	Depreciation and amortization	$	16,590		$	1,966		$	18,556
	Capital expenditures	$	48,319		$	445		$	48,764
	The following table reconciles the segment profits reported above to operating loss as reported on the Consolidated Statements of Operations for the year ended December 31, (amounts in thousands):
		2013
	Segment margin	$	33,335
	Depreciation and amortization	(18,556		)
	General and administrative	(14,760		)
	Accretion expense	(209		)
	Operating loss	$	(190	)

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	The following is schedule by year of lease obligations and minimum lease payments for non-cancellable leases with a term of more than one year at December 31, 2013 (in thousands):
	Year	Operating Leases
	2014	$	175
	2015	88
	2016	3
	Total	$	266

Quarterly_Results_of_Operation1

Quarterly Results of Operations (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Selected Quarterly Financial Information [Abstract]	'
Schedule of Quarterly Financial Information	'
	The following table summarizes quarterly financial data for the years ended December 31, 2013 and 2012 (in thousands, except per unit data):
		Quarter Ended
	2013	March 31 (1) (2)			30-Jun			30-Sep			31-Dec
	Revenues	$	9,360		$	10,649		$	12,431		$	18,235
	Income (loss) from operations	(6,118		)	2,456			2,121			1,351
	Income tax (expense) benefit	12,126			—			—			—
	Net income (loss)	$	(1,397	)	$	8,151		$	(1,986	)	$	21,854
	Earnings (loss) per unit
	Basic	$	(0.87	)	$	0.89		$	(0.22	)	$	2.05
	Diluted	$	(0.87	)	$	0.89		$	(0.22	)	$	2.05
	2012 (2)
	Revenues	$	10,031		$	8,156		$	8,262		$	9,147
	Income (loss) from operations	(354		)	(1,919		)	1,009			2,314
	Income tax (expense) benefit	144			(1,871		)	562			(631		)
	Net income (loss)	$	(108	)	$	2,921		$	(799	)	$	1,095

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Detail) (USD $)

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Feb. 13, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Mar. 12, 2013

Feb. 13, 2013

Feb. 13, 2013

Dec. 31, 2013

Feb. 13, 2013

Dec. 31, 2013

Nov. 12, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Nov. 12, 2013

New Source Energy GP, LLC

IPO

IPO

IPO

Property and Equipment

Common Stock Units

MidCentral Energy Services

MidCentral Energy Services

Minimum

Maximum

Customer Relationships

Customer Relationships

Customer Relationships

MidCentral Energy Services

MidCentral Energy Services

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

Stock Issued During Period, Shares, New Issues (in Shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

'

'

'

'

'

'

'

'

'

Share Price (in usd per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$20

$20

'

'

'

'

'

'

'

'

'

Proceeds from issuance of common units in initial public offering, net of deferred offering costs

'

'

'

'

'

'

'

'

'

$77,880,000

$0

$0

'

'

$71,900,000

'

'

'

'

'

'

'

'

'

'

Payments of Distributions to Affiliates

'

'

'

'

'

'

'

'

'

18,295,000

13,758,000

12,547,000

'

'

15,800,000

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

Common Stock, Shares, Issued (in Shares)

'

9,599,578

'

'

'

'

'

'

'

9,599,578

'

'

'

250,000

'

'

'

777,500

'

'

'

'

'

'

'

Subordinated Units Issued (in Shares)

'

2,205,000

'

'

'

'

'

'

'

2,205,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Consideration Transferred, Note Receivable

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Liabilities

'

1,585,000

'

'

'

34,000

'

'

'

1,585,000

34,000

499,000

'

'

70,000,000

70,000,000

'

'

'

'

'

'

'

'

'

Proceeds from borrowings on credit facility

'

'

'

'

'

'

'

'

'

78,500,000

3,000,000

68,500,000

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

Proceeds from Stock Options Exercised

'

'

'

'

'

'

'

'

'

'

'

'

'

4,700,000

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Working Interest

'

38.00%

'

'

'

'

'

'

'

38.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'10 years

'

'

'

Depreciation, depletion, and amortization

'

'

'

'

'

'

'

'

'

18,556,000

14,409,000

14,738,000

'

'

'

'

200,000

'

'

'

'

'

'

'

'

Discount of Estimated Future Net Revenues

'

10.00%

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Finite-Lived Intangible Assets, Net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35,009,000

'

36,800,000

Finite-Lived Intangible Asset, Useful Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'7 years

'

Amortization of Intangible Assets

'

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill

'

23,974,000

'

'

'

0

'

'

'

23,974,000

0

'

'

'

'

'

'

'

23,974,000

23,974,000

'

'

'

'

'

Income tax benefit (expense)

'

0

0

0

12,126,000

[1],[2]

-631,000

[1]

562,000

[1]

-1,871,000

[1]

144,000

[1]

12,126,000

-1,796,000

-10,502,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Partners Capital, Book Basis in Excess of Tax Basis

'

$118,900,000

'

'

'

'

'

'

'

$118,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[2]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

Summary_of_Significant_Account4

Summary of Significant Accounting Policies - Composition of Accounts Receivable (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts Receivable, Net, Current	$12,609	$5,663
Oilfield Services Segment	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts Receivable, Net, Current	3,964	0
Oil and Natural Gas	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts Receivable, Net, Current	8,417	5,621
Oil and Natural Gas from Related Parties	'	'
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'
Accounts Receivable, Net, Current	$228	$42

Summary_of_Significant_Account5

Summary of Significant Accounting Policies - Schedule of Amortization of Customer Relationships (Details) (Customer Relationships, USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Customer Relationships	'
Finite-Lived Intangible Assets [Line Items]	'
2014	$12,366
2015	8,689
2016	5,264
2017	3,425
2018	1,839
Thereafter	3,426
Total	$35,009

Acquisitions_Details

Acquisitions (Details) (USD $)

3 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 29, 2013

31-May-13

Jul. 23, 2013

Jul. 25, 2013

Oct. 04, 2013

Dec. 31, 2013

Nov. 13, 2013

Dec. 31, 2013

Nov. 12, 2013

Dec. 31, 2013

Jan. 31, 2014

Nov. 12, 2013

Nov. 13, 2013

Nov. 12, 2013

Nov. 13, 2013

Nov. 12, 2013

Feb. 13, 2013

Nov. 13, 2013

Nov. 11, 2013

acquisition

March Acquired Properties

May Acquired Properties

July Acquired Properties

Orion Acquisition

Southern Dome

Southern Dome

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

Material Acquisitions

Subsequent Event

MCE Owners

MCE Owners

MCE Owners

Select MCE Employees

Select MCE Employees

IPO

Kristian Kos

Kristian Kos

Boe

producing_well

Boe

CEU Paradigm

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

producing_well

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Acquisitions

'

'

'

'

'

'

'

'

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Acquisitions of Oil and Gas Properties

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of net assets acquired

'

'

'

'

'

'

'

'

'

'

'

$27,984,000

$7,893,000

$4,866,000

$3,230,000

$14,469,000

'

'

'

$68,170,000

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

'

'

'

'

'

'

'

'

'

'

'

1,378,500

'

'

'

'

'

'

'

'

'

'

'

1,847,265

'

99,768

'

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

'

'

'

'

'

$20.30

'

'

'

$20.79

'

'

'

'

'

$23.51

'

'

$22.64

'

$22.64

'

'

'

Payments to Acquire Oil and Gas Property

'

'

'

'

'

'

'

'

19,843,000

0

0

'

8,100,000

'

'

5,000,000

'

'

'

'

'

6,900,000

'

'

'

'

'

'

'

'

Total fair value consideration transferred

'

'

'

'

'

'

'

'

'

'

'

'

7,900,000

'

'

'

'

68,170,000

'

'

'

20,700,000

'

'

'

'

'

'

'

'

Productive Oil Wells, Percentage Working Interest Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Percentage of Voting Interests Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

Amortization of Intangible Assets

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of common units in initial public offering, net of deferred offering costs

'

'

'

'

'

'

'

'

77,880,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

71,900,000

'

'

Goodwill

23,974,000

'

'

'

0

'

'

'

23,974,000

0

'

'

'

'

'

'

'

'

23,974,000

23,974,000

'

'

'

'

'

'

'

'

'

'

Productive Oil Wells, Number of Working Interest Wells Acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

'

'

'

'

'

23

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Acquisition of Oil and Gas Properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

414,045

'

'

'

'

'

488,667

'

'

'

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

-21,372,000

'

'

'

0

'

'

'

-21,372,000

0

0

'

'

'

'

8,600,000

'

'

'

'

'

'

'

'

41,822,000

[1]

'

2,259,000

'

'

'

Business Combination, Contingent Consideration, Average Daily Production of Oil Well Required for Additional Consideration

'

'

'

'

'

'

'

'

383.5

'

'

'

'

'

'

'

383.5

'

'

'

'

'

'

'

'

'

'

'

'

'

Contingent consideration payable to related parties

6,320,000

'

'

'

0

'

'

'

6,320,000

0

'

'

'

'

'

1,600,000

0

'

6,320,000

[2]

6,300,000

'

2,300,000

'

'

'

'

'

'

'

'

Cash Paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,781,000

'

'

'

'

'

'

'

'

'

'

'

'

Non-controlling interests in subsidiary

13,988,000

'

'

'

0

'

'

'

13,988,000

0

'

'

'

'

'

'

'

'

13,988,000

[3]

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Acquisition Related Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

800,000

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

Business Combination, Contingent Consideration Arrangements, Cap on Aggregate Total Consideration Paid

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

120,000,000

120,000,000

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Ownership Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36.00%

Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

'

Gain (Loss) on Disposition of Stock in Subsidiary

'

'

'

'

'

'

'

'

22,709,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business Combination, Step Acquisition, Equity Interest In Acquiree Percentage Accounted At Purchase Price, Fair Value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

64.00%

'

'

'

'

'

'

'

Total revenues

18,235,000

12,431,000

10,649,000

9,360,000

[4],[5]

9,147,000

[4]

8,262,000

[4]

8,156,000

[4]

10,031,000

[4]

50,675,000

35,596,000

46,260,000

'

'

'

'

'

'

'

'

'

11,500,000

'

'

'

'

'

'

'

'

'

Operating loss

$1,351,000

$2,121,000

$2,456,000

($6,118,000)

[4],[5]

$2,314,000

[4]

$1,009,000

[4]

($1,919,000)

[4]

($354,000)

[4]

($190,000)

$1,050,000

$14,509,000

'

'

'

'

'

'

'

'

'

$6,500,000

'

'

'

'

'

'

'

'

'

[1]

1,847,265 common units valued at $22.64 per unit.

[2]

The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date and was considered as part of the purchase price of MCE.

[3]

Certain owners of MCE retained Class B Units, which entitle the holders to receive incentive distributions of cash distributed by MCE above specified thresholds in increasing amounts (see Note 12). The Class B units were valued at $14.0 million at the acquisition date and were considered as part of the purchase price of MCE.

[4]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[5]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

Acquisitions_Purchase_Price_Al

Acquisitions - Purchase Price Allocation for March Acquisitions (Details) (March Acquired Properties, USD $)	Mar. 29, 2013
In Thousands, unless otherwise specified
March Acquired Properties	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$29,049
Other assets acquired	754
Fair value of assets acquired	29,804
Asset retirement obligations	-1,333
Other liabilities assumed	-488
Fair value of net assets acquired	$27,984

Acquisitions_Purchase_Price_Al1

Acquisitions - Purchase Price Allocation for May Acquisitions (Details) (May Acquired Properties, USD $)	31-May-13
In Thousands, unless otherwise specified
May Acquired Properties	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$8,165
Fair value of assets acquired	8,165
Asset retirement obligations	-19
Other liabilities assumed	-254
Fair value of net assets acquired	$7,893

Acquisitions_Purchase_Price_Al2

Acquisitions - Purchase Price Allocation for July Acquisitions (Details) (July Acquired Properties, USD $)	Jul. 23, 2013
In Thousands, unless otherwise specified
July Acquired Properties	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$4,888
Fair value of assets acquired	4,888
Asset retirement obligations	-4
Other liabilities assumed	-18
Fair value of net assets acquired	$4,866

Acquisitions_Purchase_Price_Al3

Acquisitions - Purchase Price Allocation for Orion Acquisition (Details) (Orion Acquisition, USD $)	Jul. 25, 2013
In Thousands, unless otherwise specified
Orion Acquisition	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$3,274
Fair value of assets acquired	3,274
Asset retirement obligations	-24
Other liabilities assumed	-20
Fair value of net assets acquired	$3,230

Acquisitions_Purchase_Price_Al4

Acquisitions - Purchase Price Allocation for Southern Dome Acquisition (Details) (Southern Dome, USD $)	Oct. 04, 2013
In Thousands, unless otherwise specified
Southern Dome	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$15,190
Fair value of assets acquired	15,190
Asset retirement obligations	-170
Other liabilities assumed	-552
Fair value of net assets acquired	$14,469

Acquisitions_Purchase_Price_Al5

Acquisitions - Purchase Price Allocation for MCE Acquisition (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Nov. 13, 2013	Dec. 31, 2013		Nov. 12, 2013	Nov. 12, 2013		Nov. 12, 2013
				MidCentral Energy Services	MidCentral Energy Services		MidCentral Energy Services	MCE Owners		Select MCE Employees
								MidCentral Energy Services		MidCentral Energy Services
Business Acquisition [Line Items]	'	'	'	'	'		'	'		'
Cash Paid	'	'	'	$3,781,000	'		'	'		'
Business Acquisition, Equity Interest Issued or Issuable, Value Assigned	-21,372,000	0	0	'	'		'	41,822,000	[1]	2,259,000
Earn-out amount (contingent consideration) (3)	6,320,000	0	'	'	6,320,000	[2]	6,300,000	'		'
MCE Class B units granted (4)	13,988,000	0	'	'	13,988,000	[3]	'	'		'
Total fair value consideration transferred	'	'	'	$68,170,000	'		'	'		'
[1]	1,847,265 common units valued at $22.64 per unit.
[2]	The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date and was considered as part of the purchase price of MCE.
[3]	Certain owners of MCE retained Class B Units, which entitle the holders to receive incentive distributions of cash distributed by MCE above specified thresholds in increasing amounts (see Note 12). The Class B units were valued at $14.0 million at the acquisition date and were considered as part of the purchase price of MCE.

Acquisitions_Summary_of_Assets

Acquisitions - Summary of Assets Acquired and Liabilities Assumed in MCE Acquisition (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Nov. 12, 2013	Nov. 12, 2013
In Thousands, unless otherwise specified			MidCentral Energy Services	MidCentral Energy Services	Customer Relationships
					MidCentral Energy Services
Assets	'	'	'	'	'
Cash	'	'	'	$1,522	'
Accounts receivable	'	'	'	3,365	'
Other current assets	'	'	'	954	'
Property and Equipment	'	'	'	7,923	'
Intangible asset - customer relationship	'	'	'	'	36,772
Goodwill	23,974	0	23,974	23,974	'
Other assets	'	'	'	19	'
Liabilities	'	'	'	'	'
Accounts payable	'	'	'	-1,199	'
Accounts payable - related parties	'	'	'	-870	'
Accrued liabilities	'	'	'	-276	'
Factoring payable	'	'	'	-1,679	'
Current portion of long-term debt	'	'	'	-719	'
Long-term debt	'	'	'	-1,616	'
Net assets acquired	'	'	'	$68,170	'

Acquisitions_Pro_Forma_Results

Acquisitions - Pro Forma Results of Operations (Details) (USD $)

3 Months Ended

11 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

REVENUES:

'

'

'

'

'

'

'

'

'

'

'

'

As reported

$18,235

$12,431

$10,649

$9,360

[1],[2]

$9,147

[1]

$8,262

[1]

$8,156

[1]

$10,031

[1]

'

$50,675

$35,596

$46,260

Pro forma

'

'

'

'

'

'

'

'

'

77,892

67,599

'

Net Income (loss):

'

'

'

'

'

'

'

'

'

'

'

'

As reported

21,854

-1,986

8,151

-1,397

[1],[2]

1,095

[1]

-799

[1]

2,921

[1]

-108

[1]

21,319

26,622

3,109

-1,077

Pro forma

'

'

'

'

'

'

'

'

'

-3,438

12,420

'

Basic net income (loss) per unit:

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Share, Basic (in usd per unit)

$2.05

($0.22)

$0.89

($0.87)

[1],[2]

'

'

'

'

'

'

'

'

Pro Forma, Earnings Per Share, Basic (in usd per share)

'

'

'

'

'

'

'

'

'

($0.36)

'

'

Common Stock Units

'

'

'

'

'

'

'

'

'

'

'

'

Net Income (loss):

'

'

'

'

'

'

'

'

'

'

'

'

As reported

'

'

'

'

'

'

'

'

$16,929

'

'

'

Basic net income (loss) per unit:

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Share, Basic (in usd per unit)

'

'

'

'

'

'

'

'

$2.42

'

'

'

[1]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[2]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

Related_Parties_Details

Related Parties (Details) (USD $)

12 Months Ended

12 Months Ended

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Kristian Kos

David Chernicky

Richard Finley

Richard Finley

Richard Finley

General Partner

Subordinated Units

MidCentral Energy Services

MidCentral Energy Services

Kristian Kos

David Chernicky

Kristian Kos

Dikran Tourian

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Ownership Percentage of Reporting Company

'

'

'

'

25.00%

'

'

'

69.40%

'

'

'

Common Stock, Shares, Percentage Owned by Chief Executive Officer

'

'

'

8.30%

'

'

'

'

'

'

'

'

Common Stock, Shares, Percentage Owned by Principal Stockholder

'

'

'

'

27.60%

'

'

'

'

'

'

'

Subordinated Units, Shares, Percentage Owned by Principal Stockholder

'

'

'

'

100.00%

'

'

'

'

'

'

'

Subordinate Units, Units, Owned by Principal Stockholder

'

'

'

'

'

'

'

'

'

2,205,000

'

'

Due to Related Parties, Noncurrent

$350,000

'

$345,000

'

'

'

'

'

'

'

'

'

Due to Related Parties

'

'

600,000

'

'

'

'

'

'

'

'

'

Due to Related Parties, Current

'

'

300,000

'

'

'

'

'

'

'

'

'

Service Management Costs, Quarterly Fee

700,000

'

'

'

'

'

'

'

'

'

'

'

Service Management Costs

2,400,000

'

'

'

'

'

'

'

'

'

'

'

Prorated Fee

'

400,000

'

'

'

'

'

'

'

'

'

'

Ownership Percentage of Entity

'

'

'

'

'

'

'

'

'

'

36.00%

36.00%

Ownership Percentage in Accounting Services Provider

'

'

'

'

'

31.50%

'

'

'

'

'

'

Professional Fees

'

'

'

'

'

$500,000

$500,000

$100,000

'

'

'

'

Related_Parties_Summary_of_Rel

Related Parties - Summary of Related Party Transactions (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transactions	$2,035	$4,883	$2,415
Access Fee Charges [Member] | New Dominion LLC	'	'	'
Related Party Transactions	250	2,615	196
Producing Overhead Charges | New Dominion LLC	'	'	'
Related Party Transactions	980	599	581
Drilling And Completion Overhead Charges | New Dominion LLC	'	'	'
Related Party Transactions	101	27	26
Saltwater Disposal Fees | New Dominion LLC	'	'	'
Related Party Transactions	696	1,642	1,612
Administrative Fees | New Dominion LLC	'	'	'
Related Party Transactions	$9	$0	$0

Property_and_Equipment_Details

Property and Equipment (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

In Thousands, unless otherwise specified

Oilfield Services Segment

Oilfield Services Segment

Oilfield Services Segment

Oilfield Services Segment

Oilfield Services Segment

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Light-Duty Trucks

Machinery and Equipment

Rental Iron

Other Assets

Oilfield Services Segment

Oilfield Services Segment

Oilfield Services Segment

Oilfield Services Segment

Machinery and Equipment

Other Assets

Machinery and Equipment

Other Assets

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Property, Plant and Equipment, Useful Life

'

'

'

'3 years

'

'20 years

'

'3 years

'3 years

'3 years

'10 years

'10 years

'7 years

Property, Plant and Equipment, Gross

$162,868

$90,423

'

$516

$4,793

$2,971

$88

'

'

'

'

'

'

Less accumulated depreciation

-128,961

-112,372

-202

'

'

'

'

'

'

'

'

'

'

Property and equipment, net

$8,166

$0

$8,166

'

'

'

'

'

'

'

'

'

'

Asset_Retirement_Obligations_S

Asset Retirement Obligations - Summary of Asset Retirement Obligations Activity (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'	'
Asset retirement obligations, beginning of period	$1,510	$1,411	$857
Liabilities incurred from new wells drilled and acquired	1,585	34	499
Revision of previous estimates	151	-51	0
Accretion expense	209	116	55
Asset retirement obligations, end of period	$3,455	$1,510	$1,411

Major_Customers_Oil_and_Natura

Major Customers - Oil and Natural Gas Sales by Customer (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Scissortail	'	'	'
Major Customers Concentration Risk Percentage (less than 10% in 2011 for United Petroleum Purchasing)	80.00%	84.00%	90.00%
United Petroleum Purchasing	'	'	'
Major Customers Concentration Risk Percentage (less than 10% in 2011 for United Petroleum Purchasing)	14.00%	16.00%	'
Maximum | United Petroleum Purchasing	'	'	'
Major Customers Concentration Risk Percentage (less than 10% in 2011 for United Petroleum Purchasing)	'	'	10.00%

Credit_Facility_and_Factoring_1

Credit Facility and Factoring Payable (Detail) (USD $)

2 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2013

Nov. 12, 2013

Oct. 29, 2013

Jun. 25, 2013

Feb. 28, 2013

Feb. 27, 2013

Dec. 31, 2012

Sep. 01, 2012

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Federal Funds Rate

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Line of Credit

Line of Credit

Base Rate

London Interbank Offered Rate (LIBOR)

Base Rate

London Interbank Offered Rate (LIBOR)

Debt Instrument, Period

'

'

'

'

'

'

'

'

'

'

'

'36 months

'

'

'48 months

'

'

'4 years

'4 years

Line of Credit Facility, Current Borrowing Capacity

'

'

'

$87,500,000

$75,000,000

$60,000,000

$30,000,000

'

$70,000,000

$72,500,000

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

'

'

150,000,000

60,000,000

150,000,000

'

'

'

'

'

'

'

'

'

'

'

Other Notes Payable

'

'

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Covenant, Maximum Investment Acquisitions using Borrowings

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required Ratio of EBITDA to Interest Expense

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required Ratio of Total Debt to EBITDA

'

3.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required Current Ratio

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Debt Covenant, Maximum Borrowing Base Utilization, Percent

'

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Debt Covenants, Amount Available for Dividend Distribution

7,500,000

7,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

1.00%

'

'

'

'

'

'

'

'

0.50%

'

1.50%

2.50%

'

2.25%

3.25%

'

'

Line of Credit Facility, Commitment Fee Percentage

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Amount Outstanding

78,500,000

78,500,000

'

'

'

'

'

68,000,000

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Remaining Borrowing Capacity

9,000,000

9,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring Payable, Funding Received Upfront, Percent

90.00%

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring Payable, Amount of Factors Reserved, Percent

10.00%

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring Payable, Tiered Interest Schedule, Days Interest Rate Increases

'

'15 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring Payable, Interest Rate per Fifteen Day Period (up to a maximum of 5%)

'

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring Payable, Annualized Interest Rate, Maximum

'

20.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring Payables, Days till Outstanding Receivable is Repurchased

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring payable

1,907,000

1,907,000

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

Factoring Payable, Interest Expense

$39,888

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Longterm_Debt_Details

Long-term Debt (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Debt Instrument [Line Items]	'
Long-term debt, net of current portion	2,200
Minimum	'
Debt Instrument [Line Items]	'
Debt Instrument, Period	'36 months
Debt Instrument, Interest Rate, Stated Percentage	5.75%
Maximum	'
Debt Instrument [Line Items]	'
Debt Instrument, Period	'48 months
Debt Instrument, Interest Rate, Stated Percentage	10.29%

Longterm_Debt_Schedule_of_Long

Long-term Debt - Schedule of Long-term Debt Minimum Payments (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'		'
Long-term Debt	$2,200		'
Line of Credit Facility, Amount Outstanding	78,500		68,000
Notes Payable to Banks	'		'
Debt Instrument [Line Items]	'		'
2014	719		'
2015	766		'
2016	558		'
2017	78,651	[1]	'
2018	39		'
Long-term Debt	$80,733		'
[1]	Includes Credit Facility borrowings of $78.5 million maturing in February, 2017.

Fair_Value_Measurements_Detail

Fair Value Measurements (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value Disclosures [Abstract]	'	'
Line of Credit Facility, Amount Outstanding	$78,500	$68,000

Fair_Value_Measurements_Fair_V1

Fair Value Measurements Fair Value Measurements - Derivative Assets and Obligations Measured at Fair Value (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	($2,414)	($129)	'	'
Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	0	'	'
Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	103	-17	'	'
Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	-2,517	-112	-1,198	-1,108
Oil Puts	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	28	'	'	'
Oil Puts | Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Oil Puts | Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	28	'	'	'
Oil Puts | Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Oil Collar	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	-57	'	'	'
Oil Collar | Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Oil Collar | Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	-57	'	'	'
Oil Collar | Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Natual Gas Collars	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	-9	'	'	'
Natual Gas Collars | Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Natual Gas Collars | Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Natual Gas Collars | Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	-9	'	'	'
Oil and Natural Gas Swaps	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	132	-17	'	'
Oil and Natural Gas Swaps | Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	0	'	'
Oil and Natural Gas Swaps | Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	132	-17	'	'
Oil and Natural Gas Swaps | Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	0	'	'
Natural Gas and NGL Puts	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	403	'	'	'
Natural Gas and NGL Puts | Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Natural Gas and NGL Puts | Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	'	'	'
Natural Gas and NGL Puts | Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	403	'	'	'
NGL Swaps	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	-2,911	-112	'	'
NGL Swaps | Fair Value, Inputs, Level 1	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	0	'	'
NGL Swaps | Fair Value, Inputs, Level 2	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	0	0	'	'
NGL Swaps | Fair Value, Inputs, Level 3	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Derivative, Fair Value, Net	($2,911)	($112)	'	'

Fair_Value_Measurements_Fair_V2

Fair Value Measurements Fair Value Measurements - Fair Value of Allocated Derivative Assets and Liabilities (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Beginning balance	($129)	'	'
Unrealized Gain (Loss) on Derivatives	-3,619	1,070	150
Ending balance	-2,414	-129	'
Fair Value, Inputs, Level 3	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'
Beginning balance	-112	-1,198	-1,108
Realized gains (losses)	-1,670	5,965	-1,130
Unrealized Gain (Loss) on Derivatives	-2,405	1,086	-90
Settlements paid (received)	1,670	-5,965	1,130
Ending balance	-2,517	-112	-1,198
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	($2,446)	($112)	($90)

Contingent_Consideration_Detai

Contingent Consideration (Details) (USD $)	12 Months Ended						12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013		Nov. 12, 2013	Dec. 31, 2013	Oct. 04, 2013
	Boe			MidCentral Energy Services		MidCentral Energy Services	Southern Dome	Southern Dome
							Boe
Business Acquisition, Contingent Consideration [Line Items]	'	'	'	'		'	'	'
Business Combination, Contingent Consideration Arrangements, Cap on Aggregate Total Consideration Paid	'	'	'	$120,000,000		$120,000,000	'	'
Contingent consideration payable to related parties	6,320,000	0	'	6,320,000	[1]	6,300,000	0	1,600,000
Business Combination, Contingent Consideration, Average Daily Production of Oil Well Required for Additional Consideration	383.5	'	'	'		'	383.5	'
Business Combination, Contingent Consideration Arrangements, Change in Fair Value of Contingent Consideration, Liability	'	'	'	'		'	1,600,000	'
Change in fair value of contingent consideration	($1,600,000)	$0	$0	$6,320,000		'	$1,600,000	'
[1]	The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date and was considered as part of the purchase price of MCE.

Contingent_Consideration_Conti

Contingent Consideration Contingent Consideration - Reconciliation of Acquisition Related Accrued Earnouts (Details) (USD $)	12 Months Ended						12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013		Nov. 12, 2013	Dec. 31, 2013	Oct. 04, 2013
				MidCentral Energy Services		MidCentral Energy Services	Southern Dome	Southern Dome
Business Acquisition, Contingent Consideration [Roll Forward]	'	'	'	'		'	'	'
Accrued earnout liability as of December 31, 2012	$0	'	'	'		$6,300,000	'	$1,600,000
Acquisition date fair value of contingent consideration	-1,600,000	0	0	6,320,000		'	1,600,000	'
Change in fair value of contingent consideration	'	'	'	'		'	-1,600,000	'
Payment of contingent consideration	0	'	'	'		'	'	'
Accrued earnout liability as of December 31, 2013	$6,320,000	$0	'	$6,320,000	[1]	$6,300,000	$0	$1,600,000
[1]	The owners of MCE are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date and was considered as part of the purchase price of MCE.

Derivatives_Reconciliation_of_

Derivatives - Reconciliation of Changes in the Fair Value of Commodity Derivatives (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reconciliation of Changes in Fair Value of Commodity Derivatives [Roll Forward]	'	'	'
Beginning balance	($129)	'	'
Total gain (loss) on commodity derivatives	-5,548	7,057	-1,349
Ending balance	-2,414	-129	'
Commodity Contract	'	'	'
Reconciliation of Changes in Fair Value of Commodity Derivatives [Roll Forward]	'	'	'
Beginning balance	-129	-1,199	-1,349
Total gain (loss) on commodity derivatives	-5,548	7,057	-1,349
Commodity derivative premiums paid	1,334	0	0
Commodity derivative cash settlements paid (received)	1,929	-5,987	1,499
Ending balance	($2,414)	($129)	($1,199)

Derivatives_Derivatives_Offset

Derivatives Derivatives - Offsetting Commodity Derivative Assets and Liabilities (Details) (Commodity, USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Commodity	'	'
Derivative [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$2,980	$52
Derivative Asset, Fair Value, Amount Offset Against Collateral	-2,190	-27
Derivative Assets, Fair Value, Net	790	25
Derivative Liability, Fair Value, Gross Liability	-5,394	-181
Derivative Liability, Fair Value, Amount Offset Against Collateral	2,190	27
Derivative Liabilities, Fair Value, Net	($3,204)	($154)

Derivatives_Derivatives_Fair_V

Derivatives Derivatives - Fair Value of Derivatives (Details)

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

2013

2014

2014

2014

2014

2014

2014

2014

2014

2015

2015

2015

2015

2015

2015

2016

2016

2016

Natural Gas Liquids Put Options

Natural Gas Liquids Put Options

Oil Swaps

Oil Swaps

MMBTU

Oil Put Options

Oil Swaps

Oil Collar

Natual Gas Collars

Natural Gas Swaps

Natural Gas Liquids Swap

Natural Gas Liquids Put Options

Natural Gas Put Options

Oil Swaps

Oil Collar

Natual Gas Collars

Natural Gas Swaps

Natural Gas Liquids Swap

Natural Gas Put Options

Oil Swaps

Natural Gas Swaps

Natural Gas Put Options

2013

2014

2013

2014

Put Option

Variance Swap

bbl

MMBTU

Variance Swap

Variance Swap

Put Option

Put Option

Variance Swap

bbl

MMBTU

Variance Swap

Variance Swap

Put Option

Variance Swap

Variance Swap

Put Option

bbl

bbl

bbl

bbl

bbl

bbl

MMBTU

MMBTU

bbl

MMBTU

bbl

MMBTU

MMBTU

MMBTU

bbl

MMBTU

MMBTU

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative, Nonmonetary Notional Amount

436,105

24,547

14,634

80,444

1,528,083

1,102,183

643,779

59,423

445,768

39,411

42,649

1,364,382

800,573

84,793

798,853

36,658

629,301

930,468

89,333

34,410

41,843

15,905

Derivative, Swap Type, Average Fixed Price

3.6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.71

39.39

'

'

Derivative, Swap Type, Fixed Price

'

'

90.2

'

'

'

'

'

'

88.9

'

'

'

'

'

86

'

'

'

'

93.05

90.2

Derivative, Floor Price

'

80

'

80

4

'

'

'

3.5

'

80

4

'

'

3.5

'

'

3.5

'

'

'

'

Derivative, Cap Price

'

'

'

103.5

4.41

'

'

'

'

'

93.25

4.32

'

'

'

'

'

'

'

'

'

'

Derivative, Average Floor Price

'

'

'

'

'

4.09

39.79

28.66

'

'

'

'

4.25

82.74

'

'

4.37

'

'

'

'

'

Unitholders_Equity_Details

Unitholders' Equity (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
	Boe
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.53
Incentive Distribution, Required Minimum of Average Daily Energy Production to Maintain Subordination Distributions, Per Quarter for Four Quarter Period	3,200
Distribution Policy, Early Termination of Subordination Period, Required Minimum Quarterly Distribution Earned and Paid by Partnership for Twelve Consecutive Quarters	$2.10
Distribution Policy, Early Termination of Subordination Period, Required Annualized Minimum Quarterly Distribution Earned and Paid by Partnership	$2.63
Incentive Distribution, Percent of Annualized Minimum Quarterly Distribution Required to Terminate Subordination Period	125.00%
Limited Liability (LLC) or Limited Partnership (LP), Managing Member or General Partner, Distribution Percent	2.00%
Distributions Policy, Members or Limited Partners, Days after Quarter End for Distributions	'45 days
Minimum | Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.60
Minimum | Thereafter Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.66
Maximum | First Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.60
Maximum | Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.66
Common Class A | First Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distributions, Increasing Percent	15.00%
Common Class A | Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distributions, Increasing Percent	25.00%
Common Class A | Third and Thereafter Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distributions, Increasing Percent	50.00%

Unitholders_Equity_Unitholders

Unitholders' Equity Unitholders' Equity - Incentive Distribution Rights (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.53
Minimum | Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.60
Minimum | Thereafter Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.66
Maximum | First Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.60
Maximum | Second Target Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$0.66
Incentive Distribution	'
Class of Stock [Line Items]	'
Incentive Distribution, Distribution Per Unit	$525
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	98.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	2.00%
Incentive Distribution | First Target Distribution	'
Class of Stock [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	98.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	2.00%
Incentive Distribution | Second Target Distribution	'
Class of Stock [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	85.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	15.00%
Incentive Distribution | Thereafter Second Target Distribution	'
Class of Stock [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	75.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	25.00%

Unitholders_Equity_Unitholders1

Unitholders' Equity Unitholders' Equity - Cash Distributions (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2013

Jan. 21, 2014

Jan. 21, 2014

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Common Stock Units

Common Stock Units

Common Stock Units

Common Stock Units

Subordinated Units

Subordinated Units

Subordinated Units

Subordinated Units

General Partner

General Partner

General Partner

General Partner

MidCentral Energy Services

Subsequent Event

Subsequent Event

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Cash Distribution

CEU Paradigm

Cash Distribution

Distribution Made to Limited Partner [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution, Distribution Per Unit

$0.53

$0.57

[1],[2]

$0.57

$0.55

$0.27

[3]

$0.53

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution, Distribution

'

$5,757,000

$5,252,000

$5,023,000

$2,504,000

'

$4,400,000

$3,895,000

$3,725,000

$1,857,000

$1,268,000

$1,268,000

$1,213,000

$605,000

$89,000

$89,000

$85,000

$43,000

'

'

$300,000

Incentive Distribution, Period of Prorated Distribution

'

'

'

'

'

'47 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive Distribution, Distributions not Paid related to Business Combinations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,100,000

'

'

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,947,033

488,667

'

[1]

Distributions of $1.1 million were not paid on the 1,947,033 common units issued in conjunction with the MCE acquisition pursuant to an arrangement with sellers to forgo, with respect to such common units, their rights to distribution for the fourth quarter 2013 only.

[2]

Distributions of $0.3 million were paid on the 488,667 common units issued in conjunction with the CEU Acquisition in January 2014 due to the record date for the fourth quarter distribution being January 31, 2014.

[3]

Prorated to reflect 47 days of quarterly cash distribution rate of $0.525 per unit.

Unitholders_Equity_Unitholders2

Unitholders' Equity Unitholders' Equity - Distributions to Noncontrolling Interests (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Noncontrolling Interest	'
Distribution Made to Limited Partner [Line Items]	'
Incentive Distribution, Distribution	$15,820
Noncontrolling Interest | First Target Distribution | Minimum	'
Distribution Made to Limited Partner [Line Items]	'
Incentive Distribution, Distribution	18,194
Noncontrolling Interest | First Target Distribution | Maximum	'
Distribution Made to Limited Partner [Line Items]	'
Incentive Distribution, Distribution	19,776
Noncontrolling Interest | Second Target Distribution | Minimum	'
Distribution Made to Limited Partner [Line Items]	'
Incentive Distribution, Distribution	19,776
Noncontrolling Interest | Second Target Distribution | Maximum	'
Distribution Made to Limited Partner [Line Items]	'
Incentive Distribution, Distribution	23,371
Noncontrolling Interest | Third and Thereafter Target Distribution | Minimum	'
Distribution Made to Limited Partner [Line Items]	'
Incentive Distribution, Distribution	$23,371
Common Class A	'
Distribution Made to Limited Partner [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	0.00%
Common Class A | First Target Distribution	'
Distribution Made to Limited Partner [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	85.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	15.00%
Common Class A | Second Target Distribution	'
Distribution Made to Limited Partner [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	75.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	25.00%
Common Class A | Third and Thereafter Target Distribution	'
Distribution Made to Limited Partner [Line Items]	'
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	50.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	50.00%

Earnings_Per_Common_and_Subord2

Earnings Per Common and Subordinated Unit Earnings Per Common and Subordinated Unit (Details)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Limited Liability (LLC) or Limited Partnership (LP), Managing Member or General Partner, Distribution Percent	2.00%

Earnings_Per_Common_and_Subord3

Earnings Per Common and Subordinated Unit Earnings Per Common and Subordinated Unit - Earnings Per Unit (Details) (USD $)

3 Months Ended

11 Months Ended

12 Months Ended

In Thousands, except Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Numerator:

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

$21,854

($1,986)

$8,151

($1,397)

[1],[2]

$1,095

[1]

($799)

[1]

$2,921

[1]

($108)

[1]

$21,319

$26,622

$3,109

($1,077)

Denominator:

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Share, Basic (in usd per unit)

$2.05

($0.22)

$0.89

($0.87)

[1],[2]

'

'

'

'

'

'

'

'

Common Stock Units

'

'

'

'

'

'

'

'

'

'

'

'

Numerator:

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

16,929

'

'

'

Denominator:

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average units outstanding (in shares)

'

'

'

'

'

'

'

'

6,994,517

'

'

'

Earnings Per Share, Basic (in usd per unit)

'

'

'

'

'

'

'

'

$2.42

'

'

'

Subordinated Units

'

'

'

'

'

'

'

'

'

'

'

'

Numerator:

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

4,099

'

'

'

Denominator:

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average units outstanding (in shares)

'

'

'

'

'

'

'

'

2,205,000

'

'

'

Earnings Per Share, Basic (in usd per unit)

'

'

'

'

'

'

'

'

$1.86

'

'

'

General Partnership Units

'

'

'

'

'

'

'

'

'

'

'

'

Numerator:

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

'

$291

'

'

'

Denominator:

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average units outstanding (in shares)

'

'

'

'

'

'

'

'

154,673

'

'

'

Earnings Per Share, Basic (in usd per unit)

'

'

'

'

'

'

'

'

$1.88

'

'

'

[1]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[2]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

EquityBased_Compensation_Detai

Equity-Based Compensation (Detail) (USD $)

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

Feb. 13, 2013

Aug. 18, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Nov. 13, 2013

Nov. 12, 2013

Dec. 31, 2013

Nov. 13, 2013

Nov. 12, 2013

Restricted Stock

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

Select MCE Employees

Select MCE Employees

Restricted Stock

Restricted Stock

Restricted Stock

Select MCE Employees

Select MCE Employees

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Allocated equity-based compensation of parent

'

'

'

'

'

$7,400,000

'

'

'

'

'

Business Acquisition, Equity Interest Issued or Issuable, Number of Shares

'

'

'

'

'

'

99,768

'

'

99,768

'

Business Acquisition, Equity Interest Issued or Issuable, Value Assigned

'

'

-21,372,000

0

0

'

'

2,259,000

'

'

2,259,000

[1]

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

'

'

'

'

'

'

'3 years

'

'3 years

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Days After Calendar Year that Forfeited Shares Are Issued to Prior Owners

'

'

'

'

'

'

'

'

'45 days

'

'

Unit compensation funded by unitholders

'

'

101,000

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Restricted Stock Award, Gross

367,500

2,900,000

'

'

'

'

'

'

'

'

'

Investment Owned, Restricted, Carrying Value Per Unit at Date of Balance Sheet

20

'

'

'

'

'

'

'

'

'

'

Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized

'

'

2,100,000

'

'

'

'

'

'

'

'

Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition

'

'

'2 years 9 months 18 days

'

'

'

'

'

'

'

'

RestrictedStockSharesVestingWithin1YearOfIssueDate

'

1,000,000

'

'

'

'

'

'

'

'

'

RestrictedStockSharesVestingWithin2YearsOfIssueDate

'

700,000

'

'

'

'

'

'

'

'

'

RestrictedStockSharesVestingUponCompletionOfIPO

'

1,200,000

'

'

'

'

'

'

'

'

'

Equity-based compensation

'

'

$7,839,000

$8,204,000

$4,470,000

'

'

'

'

'

'

[1]

99,768 common units valued at $22.64 per unit. These common units were issued to certain employees of MCE, under the Partnershipbs long-term incentive plan. If the recipients of the common units do not remain employed by MCE for three years, then they forfeit the units. The common units do not revert to the Partnership, but would be distributed to the former owners of MCE. The $2.3 million fair value of the common units is included in the consideration transferred for the MCE Acquisition, as the units do not revert back to the Partnership upon any circumstance. Since this compensation arrangement is funded by unitholders, the compensation will be reflected in the accompanying Consolidated Statements of Operations over the three-year straight-line vesting period. See Note 14, Equity-Based Compensation, for more information.

EquityBased_Compensation_Equit

Equity-Based Compensation Equity-Based Compensation - Composition of Equity-Based Compensation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Equity-based compensation	$7,839	$8,204	$4,470
New Source Energy Partners LP	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
Equity-based compensation	$388	'	'

Segment_Information_Segment_In

Segment Information Segment Information (Details)	12 Months Ended
	Dec. 31, 2013
	segment
Segment Reporting [Abstract]	'
Number of Operating Segments	2

Segment_Information_Summary_of

Segment Information - Summary of Operating Segment Activities (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Identifiable assets

$254,710

'

'

'

$99,934

'

'

'

$254,710

$99,934

'

Total revenues

18,235

12,431

10,649

9,360

[1],[2]

9,147

[1]

8,262

[1]

8,156

[1]

10,031

[1]

50,675

35,596

46,260

Operating costs

'

'

'

'

'

'

'

'

-17,340

'

'

Segment margin

'

'

'

'

'

'

'

'

33,335

'

'

Depreciation, depletion, and amortization

'

'

'

'

'

'

'

'

18,556

14,409

14,738

Capital Expenditures

'

'

'

'

'

'

'

'

48,764

'

'

E & P Segment

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Identifiable assets

181,440

'

'

'

'

'

'

'

181,440

'

'

Total revenues

'

'

'

'

'

'

'

'

46,937

'

'

Operating costs

'

'

'

'

'

'

'

'

-15,300

'

'

Segment margin

'

'

'

'

'

'

'

'

31,637

'

'

Depreciation, depletion, and amortization

'

'

'

'

'

'

'

'

16,590

'

'

Capital Expenditures

'

'

'

'

'

'

'

'

48,319

'

'

Oilfield Services Segment

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Identifiable assets

73,270

'

'

'

'

'

'

'

73,270

'

'

Total revenues

'

'

'

'

'

'

'

'

3,738

'

'

Operating costs

'

'

'

'

'

'

'

'

-2,040

'

'

Segment margin

'

'

'

'

'

'

'

'

1,698

'

'

Depreciation, depletion, and amortization

'

'

'

'

'

'

'

'

1,966

'

'

Capital Expenditures

'

'

'

'

'

'

'

'

$445

'

'

[1]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[2]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

Segment_Information_Reconcilia

Segment Information - Reconciliation of Segment Profits to Consolidated Statements of Operations (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Segment margin

'

'

'

'

'

'

'

'

$33,335

'

'

Depreciation, depletion, and amortization

'

'

'

'

'

'

'

'

-18,556

-14,409

-14,738

General and administrative

'

'

'

'

'

'

'

'

-14,760

-12,660

-6,928

Accretion expense

'

'

'

'

'

'

'

'

-209

-116

-55

Operating loss

$1,351

$2,121

$2,456

($6,118)

[1],[2]

$2,314

[1]

$1,009

[1]

($1,919)

[1]

($354)

[1]

($190)

$1,050

$14,509

[1]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[2]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

Commitments_and_Contingencies_1

Commitments and Contingencies (Detail) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
AverageAnnualDrillingBudgetMinimum	$8.20
Minimum	'
Loss Contingency, Estimate of Possible Loss	0.01
Maximum	'
Loss Contingency, Estimate of Possible Loss	$0.25

Commitments_and_Contingencies_2

Commitments and Contingencies - Lease Obligations (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Commitments and Contingencies Disclosure [Abstract]	'
2014	$175
2015	88
2016	3
Total	$266

Quarterly_Results_of_Operation2

Quarterly Results of Operations (unaudited) (Details) (USD $)

3 Months Ended

11 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Selected Quarterly Financial Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Total revenues

$18,235

$12,431

$10,649

$9,360

[1],[2]

$9,147

[1]

$8,262

[1]

$8,156

[1]

$10,031

[1]

'

$50,675

$35,596

$46,260

Operating loss

1,351

2,121

2,456

-6,118

[1],[2]

2,314

[1]

1,009

[1]

-1,919

[1]

-354

[1]

'

-190

1,050

14,509

Income tax benefit (expense)

0

0

0

12,126

[1],[2]

-631

[1]

562

[1]

-1,871

[1]

144

[1]

'

12,126

-1,796

-10,502

Net income (loss)

$21,854

($1,986)

$8,151

($1,397)

[1],[2]

$1,095

[1]

($799)

[1]

$2,921

[1]

($108)

[1]

$21,319

$26,622

$3,109

($1,077)

Earnings (loss) per unit

'

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Share, Basic (in usd per unit)

$2.05

($0.22)

$0.89

($0.87)

[1],[2]

'

'

'

'

'

'

'

'

Earnings Per Share, Diluted (in usd per unit)

$2.05

($0.22)

$0.89

($0.87)

[1],[2]

'

'

'

'

'

'

'

'

[1]

EPU for periods prior to Feb 13, 2013 is not presented because the data would not be meaningful due to the change in tax status that took place on Feb 13, 2013.

[2]

The first quarter, 2013 loss per unit only applies to earnings from February 14, 2013 (the Partnership's IPO date) to December 31, 2013.

Subsequent_Events_Detail

Subsequent Events (Detail) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Feb. 28, 2013

Feb. 27, 2013

Jan. 21, 2014

Jan. 31, 2014

Dec. 31, 2013

Dec. 31, 2013

Jan. 08, 2013

Feb. 11, 2014

Feb. 28, 2014

Mar. 10, 2014

Jan. 08, 2013

Feb. 28, 2014

Jan. 08, 2013

Feb. 28, 2014

Subsequent Event

CEU Paradigm

Minimum

Maximum

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

Subsequent Event

agreement

Subsequent Event

Subsequent Event

Subsequent Event

Minimum

Minimum

Maximum

Maximum

producing_well

equipment

Revolving Credit Facility

Loans Payable

Notes Payable to Banks

Loans Payable

Subsequent Event

Loans Payable

Subsequent Event

Loans Payable

Loans Payable

Productive Oil Wells, Number of Working Interest Wells Acquired

'

'

'

'

'

'

23

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Oil and Gas Property

$19,843,000

$0

$0

'

'

'

$6,900,000

'

'

'

'

'

'

'

'

'

'

Stock Issued During Period, Shares, Acquisition of Oil and Gas Properties

'

'

'

'

'

'

488,667

'

'

'

'

'

'

'

'

'

'

Business Acquisition, Share Price

'

'

'

'

'

'

$23.51

'

'

'

'

'

'

'

'

'

'

Contingent consideration payable to related parties

6,320,000

0

'

'

'

'

2,300,000

'

'

'

'

'

'

'

'

'

'

Total fair value consideration transferred

'

'

'

'

'

'

20,700,000

'

'

'

'

'

'

'

'

'

'

Number of Loan Agreements

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

Pieces of Equipment Acquired With Loans

'

'

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

Loans Payable to Bank

'

'

'

'

'

'

'

'

'

'

'

'

'

141,842

'

251,110

'

Debt Instrument, Periodic Payment

'

'

'

'

'

'

'

'

'

'

'

'

58,173

'

4,303

'

7,613

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

5.75%

10.29%

'

'

5.75%

5.75%

'

'

'

'

Debt Instrument, Period

'

'

'

'

'

'

'

'36 months

'48 months

'

'

'48 months

'48 months

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

150,000,000

'

150,000,000

60,000,000

'

'

'

'

'

4,000,000

'

'

'

'

'

'

Notes Payable

'

'

'

'

'

'

'

'

'

'

'

'

$2,484,703

'

'

'

'

Common Stock, Dividends, Per Share, Declared

'

'

'

'

'

$0.57

'

'

'

'

'

'

'

'

'

'

'