New Source Energy Partners (NSLP) 10-Q 14 Aug 14 2014 Q2 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 01, 2014	Aug. 01, 2014	Aug. 01, 2014
		Common Units	Subordinated Units	General Partnership Units
Document Information [Line Items]	'	'	'	'
Entity Registrant Name	'New Source Energy Partners L.P.	'	'	'
Document Type	'10-Q	'	'	'
Current Fiscal Year End Date	'--12-31	'	'	'
Entity Common Stock, Shares Outstanding	'	15,440,381	2,205,000	155,102
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	30-Jun-14	'	'	'
Document Fiscal Year Focus	'2014	'	'	'
Document Fiscal Period Focus	'Q2	'	'	'

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (Unaudited) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash	$8,368	$7,291
Restricted cash	975	0
Accounts receivable	39,004	12,609
Other current assets	4,871	1,114
Total current assets	53,218	21,014
Oil and natural gas properties, at cost using full cost method of accounting:	'	'
Proved oil and natural gas properties	325,332	291,829
Less: Accumulated depreciation, depletion, and amortization	-141,675	-128,961
Total oil and natural gas properties, net	183,657	162,868
Property and equipment, net	56,459	8,166
Intangible assets, net	99,226	35,009
Goodwill	39,698	23,974
Other assets	4,579	3,679
Total assets	436,837	254,710
Current liabilities:	'	'
Accounts payable and accrued liabilities	13,451	3,267
Accounts payable-related parties	8,901	8,221
Factoring payable	16,164	1,907
Contingent consideration payable	26,609	0
Derivative contracts	3,135	3,167
Current portion of long-term debt	21,677	719
Total current liabilities	89,937	17,281
Long-term debt	87,867	80,014
Contingent consideration payable to related parties	0	6,320
Asset retirement obligations	3,787	3,455
Other liabilities	1,016	387
Total liabilities	182,607	107,457
Commitments and contingencies (Note 13)	'	'
Unitholders' equity:	'	'
Total New Source Energy Partners L.P. unitholders' equity	238,733	133,265
Noncontrolling interest	15,497	13,988
Total unitholders' equity	254,230	147,253
Total liabilities and unitholders' equity	436,837	254,710
Common Units	'	'
Unitholders' equity:	'	'
Common units (15,428,822 units outstanding at June 30, 2014 and 9,599,578 units outstanding at December 31, 2013)	269,417	151,773
Common units held in escrow	-9,407	0
Subordinated Units	'	'
Unitholders' equity:	'	'
Subordinated units (2,205,000 units issued and outstanding at June 30, 2014 and December 31, 2013)	-19,921	-17,334
General Partnership Units	'	'
Unitholders' equity:	'	'
General partner's units (155,102 units issued and outstanding at June 30, 2014 and December 31, 2013)	($1,356)	($1,174)

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Unaudited) (Parentheticals)	Jun. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Common units outstanding (in Shares)	15,428,822	9,599,578
Subordinated units outstanding (in Shares)	2,205,000	2,205,000
General partner's capital units outstanding (in Shares)	155,102	155,102

Condensed_Statements_of_Operat

Condensed Statements of Operations (Unaudited) (USD $)	3 Months Ended				6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Revenues:	'		'		'		'
Oil sales	$4,402		$1,636		$8,348		$2,834
Natural gas sales	3,850		2,642		9,217		4,449
NGL sales	8,466		6,371		18,004		12,726
Oilfield services	10,100		0		18,676		0
Total revenues	26,818		10,649		54,245		20,009
Operating costs and expenses:	'		'		'		'
Oil, natural gas and NGL production	4,516		2,827		9,019		5,274
Production taxes	792		486		1,671		1,439
Cost of providing oilfield services	5,968		0		10,534		0
Depreciation, depletion and amortization	10,289		3,577		19,567		6,772
Accretion	74		57		143		86
General and administrative	3,489		1,246		9,050		10,100	[1]
Total operating costs and expenses	25,128		8,193		49,984		23,671
Operating income (loss)	1,690		2,456		4,261		-3,662
Other income (expense):	'		'		'		'
Interest expense	-1,015		-487		-1,984		-2,566
(Loss) gain on derivative contracts, net	-1,396	[2]	6,182	[2]	-4,528	[2]	856	[2]
Gain on investment in acquired business	2,298		0		2,298		0
Other income	9		0		7		0
Income (loss) before income taxes	1,586		8,151		54		-5,372
Income tax benefit	0		0		0		12,126
Net income	1,586		8,151		54		6,754
Less: net income attributable to noncontrolling interest	0		0		0		0
Net income	1,586		8,151		54		6,754
Common Units	'		'		'		'
Other income (expense):	'		'		'		'
Net income	'		'		97		'
Net income (loss) per unit:	'		'		'		'
Basic and diluted income per unit (in usd per unit)	$0.11		$0.89		$0.01		$0.22
Subordinated Units	'		'		'		'
Other income (expense):	'		'		'		'
Net income	'		'		-40		'
Net income (loss) per unit:	'		'		'		'
Basic and diluted income per unit (in usd per unit)	$0.11		$0.89		($0.02)		$0.02
General Partnership Units	'		'		'		'
Other income (expense):	'		'		'		'
Net income	'		'		($3)		'
Net income (loss) per unit:	'		'		'		'
Basic and diluted income per unit (in usd per unit)	$0.11		$0.89		($0.02)		$0.03
[1]	Includes $7.7 million of compensation expense related to common units granted to consultants, officers, directors and employees in conjunction with our initial public offering.
[2]	Included in (loss) gain on derivative contracts for the three months ended June 30, 2014 and 2013 are net cash payments upon contract settlement of $1.0 million and $0.1 million, respectively. Included in (loss) gain on derivative contracts for the six months ended June 30, 2014 and 2013 are net cash payments upon contract settlement of $3.4 million and $0.3 million, respectively.

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Unitholders' Equity (Unaudited) (USD $)	Total	Common Units	Subordinated Units	General Partnership Units	Noncontrolling Interest
In Thousands, except Share data, unless otherwise specified
Beginning Balance at Dec. 31, 2013	$147,253	$151,773	($17,334)	($1,174)	$13,988
Beginning Balance (in units) at Dec. 31, 2013	'	9,599,578	2,205,000	155,102	'
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'	'	'
Issuance of common units, net of offering costs (in units)	'	3,450,000	'	'	'
Issuance of common units, net of offering costs	76,191	76,191	'	'	'
Offering cost related to 2013 private placement paid in 2014	-100	-100	'	'	'
Issuance of common units in acquisitions (in units)	'	1,964,957	'	'	'
Issuance of common units in acquisitions	45,447	43,938	'	'	1,509
Equity-based compensation (in units)	'	414,287	'	'	'
Equity-based compensation	644	644	'	'	'
Distributions to unitholders	-15,259	-12,533	-2,547	-179	'
Net income (loss)	54	97	-40	-3	'
Ending Balance at Jun. 30, 2014	$254,230	$260,010	($19,921)	($1,356)	$15,497
Ending Balance (in units) at Jun. 30, 2014	'	15,428,822	2,205,000	155,102	'

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Cash Flow (Unaudited) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash Flows from Operating Activities:	'	'
Net income (loss)	$54	$6,754
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, depletion and amortization	19,567	6,772
Accretion	143	86
Amortization of deferred loan costs	292	240
Write off of loan costs due to debt refinancing	0	1,436
Equity-based compensation	644	7,738
Deferred income tax benefit	0	-12,023
Change in fair value of contingent consideration	-912	0
Gain on investment in acquired business	-2,298	0
Loss (gain) on derivative contracts, net	4,528	-856
Cash paid on settlement of derivative contracts	-3,412	-341
Payments for premiums on derivatives	0	-1,334
Changes in operating assets and liabilities:	'	'
Accounts receivable	-3,045	-8,437
Other current assets and other assets	-1,493	0
Accounts payable and accrued liabilities	620	2,691
Net cash provided by operating activities	14,688	2,726
Cash Flows from Investing Activities:	'	'
Acquisitions, net of cash acquired	-63,446	-7,893
Additions to oil and natural gas properties	-18,218	-4,302
Additions to other property and equipment	-2,991	0
Net cash used in investing activities	-84,655	-12,195
Cash Flows from Financing Activities:	'	'
Proceeds from borrowings	14,934	50,000
Payments on borrowings	-5,648	-95,000
Bank overdraft	1,838	0
Proceeds from financing	808	0
Proceeds from borrowings, net - related party	300	0
Payments for deferred loan costs	-437	-1,747
Payments on factoring payable, net	-1,583	0
Proceeds from sales of common units, net of offering costs	76,191	77,880
Payments of offering costs	-100	0
Distribution to unitholders	-15,259	-2,504
Distribution to New Source Energy	0	-18,295
Net cash provided by financing activities	71,044	10,334
Net change in cash and cash equivalents	1,077	865
Cash and cash equivalents, beginning of period	7,291	0
Cash and cash equivalents, end of period	8,368	865
Supplemental Cash Flow Information:	'	'
Cash paid for interest	1,859	1,020
Non-cash Investing and Financing Activities:	'	'
Capitalized asset retirement obligation	189	1,354
(Decrease) increase in accrued capital expenditures	-1,457	786
Accounts receivable distributed to New Source Energy	0	-7,014
Accounts payable assumed by New Source Energy	0	-1,742
Subordinated note issued to New Source Energy for oil and natural gas properties	0	25,000
Common units issued in connection with acquisitions	-46,239	-27,983
Acquisition of property and equipment by financing	2,725	0
Factoring payables assumed in connection with acquisitions	15,840	0
Debt assumed in connection with acquisitions	$17,571	$0

Basis_of_Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	Nature of Business.  We are a vertically integrated independent energy partnership formed in October 2012. The Partnership is actively engaged in the development and production of onshore oil and natural gas properties that extend across conventional resource reservoirs in east-central Oklahoma. Our oil and natural gas properties consist of non-operated working interests primarily in the Misener-Hunton formation, or Hunton formation. In addition, the Partnership is engaged in oilfield services through its oilfield services subsidiaries. Our oilfield services business provides full service blowout prevention installation and pressure testing services, including certain ancillary equipment necessary to perform such services, throughout the Mid-Continent region and in South Texas and West Texas. In June 2014, we acquired oilfield services companies that specialize in providing well testing and flowback services to the oil and natural gas industry primarily in Oklahoma, Texas, Pennsylvania and Ohio.
	Principles of Consolidation. The unaudited condensed consolidated financial statements include the accounts of the Partnership and its wholly owned and majority owned subsidiaries. Noncontrolling interest represents third-party ownership interest in a majority owned subsidiary of the Partnership and is included as a component of equity in the consolidated balance sheet and consolidated statement of unitholders' equity. All significant intercompany accounts and transactions have been eliminated in consolidation.
	Interim Financial Statements. The accompanying condensed consolidated financial statements as of December 31, 2013 have been derived from the audited financial statements contained in the Partnership’s 2013 Form 10-K. The unaudited interim condensed consolidated financial statements have been prepared by the Partnership in accordance with the accounting policies stated in the audited consolidated financial statements contained in the 2013 Form 10-K. Certain information and disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") have been condensed or omitted, although the Partnership believes that the disclosures contained herein are adequate to make the information presented not misleading. In the opinion of management, all adjustments, which consist only of normal recurring adjustments, necessary to state fairly the information in the Partnership’s accompanying unaudited condensed consolidated financial statements have been included. These unaudited condensed consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in the 2013 Form 10-K.
	Significant Accounting Policies. For a description of the Partnership’s significant accounting policies, refer to Note 1 of the consolidated financial statements included in the 2013 Form 10-K.
	Reclassifications. Certain reclassifications have been made to the prior period financial statements to conform to the current period presentation. These reclassifications have no effect on the Partnership's previously reported results of operations.
	Use of Estimates. The preparation of the Partnership’s consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of the Partnership’s consolidated financial statements, as well as the reported amounts of revenue and expenses during the reporting periods. The Partnership’s consolidated financial statements are based on a number of significant estimates, including oil, natural gas and NGL reserves, revenue and expense accruals, depreciation, depletion and amortization, fair value of derivative instruments and contingent consideration, the allocation of purchase price to the fair value of assets acquired and liabilities assumed and asset retirement obligations. Actual results could differ from those estimates.
	Recently Issued Accounting Standard. In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers, ("ASU 2014-09"), which revises the guidance on revenue recognition by providing a single, principles-based method for companies to use to account for revenue arising from contracts with customers.  The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires disclosures enabling users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. ASU 2014-09 is effective for fiscal years beginning after December 15, 2016 and is to be applied retrospectively. Early application is not permitted. We are in the process of assessing the potential impact of ASU 2014-09 on the Partnership's financial statements.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Acquisitions	'
	Acquisitions
	The Partnership completed acquisitions during 2013 and 2014, as described below. Certain of the 2013 acquisitions increased the Partnership's portfolio of oil and natural gas properties. The acquisitions of MCE, Erick Flowback Services LLC ("EFS"), Rod's Production Services, L.L.C. ("RPS") and MidCentral Completion Services, LLC ("MCCS") help to facilitate the Partnership's goals of becoming a more fully integrated oil and natural gas partnership. With the exception of the acquisition of oil and natural gas properties from Orion Exploration Partners, LLC, all of the 2013 acquisitions were with related parties. The acquisition of MCCS was the only acquisition in 2014 with related parties. See Note 11 "Related Party Transactions."
	The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs under the fair value hierarchy as described in Note 7 "Fair Value Measurements." Fair value may be estimated using comparable market data, a discounted cash flow method, or another method as discussed below. In the discounted cash flow method, estimated future cash flows are based on management’s expectations for the future and include estimates of applicable sales estimates, operational costs and a risk-adjusted discount rate. The fair values of oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties included estimates of: (i) reserves, including risk adjustments for probable and possible reserves; (ii) production rates; (iii) future operating and development costs; (iv) future commodity prices; (v) future cash flows; and (vi) a market-based weighted average cost of capital rate. Fair value of MCCS' inventory acquired was determined based on a comparative sales approach. Fair value for intangible assets acquired was primarily determined using a discounted cash flow model or multi-period excess earnings model under the income approach, which factors in discount rates, probability factors and forecasts. The fair values of property, plant and equipment acquired were primarily based on a cost approach using an indirect cost methodology to determine replacement cost. The inputs, as noted above, used to determine fair value required significant judgments and estimates by the Partnership’s management at the time of the valuation and are the most sensitive and subject to change. Carrying value for current assets and liabilities acquired is typically representative of fair value due to their short term nature.
	2013 Acquisitions
	March Acquired Properties. In March 2013, we acquired certain oil and natural gas properties located in the Golden Lane and Luther fields in Oklahoma from New Source, Scintilla, and W.K. Chernicky, LLC, for an aggregate adjusted purchase price of $28.0 million (the "March Acquired Properties"). As consideration, the Partnership issued 1,378,500 common units valued at $20.30 per unit.
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	29,049
	Other assets	754
	Asset retirement obligations	(1,333		)
	Other liabilities	(488		)
	Total net assets	$	27,982
	May Acquired Properties. In May 2013, the Partnership completed an acquisition of certain oil and natural gas properties located in Oklahoma from New Source Energy for $7.9 million, net of purchase price adjustments (the "May Acquired Properties").
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	8,165
	Asset retirement obligations	(19		)
	Other liabilities	(254		)
	Total net assets	$	7,892
	The amounts of revenues and excess of revenues over direct operating expenses included in the accompanying unaudited condensed consolidated statements of operations for the three and six months ended June 30, 2013 generated by the March Acquired Properties and the May Acquired Properties are shown in the table below. Direct operating expenses include lease operating expenses and production taxes.
		Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
		(in thousands)
	Revenue	$	2,692		$	2,777
	Excess of revenues over direct operating expenses	$	1,286		$	1,333
	Acquisition expense related to the March Acquired Properties and the May Acquired Properties of $0.5 million was included in general and administrative expenses in the accompanying unaudited condensed consolidated statements of operations for both the three and six months ended June 30, 2013.
	July Scintilla Acquired Properties. In July 2013, the Partnership completed an acquisition of a 10% working interest in certain oil and natural gas properties located in Oklahoma from Scintilla for $4.9 million, net of purchase price adjustments.
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	4,888
	Asset retirement obligations	(4		)
	Other liabilities	(18		)
	Total net assets	$	4,866
	Orion Acquired Properties. In July 2013, the Partnership acquired certain oil and natural gas properties located in Oklahoma from Orion Exploration Partners, LLC for $3.2 million, net of purchase price adjustments.
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	3,274
	Asset retirement obligations	(24		)
	Other liabilities	(20		)
	Total net assets	$	3,230
	Southern Dome Acquired Properties. In October 2013, the Partnership completed the 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 for total consideration of $14.5 million, net of purchase price adjustments.
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Consideration:
	Cash	$	4,260
	Fair value of common units granted (1)	8,608
	Contingent consideration (2)	1,600
	Total fair value of consideration	$	14,468
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	15,190
	Asset retirement obligations	(170		)
	Other liabilities	(552		)
	Total net assets	$	14,468
	__________
	-1	The fair value of the unit consideration was based upon 414,045 common units valued at $20.79 per unit (closing price on the date of the acquisition).
	-2	The Partnership agreed to provide additional consideration to Scintilla if average daily production attributable to the acquired working interests exceeds a specified average daily production during the specified period (the "Southern Dome Contingent Consideration"). See Note 3 "Contingent Consideration" for additional discussion of the Southern Dome Contingent Consideration.
	MCE Acquisition. In November 2013, the Partnership acquired 100% of the equity interests in MCE, other than Class B Units that were retained by certain of the sellers as discussed further below (the "MCE Acquisition"). MidCentral Energy Services, LLC ("MCES"), a wholly owned subsidiary of MCE, operates an oilfield services business that offers full service blowout prevention installation and pressure testing services throughout the Mid-Continent region and in South Texas and West Texas, along with the rental of certain ancillary equipment necessary to perform such services.
	Total consideration for the MCE Acquisition is as follows (in thousands):
	Consideration:
	Cash	$	3,781
	Fair value of common units granted (1)	41,822
	Common units granted to MCE employees (2)	2,259
	Contingent consideration (3)	6,320
	MCE Class B units granted (4)	13,988
	Total fair value of consideration	$	68,170
__________
-1	The fair value of the unit consideration was based upon 1,847,265 common units valued at $22.64 per unit (closing price on the date of the acquisition).
-2	The fair value of the unit consideration was based upon 99,768 common units valued at $22.64 per unit (closing price on the date of the acquisition). These common units were issued to certain employees of MCE under the Partnership’s long-term incentive plan, primarily for service prior to the acquisition. Any forfeited common units do not revert to the Partnership, but would be distributed to the former owners of MCE.
-3	The owners of MCE are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCES for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $120.0 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCE Contingent Consideration.
-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 9 "Equity" for additional discussion of these incentive distributions. The Class B units were valued at $14.0 million at the acquisition date through the use of a Monte Carlo simulation.
The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
Fair value of assets acquired and liabilities assumed:
Cash	$	1,522
Accounts receivable	3,365
Other current assets	954
Property and equipment	7,923
Intangible asset (1)	36,772
Goodwill (2)	23,974
Other assets	19
Total assets acquired	74,529
Accounts payable and accrued liabilities	(2,345		)
Factoring payable	(1,679		)
Long-term debt	(2,335		)
Total liabilities assumed	(6,359		)
Net assets acquired	$	68,170
__________
-1	Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years.
-2	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. Such goodwill is not 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. Goodwill has been allocated to the oilfield services segment.
Since the President and Chief Executive Officer of the Partnership's general partner, Kristian B. Kos, through his control over the Partnership’s general partner, controls the Partnership and also owned 36% of the equity interest in MCE, the MCE Acquisition was accounted for as a business combination achieved in stages. The Partnership initially recorded the 36% equity interest in MCE acquired from Mr. Kos at his equity method carrying basis, which was $1.8 million as of November 12, 2013. The Partnership remeasured the 36% interest to determine the acquisition-date fair value and recognized a corresponding gain of $22.7 million on investment in acquired business.
2014 Acquisitions
CEU Acquisition. On January 31, 2014, we completed the 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") for $17.1 million, net of purchase price adjustments (the "CEU Acquisition").
The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition, net of purchase price adjustments, is as follows (in thousands):
Consideration:
Cash	$	5,503
Fair value of common units granted (1)	11,621
Contingent consideration (2)	—
Total fair value of consideration	$	17,124
Fair value of assets acquired and liabilities assumed:
Proved oil and natural gas properties	$	17,306
Asset retirement obligations	(182		)
Total net assets	$	17,124
__________
-1	The fair value of the unit consideration was based upon 488,667 common units valued at $23.78 per unit (closing price on the date of the acquisition).
-2	The Partnership agreed to provide additional consideration to CEU if average daily production attributable to the acquired working interests exceeds a specified average daily production during a specified period (the "CEU Contingent Consideration"). See Note 3 "Contingent Consideration" for additional discussion of the CEU Contingent Consideration.
MCCS Acquisition. On June 26, 2014, we exercised the option granted in connection with the MCE Acquisition to acquire 100% of the equity interest in MCCS, an oilfield services company that specializes in providing services, primarily installation and pressure testing, to oil and natural gas exploration and production companies (the "MCCS Acquisition").
Total consideration for the MCCS Acquisition is as follows (in thousands):
Consideration:
Fair value of common units granted (1)	$	789
Contingent consideration (2)	4,057
Noncontrolling interest (3)	1,509
Total fair value of consideration	$	6,355
__________
-1	The fair value of the unit consideration was based upon 33,646 common units valued at $23.45 per unit (closing price on the date of the acquisition).
-2	The owners of MCCS are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $4.5 million cap ("MCCS Contingent Consideration"). The MCCS Contingent Consideration was valued at $4.1 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCCS Contingent Consideration.
-3	As a condition of the acquisition agreement, MCCS was contributed to MCE by the Partnership, which increased the value of the noncontrolling interest held by MCE's Class B unitholders. The increase in the value of the noncontrolling interest that resulted from this is part of the total consideration paid for the MCCS Acquisition and was valued at the acquisition date through the use of a Monte Carlo simulation.
The following table summarizes the assets acquired and the liabilities assumed as of the acquisition date at estimated fair value (in thousands):
Fair value of assets acquired and liabilities assumed:
Cash	$	109
Accounts receivable	524
Inventory	2,035
Other current assets	14
Property and equipment	107
Intangible asset (1)	1,700
Goodwill (2)	4,060
Other assets	28
Total assets acquired	8,577
Accounts payable and accrued liabilities	(1,431		)
Long-term debt	(791		)
Total liabilities assumed	(2,222		)
Net assets acquired	$	6,355
__________
-1	Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years.
-2	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the acquisition of MCCS includes any intangible assets that do not qualify for separate recognition, such as the MCCS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships and integrating new product offerings into MCCS's business. Goodwill has been allocated to the oilfield services segment.
Since the President and Chief Executive Officer of the Partnership's general partner, Kristian B. Kos, through his control over the Partnership’s general partner, controls the Partnership and also owned 50% of the equity interest in MCCS, the MCCS Acquisition was accounted for as a business combination achieved in stages. The Partnership initially recorded the 50% equity interest in MCCS acquired from Mr. Kos at his equity method carrying basis, which was $0.1 million as of June 26, 2014. The Partnership remeasured the 50% interest to determine the acquisition-date fair value and recognized a corresponding gain of $2.3 million on investment in acquired business.
Services Acquisition. On June 26, 2014, the Partnership acquired 100% of the outstanding membership interests in EFS and 100% of the outstanding membership interests in RPS for total consideration of approximately $108.3 million (the "Services Acquisition"). EFS and RPS are oilfield services companies that specialize in providing well testing and flowback services to the oil and natural gas industry.
Total consideration for the Services Acquisition is as follows (in thousands):
Consideration:
Cash	$	57,348
Fair value of common units granted (1)	33,106
Common units granted for the benefit of EFS/RPS employees (2)	724
Contingent consideration (3)	17,144
Total fair value of consideration	$	108,322
__________
-1	The fair value of the unit consideration was based upon 1,411,777 common units valued at $23.45 per unit (closing price on the date of the acquisition).
-2	The fair value of the unit consideration was based upon 30,867 common units valued at $23.45 per unit (closing price on the date of the transaction). These units were issued to satisfy the settlement of phantom units granted to EFS employees with no service requirement. An additional 401,171 common units were issued and are held in escrow to satisfy the future settlement of phantom units granted to EFS and RPS employees in conjunction with the Services Acquisition are excluded from consideration based on the future service requirement for vesting. See Note 9 "Equity" for additional discussion of phantom units.
-3	The former owners of EFS and RPS are entitled to receive additional consideration in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments ("EFS/RPS Contingent Consideration"). The EFS/RPS Contingent Consideration was valued at $17.1 million at the acquisition date through the use of a probability analysis. See Note 3 "Contingent Consideration" for additional discussion of the EFS/RPS Contingent Consideration.
The following table summarizes the assets acquired and the liabilities assumed as of the acquisition date at estimated fair value (in thousands):
Fair value of assets acquired and liabilities assumed:
Cash	$	1,668
Accounts receivable	21,611
Other current assets	247
Property and equipment	43,151
Goodwill (1)	11,665
Intangible assets (2)	68,700
Total assets acquired	147,042
Accounts payable and accrued liabilities	(6,080		)
Factoring payable	(15,840		)
Long-term debt	(16,800		)
Total liabilities assumed	(38,720		)
Net assets acquired	$	108,322
__________
-1	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the Services Acquisition includes any intangible assets that do not qualify for separate recognition, such as the EFS and RPS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships. Goodwill has been allocated to the oilfield services segment.
-2	Identifiable intangible assets include $64.2 million for customer relationships and $4.5 million for non-compete agreements. Customer relationships were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years. Non-compete agreements were valued based on an income approach and are amortized over the agreement period.
Pro forma financial information. The following unaudited pro forma combined results of operations are presented for the three and six months ended June 30, 2014 as though the Partnership completed the CEU Acquisition and the Services Acquisition (collectively, the "2014 Material Acquisitions") as of January 1, 2013. The pro forma combined results of operations for the three and six months ended June 30, 2014 have been prepared by adjusting the historical results of the Partnership to include the historical results of the 2014 Material Acquisitions through the dates of acquisition and estimates of the effect of these transactions on the combined results. In addition, pro forma adjustments have been made assuming the units issued as consideration for these acquisitions and a portion of the units issued in the April 2014 equity offering, the proceeds from which were used to fund an acquisition, had been outstanding since January 1, 2013. Future results may vary significantly from the results reflected in this pro forma financial information because of future events and transactions, as well as other factors.
	Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
	(in thousands)
Revenue	$	55,881		$	116,166
Net income (1)	$	4,079		$	6,186
Net income per common unit (1):
Basic	$	0.24		$	0.37
Diluted	$	0.24		$	0.37
__________
-1	Excludes $23.9 million of acquisition costs and transaction bonuses paid to EFS and RPS employees that were included in the historical results of the Partnership, EFS or RPS.
The amounts of revenues and operating income included in the accompanying unaudited condensed consolidated statements of operations for the three and six months ended June 30, 2014 generated by the 2014 Material Acquisitions are shown in the table below. The operating income attributable to the CEU Acquisition represents the excess of revenue over direct operating expenses and does not reflect certain expenses, such as general and administrative; therefore, this information is not intended to report results as if these operations were managed on a stand-alone basis. Direct operating expenses include lease operating expenses and production and other taxes for the CEU Acquisition.
	Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
	(in thousands)
Revenue	$	3,054		$	4,937
Operating income	$	1,077		$	2,196
Acquisition expense for the 2014 Material Acquisitions of $1.3 million was included in general and administrative expenses in the accompanying unaudited statements of operations for both the three and six months ended June 30, 2014.
The following unaudited pro forma combined results of operations are presented for the three and six months ended June 30, 2013 as though the Partnership completed the acquisitions of the March Acquired Properties, the Southern Dome Acquired Properties and the MCE Acquisition (collectively, the "2013 Material Acquisitions") as of January 1, 2012, which was the beginning of the earliest period presented at the time of the acquisition, and the 2014 Material Acquisitions, as of January 1, 2013. The pro forma combined results of operations for the three and six months ended June 30, 2013 have been prepared by adjusting the historical results of the Partnership to include the historical results of these acquisitions through the date of acquisition and estimates of the effect of the 2013 Material Acquisitions and the 2014 Material Acquisitions on the combined results. In addition, pro forma adjustments have been made for the interest that would have been incurred for financing the cash portion of the consideration of the 2013 Material Acquisitions with the Partnership's senior secured revolving credit facility and assume the units issued as consideration for the 2013 Material Acquisitions had been outstanding since January 1, 2012 and the units issued as consideration for the 2014 Material Acquisitions and a portion of the units issued in the April 2014 equity offering, the proceeds from which were used to fund an acquisition, had been outstanding since January 1, 2013.
	Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
	(in thousands)
Revenue	$	48,942		$	102,993
Net income (loss) (1)	$	1,776		$	(3,628	)
Net income (loss) per common unit (1):
Basic	$	0.11		$	(0.41	)
Diluted	$	0.11		$	(0.41	)
__________
(1)    Includes $1.4 million of the Partnership's acquisition costs related to the 2014 Material Acquisitions in the six months ended June 30, 2013.

Contingent_Consideration

Contingent Consideration	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Contingent Consideration	'
	Contingent Consideration
	The contingent consideration provided for in certain of our acquisitions represents additional consideration. The fair value of such contingent consideration is estimated using various inputs, including the probability that targets for additional payout will be met, as described below. As the significant inputs to determine fair value of the contingent consideration represent significant unobservable inputs, they are classified as Level 3 under the fair value hierarchy described in Note 7 "Fair Value Measurements."
	A reconciliation of the beginning and ending balances of acquisition-related contingent consideration for the three and six months ended June 30, 2014 is as follows (in thousands):
		Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
	Contingent consideration, beginning balance	$	6,753		$	6,320
	Acquisition date fair value of contingent consideration - CEU Acquisition	—			—
	Acquisition date fair value of contingent consideration - MCCS Acquisition	4,057			4,057
	Acquisition date fair value of contingent consideration - Services Acquisition	17,144			17,144
	Change in fair value of contingent consideration	(1,345		)	(912		)
	Payment of contingent consideration	—			—
	Contingent consideration, ending balance	$	26,609		$	26,609
	Southern Dome Contingent Consideration. In conjunction with the acquisition of the Southern Dome Acquired Properties, the Partnership agreed to provide additional consideration to Scintilla if the average daily production attributable to the Southern Dome Acquired Properties for the nine months ending September 30, 2014 exceeds 383.5 Boe. We may satisfy any such additional consideration in cash, common units, or a combination thereof at our discretion. The contingent consideration was determined to have a fair value of $1.6 million at the acquisition date and was included in the consideration for the Southern Dome Acquired Properties. As detailed in the acquisition agreement, the additional consideration is calculated as the value of average daily production for the nine months ending September 30, 2014 less (i) the asset value, (ii) capital expenditures incurred attributable to the production growth (including an allowance for the cost of capital for such capital expenditures) and (iii) revenue attributable to any wells located in a specified project area that were not producing in paying quantities as of the effective date of the acquisition. Any change to the fair value of the contingent consideration is adjusted through earnings due to the factors impacting the ultimate payout. Based on estimated production levels for the nine months ending September 30, 2014, the Partnership estimated the fair value as of both June 30, 2014 and December 31, 2013 at $0.
	MCE Contingent Consideration. The former owners of MCE are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCE, excluding EFS, RPS and MCCS, for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $120.0 million cap. The contingent consideration was valued at $6.3 million at the acquisition date and was included in the consideration for the MCE Acquisition. Any change to the fair value of the contingent consideration is adjusted through earnings. Based on projections for MCE, the Partnership estimated fair value of the MCE Contingent Consideration as of June 30, 2014 and December 31, 2013 was approximately $5.4 million and $6.3 million, respectively, which is presented as contingent consideration payable in the accompanying unaudited condensed consolidated balance sheets. The decrease in fair value of approximately $1.3 million and $0.9 million is included in general and administrative expenses in the accompanying unaudited condensed consolidated statements of operations for the three and six months ended June 30, 2014, respectively.
	CEU Contingent Consideration. In conjunction with the CEU Acquisition, the Partnership agreed to provide additional consideration to CEU if the average daily production attributable to the acquired working interest for the nine months ending September 30, 2014 exceeds 566.0 Boe. We may satisfy any such additional consideration in cash, Partnership common units, or a combination thereof at our discretion. The CEU Contingent Consideration was determined to have no value at the acquisition date. As detailed in the acquisition agreement, the additional consideration is calculated as the acquisition value of the production increase less (i) 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 located in a specified project area that were not producing in paying quantities as of the effective date of the acquisition. Any change to the fair value of the contingent consideration is adjusted through earnings. Based on current estimated production levels for the nine months ending September 30, 2014, the Partnership estimated the fair value as of June 30, 2014 at $0.
	MCCS Contingent Consideration. The former owners of MCCS are entitled to receive additional Partnership common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, which is subject to a $4.5 million cap. The contingent consideration was valued at $4.1 million at the acquisition date and was included in the consideration for the MCCS Acquisition. Any changes to the fair value of the contingent consideration will be adjusted through earnings. The fair value of the contingent consideration was unchanged at June 30, 2014.
	EFS/RPS Contingent Consideration. The former owners of EFS and RPS are entitled to receive additional consideration in the form of cash and common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments. The contingent consideration was valued at $17.1 million at the acquisition date and was included in the consideration for the Services Acquisition. Any change to the fair value of the contingent consideration will be adjusted through earnings. The fair value of the contingent consideration was unchanged at June 30, 2014.

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	The Partnership's debt consists of the following (in thousands):
		30-Jun-14		31-Dec-13
	Credit facility	$	85,000	$	78,500
	Notes payable	21,335		2,233
	Line of credit	3,209		—
	Total debt	109,544		80,733
	Less: current maturities of long-term debt	21,677		719
	Long-term debt	$	87,867	$	80,014
	Senior Secured Revolving Credit Facility
	The Partnership has a senior secured revolving credit facility that is available to be drawn on subject to limitations based on its terms and certain financial covenants, as described below, (the "credit facility"). As of June 30, 2014, the credit facility contained financial covenants, including maintaining (i) 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; (ii) a ratio of total debt to EBITDA of not more than 3.5 to 1.0; and (iii) 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 governing the credit facility. The financial covenants are calculated based on the results of the Partnership, excluding its subsidiaries. The obligations under the credit facility are secured by substantially all of the Partnership's oil and natural gas properties and other assets, excluding assets of all subsidiaries. The credit facility matures in February 2017.
	Additionally, the credit facility contains various covenants and restrictive provisions that, among other things, limit 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 facility permits the Partnership to make distributions to its common unit holders in an amount not to exceed "available cash" (as defined in the First Amended and Restated Agreement of Limited Partnership of the Partnership) if (i) no default or event of default has occurred and is continuing or would result therefrom and (ii) borrowing base utilization under the credit facility does not exceed 90%. As of June 30, 2014, the Partnership was in compliance with all covenants under the credit facility.
	Borrowings under the credit facility bear interest at a base rate (a rate equal to the highest of (a) the Federal Funds Rate plus 0.5%, (b) Bank of Montreal’s prime rate or (c) the London Interbank Offered Rate ("LIBOR") plus 1.0%) 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. Interest and commitment fees are payable quarterly, or in the case of certain LIBOR loans at shorter intervals. The average annual interest rate paid on amounts outstanding under the credit facility during the three months ended June 30, 2014 and 2013 was 3.27% and 3.29%, respectively. The average annual interest rate paid on amounts outstanding under the credit facility during the six months ended June 30, 2014 and 2013 was 3.30% and 3.29%, respectively. At June 30, 2014 and December 31, 2013, the average annual interest rates on borrowings outstanding under the credit facility were 3.19% and 3.25%, respectively. At June 30, 2014, the borrowing base under the credit facility was $102.5 million with $17.5 million of available borrowing capacity and approximately $7.3 million available borrowing capacity before restriction on distribution occurs.
	Notes Payable
	The Partnership has $4.5 million in debt as of June 30, 2014 related to financing notes with various lending institutions for certain property and equipment through MCES. These notes range from 36-60 months in duration with maturity dates from May 2016 through April 2018 and carry variable interest rates ranging from 5.50% to 10.51%. All notes are associated with specific capital assets of MCES and are secured by such assets.
	In conjunction with the Services Acquisition, the Partnership assumed the outstanding balances on term loans held by EFS. These term loans had a balance of $16.8 million as of June 30, 2014 and mature on June 26, 2015. The term loans have a variable interest rate based on the Bank 7 Base Rate minus 2.3%, which was 5.5% at June 30, 2014, with a minimum interest rate of 5.5%. The Partnership is required to maintain a reserve bank account of the lesser of $0.3 million or 100% of excess cash flow (as defined in the loan agreement). The Partnership has a balance of $1.0 million in the reserve account at June 30, 2014, which is shown as restricted cash on the accompanying unaudited condensed consolidated balance sheet. Payments of principal and interest are due in monthly installments. The term loans are collateralized by various assets of the parties to the agreement and guaranteed by MCE and former owners of EFS and RPS.
	The EFS term loan agreement contains various covenants and restrictive provisions that, among other things, limit the ability of EFS and RPS to incur additional debt, guarantees or liens; consolidate, merge or transfer all or substantially all of its assets; make certain investments; and dispose of assets. Additionally, beginning October 1, 2014, EFS and RPS must comply with certain financial covenants, including maintaining (i) a fixed charge ratio of not less than 1.25 to 1.0 (ii) a leverage ratio of not greater than 1.5 to 1.0, and (iii) a working capital and cash balance of at least $4.0 million, in each case as more fully described in the loan agreement.
	Line of Credit
	In February 2014, MCES entered into a loan agreement for a revolving line of credit of up to $4.0 million, based on a borrowing base of $4.0 million related to MCES' accounts receivable. Interest only payments are due monthly with the line of credit maturing in February 2015. The line of credit replaced MCES' factoring payable agreement described in Note 5 "Factoring Payable." Interest on the line of credit accrues at the Bank of Oklahoma Financial Corporation National Prime Rate, which was 4.0% at June 30, 2014. The line of credit is secured by accounts receivable, inventory, chattel paper, and general intangibles of MCES. Based on the outstanding balance of $3.2 million, there was $0.8 million of available borrowing capacity at June 30, 2014.
	As of June 30, 2014, the line of credit contained a covenant requiring a debt service coverage ratio, as defined in agreement, of not less than 1.25 to 1.0. As of June 30, 2014, MCES was in compliance with this covenant under the line of credit.

Factoring_Payable

Factoring Payable	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Factoring Payable	'
	Factoring Payable
	The Partnership was a party to a secured borrowing agreement to factor the accounts receivable of MCES. At December 31, 2013, the outstanding balance was $1.9 million. The outstanding balance was paid and the agreement was terminated in February 2014 when MCES established its line of credit. See Note 4 "Debt" for discussion of MCES' line of credit.
	In conjunction with the Services Acquisition, the Partnership assumed the EFS and RPS factoring agreements. Under these factoring agreements, invoices to pre-approved customers are submitted to the bank and the Partnership receives 90% funding immediately, and 10% is held in a reserve account with the factoring company for each invoice that is factored. Factoring fees, calculated based on three month LIBOR plus 5% (subject to a monthly minimum), are deducted from collected receivables. These factoring fees, along with an annual fee, are included in interest expense in the statement of operations. 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. The outstanding balance of the factoring payable was $16.2 million as of June 30, 2014.

Derivative_Contracts

Derivative Contracts	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Contracts	'
	Derivative Contracts
	Due to the volatility of commodity prices, the Partnership periodically enters into derivative contracts to achieve a more predictable cash flow, as well as to reduce exposure from price fluctuations for a portion of its oil, natural gas and NGL production. While the use of derivative contracts 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 derivative contracts apply to only a portion of its expected production, provide only partial price protection against declines in market prices and limit the Partnership’s potential gains from future increases in market prices. Changes in the derivatives' fair values are recognized in earnings since the Partnership has elected not to designate its derivative contracts as hedges for accounting purposes.
	At June 30, 2014, the Partnership's derivative contracts consisted of collars, put options, and fixed price swaps, as described below:
	Collars	The instrument contains a fixed floor price (long put option) and ceiling price (short call option), where the purchase price of the put option equals the sales price of the call option. At settlement, if the market price exceeds the ceiling price, the Partnership pays the difference between the market price and the ceiling price. If the market price is less than the fixed floor price, the Partnership receives the difference between the fixed floor price and the market price. If the market price is between the ceiling and the fixed floor price, no payments are due from either party.
	Put options	The Partnership periodically buys put options. At the time of settlement, if market prices are below the fixed price of the put option, the Partnership is entitled to the difference between the put option and the fixed price.
	Fixed price swaps	The Partnership receives a fixed price for the contract and pays a floating market price to the counterparty over a specified period for a contracted volume.
	The following tables present our derivative instruments outstanding as of June 30, 2014:
	Oil collars		Volumes		Floor Price				Ceiling Price
			(Bbls)
	2014		46,788		$	80			$	103.5
	2015		42,649		$	80			$	93.25
	Natural gas collars		Volumes		Floor Price				Ceiling Price
			(MMBtu)
	2014		676,776		$	4			$	4.41
	2015		1,362,382		$	4			$	4.32
	Oil put options		Volumes (Bbls)		Floor Price
	2014		17,548		$	80
	Natural gas put options		Volumes		Floor Price
			(MMBtu)
	2014		237,434		$	3.5
	2015		799,853		$	3.5
	2016		930,468		$	3.5
	NGL put options		Volumes (Bbls)		Average Floor
					Price
	2014		17,506		$	56.53
	Oil fixed price swaps		Volumes (Bbls)		Weighted Average Fixed Price
	2014		2,382		$	90.2
	2015		39,411		$	88.9
	2016		36,658		$	86
	Natural gas fixed price swaps		Volumes		Weighted Average Fixed Price
			(MMBtu)
	2014		461,571		$	4.09
	2015		800,573		$	4.25
	2016		629,301		$	4.37
	NGL fixed price swaps		Volumes		Weighted Average Fixed Price
			(Bbls)
	2014		341,868		$	54.96
	2015		84,793		$	75.18
	By using derivative instruments to mitigate exposures to changes in commodity prices, the Partnership exposes itself to credit risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. The Partnership nets derivative assets and liabilities for counterparties where it has a legal right of offset. Such credit risk is mitigated by the fact that the Partnership's derivatives counterparties are major financial institutions with investment grade credit ratings, some of which are lenders under the Partnership's credit facility.  In addition, the Partnership routinely monitors the creditworthiness of its counterparties.
	The following table summarizes our derivative contracts on a gross basis, the effects of netting assets and liabilities for which the right of offset exists (in thousands):
	30-Jun-14		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset				Net Amounts Presented
	Assets:
	Commodity derivatives - current assets		$	18,154		$	(18,103	)		$	51
	Commodity derivatives - long-term assets		9,652			(9,353		)		299
	Total		$	27,806		$	(27,456	)		$	350
	Liabilities:
	Commodity derivatives - current liabilities		$	21,238		$	(18,103	)		$	3,135
	Commodity derivatives - long-term liabilities		10,098			(9,353		)		745
	Total		$	31,336		$	(27,456	)		$	3,880
	31-Dec-13		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset				Net Amounts Presented
	Assets:
	Commodity derivatives - current assets		$	1,342		$	(1,212	)		$	130
	Commodity derivatives - long-term assets		1,638			(978		)		660
	Total		$	2,980		$	(2,190	)		$	790
	Liabilities:
	Commodity derivatives - current liabilities		$	4,379		$	(1,212	)		$	3,167
	Commodity derivatives - long-term liabilities		1,015			(978		)		37
	Total		$	5,394		$	(2,190	)		$	3,204
	See Note 7 "Fair Value Measurements" for additional information on the fair value measurement of the Partnership's derivative contracts.
	The following table presents (loss) gain on our derivative contracts as included in the accompanying unaudited statements of operations for the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,							Six Months Ended June 30,
		2014			2013				2014			2013
	Total (loss) gain on derivative contracts, net (1)	$	(1,396	)	$	6,182			$	(4,528	)	$	856
__________
-1	Included in (loss) gain on derivative contracts for the three months ended June 30, 2014 and 2013 are net cash payments upon contract settlement of $1.0 million and $0.1 million, respectively. Included in (loss) gain on derivative contracts for the six months ended June 30, 2014 and 2013 are net cash payments upon contract settlement of $3.4 million and $0.3 million, respectively.

Fair_Value_Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	We measure and report certain assets and liabilities at fair value and classify and disclose our fair value measurements based on the levels of the fair value hierarchy, as described below:
	Level 1:     Measured based on unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities.
	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.
	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).
	Assets and liabilities that are measured at fair value 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, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
	Level 2 Fair Value Measurements
	Derivative contracts. The fair values of our commodity collars, put options and fixed price swaps are based upon inputs that are either readily available in the public market, such as oil and natural gas futures prices, volatility factors and discount rates, or can be corroborated from active markets. 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.
	Level 3 Fair Value Measurements
	Derivative contracts. The fair values of our natural gas and NGL put options and NGL fixed price swaps at December 31, 2013 were based upon quotes obtained from counterparties to the derivative contracts. These values were reviewed internally for reasonableness. The significant unobservable inputs used in the fair value measurement of our natural gas and NGL put options and NGL fixed price swaps were the estimated probability of exercise and the estimate of NGL futures prices. Significant increases (decreases) in the probability of exercise and NGL futures prices could result in a significantly higher (lower) fair value measurement.
	The following table sets forth by level within the fair value hierarchy the Partnership’s financial assets and liabilities that were measured at fair value on a recurring basis (in thousands):
	30-Jun-14		Fair Value Measurements
	Description		Active Markets for Identical Assets (Level 1)			Observable Inputs (Level 2)				Unobservable Inputs (Level 3)				Total Carrying Value
	Oil and natural gas collars		$	—		$	(671	)		$	—			$	(671	)
	Oil, natural gas and NGL put options		—			230				—				230
	Oil, natural gas and NGL fixed price swaps		—			(3,089		)		—				(3,089		)
	Total		$	—		$	(3,530	)		$	—			$	(3,530	)
	31-Dec-13		Fair Value Measurements
	Description		Active Markets for Identical Assets (Level 1)			Observable Inputs (Level 2)				Unobservable Inputs (Level 3)				Total Carrying Value
	Oil collars		$	—		$	(57	)		$	—			$	(57	)
	Natural gas collars		—			—				(9		)		(9		)
	Oil put options		—			28				—				28
	Natural gas and NGL put options		—			—				403				403
	Oil and natural gas fixed price swaps		—			132				—				132
	NGL fixed price swaps		—			—				(2,911		)		(2,911		)
	Total		$	—		$	103			$	(2,517	)		$	(2,414	)
	The following table sets forth a reconciliation of our derivative contracts measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,							Six Months Ended June 30,
		2014			2013				2014				2013
	Beginning balance	$	(2,843	)	$	(2,854	)		$	(2,517	)		$	(112	)
	Gains (losses)	—			4,812				(2,432		)		1,755
	Transfers out (1)	2,843			—				2,843				—
	Cash (paid) received upon settlement	—			(92		)		2,106				223
	Ending balance	$	—		$	1,866			$	—			$	1,866
	Unrealized gains included in earnings relating to derivatives held at period end	$	—		$	4,720			$	—			$	1,978
	__________
	-1	Fair values related to the Company’s natural gas collars, natural gas and NGL put options and NGL fixed price swaps were transferred from Level 3 to Level 2 in the second quarter of 2014 due to enhancements to the Company’s internal valuation process, including the use of observable inputs to assess the fair value. During the three and six months ended June 30, 2013, the Company did not have any transfers between Level 1, Level 2 or Level 3 fair value measurements. The Company’s policy is to recognize transfers in and/or out of fair value hierarchy levels as of the beginning of the quarterly reporting period in which the event or change in circumstances causing the transfer occurred.
	See Note 6 "Derivative Contracts" for additional discussion of our derivative contracts.
	Fair Value of Financial Instruments
	Credit Facility. The carrying amount of the credit facility of $85.0 million and $78.5 million as of June 30, 2014 and December 31, 2013, respectively, approximates fair value because the Partnership's current borrowing rate does not materially differ from market rates for similar bank borrowings.
	Notes Payable. The carrying value of our notes payable of $21.3 million and $2.2 million at June 30, 2014 and December 31, 2013 approximated fair value based on rates applicable to similar instruments.
	The credit facility and notes payable are classified as a Level 2 item within the fair value hierarchy.
	Fair Value on a Non-Recurring Basis
	The Partnership performs valuations on a non-recurring basis primarily as it relates to the consideration, assets acquired, and liabilities assumed related to acquisitions. See Note 2 "Acquisitions" for discussion of these valuations.

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets	'
	Goodwill and Intangible Assets
	Goodwill
	Goodwill represents the estimated future economic benefits arising from other assets acquired in business combinations that could not be individually identified and separately recognized. See Note 2 "Acquisitions" for discussion of our business acquisitions. Such goodwill is not deductible for tax purposes. Goodwill has been allocated to the oilfield services segment. A reconciliation of the aggregate carry amount of goodwill for the period from December 31, 2013 to June 30, 2014 is as follows (in thousands):
	Goodwill at December 31, 2013	$	23,974
	Additions:
	Services Acquisition	11,664
	MCCS Acquisition	4,060
	Goodwill at June 30, 2014	$	39,698
	Intangible Assets
	Intangible assets were identified in the acquisitions during 2013 and 2014. See Note 2 "Acquisitions" for discussion of our business acquisitions. Intangible assets are amortized over the expected cash flow period for customer relationships and over the agreement period for the non-compete agreements. Amortization expense for the three and six months ended June 30, 2014 was $3.1 million and $6.2 million, respectively. The Partnership's intangible assets at June 30, 2014 and December 31, 2013 consist of the following (in thousands):
		30-Jun-14		31-Dec-13
	Customer relationships - MCE Acquisition	$	36,772	$	36,772
	Customer relationships - Services Acquisition	64,200		—
	Non-compete agreements - Services Acquisition	4,500		—
	Customer relationships - MCCS Acquisition	1,700		—
	Total intangible assets	107,172		36,772
	Less: accumulated amortization	7,946		1,763
	Intangible assets, net	$	99,226	$	35,009

Equity

Equity	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Equity	'
	Equity
	Common Units
	Issuance for Acquisitions. In January and June 2014, we issued 488,667, 33,646, and 1,411,777 of common units to satisfy the equity portion of the consideration paid in the CEU Acquisition, the MCCS Acquisition, and the Services Acquisition, respectively. See Note 2 "Acquisitions" for additional discussion of these transactions.
	Equity Offering. On April 29, 2014, we completed a public offering of 3,450,000 of our common units at a price of $23.25 per unit. We received net proceeds of approximately $76.2 million from this offering, after deducting underwriting discounts of $3.6 million and offering costs of $0.3 million. We used $5.0 million of the net proceeds from this offering to repay indebtedness outstanding under our credit facility with the remaining proceeds used to fund the cash portion of the Services Acquisition and related acquisition costs and for general corporate purposes.
	Distributions
	Distributions are declared and distributed within 45 days following the end of each quarter. The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common, subordinated and general partner units during the three and six months ended June 30, 2014 and 2013, as shown in the following table (in thousands):
	Distributions	Common Units			Subordinated Units			General Partner Units		Total
	2014
	First Quarter (1)	$	4,681		$	1,268		$	89	$	6,038
	Second Quarter (2)	$	7,852		$	1,279		$	90	$	9,221
	2013
	Second Quarter (3)	$	1,857		$	604		$	43	$	2,504
	__________
	(1)    Reflects quarterly distributions of $0.575 per unit paid in the first quarter of 2014.
	(2)    Reflects quarterly distributions of $0.58 per unit paid in the second quarter of 2014.
	(3)    Prorated to reflect 47 days of the quarterly cash distribution of $0.525 per unit paid in the second quarter of 2013.
	Pursuant to our Partnership Agreement, to the extent that the quarterly distributions exceed certain targets, our 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. No such incentive distributions were made to our general partner as quarterly distributions declared by the board of directors for the first and second quarters of 2014 and 2013 did not exceed the specified targets.
	See Note 15 "Subsequent Events" for discussion of distribution declared in July 2014.
	Noncontrolling Interest
	As part of the MCE Acquisition, 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 based on results of MCES and MCCS. As these Class B Units are not held by the Partnership, they are presented as noncontrolling interest in the accompanying unaudited condensed 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 the Partnership.
	As a result of the MCCS Acquisition, the specified target distribution levels for the allocations of MCE's available cash from operating surplus between the Class A unitholders and the Class B unitholders was adjusted for the capital contribution by the Partnership as provided for in the amended and restated MCE partnership agreement. The following table illustrates the 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, as adjusted based on the MCCS Acquisition.
					Marginal Percentage Interest in
					Distributions
		Total Quarterly Distributions per MCE Unit			MCE Class A Unitholders (the Partnership)		MCE Class B Unitholders
	Minimum Quarterly Distribution	$16,116			100%		—%
	First Target Distribution	$18,533	to	$20,144	85%		15%
	Second Target Distribution	$20,145	to	$24,173	75%		25%
	Third Target Distribution and Thereafter	$24,174	and above		50%		50%
	Based on MCE's distribution amounts for 2014, the MCE Class B unitholders were not entitled to distributions during the six months ended June 30, 2014.
	Equity Compensation
	We may grant awards of the Partnership's common units to employees. Such awards are valued based upon the market value of common units on the date of grant and expensed over the relevant vesting period to the extent the awards contain a service requirement. If there is no service requirement, the awards are expensed at the time of grant. For the three and six months ended June 30, 2014, the Partnership recorded equity-based compensation expense of $0.4 million and $0.6 million, respectively. For the six months ended June 30, 2013, the Partnership recorded equity-based compensation expense of $7.7 million. Additionally, the Partnership had $0.4 million of allocated equity-based compensation from New Source Energy during the six months ended June 30, 2013. There was no equity-based compensation expense for the three months ended June 30, 2013.
	Phantom Units. In conjunction with the Services Acquisition, the Partnership granted 432,038 phantom units, which represent the right to receive common units or cash equal to the value of the associated common units, to employees of EFS and RPS under the Partnership's Fair Market Value Purchase Plan. The phantom units vest over a period not to exceed 2 years. If a phantom unit is forfeited, the associated common units are released from escrow to the former owners of EFS and RPS. Except as otherwise provided in the Phantom Unit Agreement, phantom units subject to forfeiture restrictions may be forfeited upon termination of employment prior to the end of the vesting period. Although ownership of common units related to the vesting of such phantom units does not transfer to the holder until the phantom units vest, the recipients have distribution equivalent rights on these phantom units from the date of grant.
	Although the phantom unit grants may be settled in either common units or cash at the holder's election, the settlement of the phantom units upon vesting will be made from a transfer or sale of the associated common units that were issued to an escrow account in conjunction with the Services Acquisition. As a result, the 401,171 phantom units valued at $9.4 million with a service requirement were measured at fair market value of the Partnership’s common units on the grant date and are being expensed over the vesting period in accordance with accounting guidance for equity compensation. At June 30, 2014, approximately $9.4 million of expense remains. The associated common units held in escrow are reflected as contra equity on the accompanying unaudited condensed consolidated balance sheet at June 30, 2014.

Earnings_per_Unit

Earnings per Unit	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Earnings per Unit	'
	Earnings per Unit
	The Partnership’s net income is allocated to the common, subordinated and general partner unitholders, in accordance with their respective ownership percentages, and when applicable, giving effect to unvested units granted under the Partnership’s Long-Term Incentive Plan ("LTIP") and incentive distributions allocable to the general partner. The allocation of undistributed earnings, or net income in excess of distributions, to the incentive distribution rights is limited to available cash (as defined by the partnership agreement) for the period. Basic and diluted net income per unit is calculated by dividing net income by the weighted average number of units outstanding during the period. Any common units issued during the period are included on a weighted average basis for the days in which they were outstanding. The Partnership had no potential common units outstanding as of June 30, 2014 or 2013. Therefore, basic and diluted earnings per unit are the same.
	Basic and diluted earnings per unit for the three and six months ended June 30, 2014 and 2013 were computed as follows (in thousands, except per unit amounts):
		Three Months Ended June 30, 2014						Six Months Ended June 30, 2014
		Common Units		Subordinated Units		General Partner		Common Units		Subordinated Units			General Partner
	Net income	$	1,334	$	235	$	17	$	97	$	(40	)	$	(3	)
	Weighted average units outstanding	12,529		2,205		155		11,232		2,205			155
	Basic and diluted income (loss) per unit	$	0.11	$	0.11	$	0.11	$	0.01	$	(0.02	)	$	(0.02	)
		Three Months Ended June 30, 2013						Six Months Ended June 30, 2013
		Common Units		Subordinated Units		General Partner		Common Units		Subordinated Units			General Partner
	Net income (1)	$	6,045	$	1,968	$	138	$	1,397	$	49		$	5
	Weighted average units outstanding	6,774		2,205		155		6,285		2,205			154
	Basic and diluted income per unit	$	0.89	$	0.89	$	0.89	$	0.22	$	0.02		$	0.03
	__________
	-1	Reflects net income from February 13, 2013 through June 30, 2013 for the six months ended June 30, 2013.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Ownership. The Partnership is controlled by the Partnership's general partner, which is owned 69.4% by Kristian Kos, the President and Chief Executive Officer of our general partner, and 25.0% by the Chairman and Senior Geologist of our general partner, David J. Chernicky. Mr. Kos beneficially owns approximately 5.3% of the Partnership's outstanding common units, including common units awarded under the Partnership's long-term incentive plan, and units owned through Deylau, LLC, an entity he controls. Mr. Chernicky beneficially owns approximately 17.2% of the Partnership's outstanding common units, including common units awarded under the Partnership's long-term incentive plan, and units owned through New Source Energy and Scintilla, entities that he controls. In addition, Mr. Chernicky beneficially owns 100% of the 2,205,000 subordinated units through his control of New Source Energy. Mr. Chernicky owns all of the membership interests in New Dominion, which operates all of the Partnership's oil and natural gas properties.
	New Dominion. New Dominion is an exploration and production operator, which is wholly owned by Mr. Chernicky. Pursuant to various development agreements with the Partnership, New Dominion is currently contracted to operate the Partnership’s existing wells. New Dominion has historically performed this service for New Source Energy. In addition to the various development agreements, the Partnership, along with other working interest owners, is a party to an agreement with New Dominion in which we reimburse New Dominion for our proportionate share of costs incurred to construct a gas gathering system. In return, we own a portion of such gas gathering system, which facilitates the transportation of our production in the Greater Golden Lane field to the gas processing plant.
	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 was approximately $0.3 million as of June 30, 2014 and $0.4 million as of December 31, 2013, all of which is classified as a long-term liability in the accompanying unaudited condensed consolidated balance sheets. 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.
	Under agreements with New Dominion, the Partnership incurred charges as follows for the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
	Producing overhead charges	$	454	$	86	$	829	$	256
	Drilling and completion overhead charges	39		97		48		114
	Saltwater disposal fees	443		94		858		173
	Total expenses incurred	$	936	$	277	$	1,735	$	543
	At June 30, 2014 and December 31, 2013, $3.4 million and $1.3 million, respectively, were due to New Dominion for charges and fees under operating agreements and included in accounts payable - related party in the accompanying unaudited condensed consolidated balance sheets.
	New Source Energy. Under an agreement by and among New Source Energy, the Partnership and our general partner, New Source Energy provided administrative services for the Partnership from February 13, 2013 through December 31, 2013. For the three and six months ended June 30, 2013, fees paid for such services were $0.7 million and $1.0 million, respectively, and were included in general and administrative expenses in the accompanying unaudited condensed consolidated statements of operations.
	New Source Energy GP, LLC. Effective January 1, 2014, our general partner began billing us for general and administrative expenses related to payroll, employee benefits and employee reimbursements. For the three and six months ended June 30, 2014, amounts paid to our general partner for such reimbursements were $0.3 million and $0.6 million, respectively, and were included in general and administrative expenses in the accompanying unaudited condensed consolidated statements of operations. Additionally, we received approximately $1.5 million and paid approximately $1.2 million to our general partner during the six months ended June 30, 2014 for operational cash advances. At June 30, 2014 and December 31, 2013, $0.7 million and $0.4 million, respectively, were due to our general partner for reimbursement and included in accounts payable - related party in the accompanying unaudited condensed consolidated balance sheets.
	Acquisitions. As described in Note 2 "Acquisitions," we acquired oil and natural gas properties, MCE and MCCS from related parties. As these acquisitions were with related parties, the transactions were subject to approval by the board of directors of the Partnership's general partner, based on the approval and recommendation of its conflicts committee.
	As discussed in Note 2 "Acquisitions," Mr. Kos was a 36% owner of MCE prior to the MCE Acquisition. Additionally, Dikran Tourian, President-Oilfield Services Division and member of our general partner's board of directors, was a 36% owner of MCE prior to the MCE Acquisition. In conjunction with the MCE Acquisition, Mr. Kos and Mr. Tourian received Class B units that are entitled to incentive distributions as discussed in Note 9 "Equity" as well as contingent consideration as discussed in Note 3 "Contingent Consideration."
	On June 26, 2014, we exercised our option to acquire MCCS, which was owned by Mr. Kos and Mr. Tourian. See Note 2 "Acquisitions" for discussion of this acquisition and Note 3 "Contingent Consideration" for discussion of the MCCS Contingent Consideration.
	Transactions with Chief Financial Officer. The Partnership engaged Finley & Cook, PLLC ("Finley & Cook") to provide various accounting services on our behalf during the three and six months ended June 30, 2014. Richard Finley, the Chief Financial Officer of our general partner, is an equity member of Finley & Cook, holding a 31.5% ownership interest. The Partnership paid Finley & Cook approximately $0.2 million and $0.3 million in fees for the three and six months ended June 30, 2014, respectively. New Source Energy engaged Finley & Cook to provide various accounting services on our behalf during the year ended December 31, 2013. Fees for such accounting services were included in the amounts paid to New Source Energy, as discussed above.

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligation	'
	Asset Retirement Obligations
	A reconciliation of the aggregate carry amounts of the asset retirement obligations for the period from December 31, 2013 to June 30, 2014 is as follows (in thousands):
	Asset retirement obligation at December 31, 2013	$	3,455
	Liabilities incurred upon acquiring and drilling wells	222
	Revision of previous estimates	(33		)
	Accretion	143
	Asset retirement obligation at June 30, 2014	$	3,787

Commitments_and_Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
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. See Note 11 "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 our proportionate share of maintenance and operating costs of New Dominion’s saltwater disposal wells.
	On February 13, 2013, in connection with the closing of our initial public offering, the Partnership entered into a development agreement (the "Development Agreement") with New Source Energy and New Dominion. Pursuant to the Development Agreement, during each of the fiscal years ending December 31, 2013 through December 31, 2016, the Partnership has agreed to maintain an average annual maintenance drilling budget of at least $8.2 million to drill certain of the Partnership’s proved undeveloped locations and maintain the Partnership’s producing wells. As of June 30, 2014, we had incurred $7.0 million towards the annual maintenance drilling budget.
	See Note 3 "Contingent Consideration" for discussion of contingencies related to certain acquisitions.
	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 ("Scissortail"). The plaintiffs assert that royalties to the class should be paid based upon the price received by Scissortail for the natural gas and its components at the tailgate of the plant, rather than the price paid by Scissortail at the wellhead where the natural 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. A hearing on the matter is scheduled for August 27, 2014.
	Any liability on the part of New Dominion, as operator, would be allocated to the working interest owners to pay their proportionate share such liability. While the outcome and impact on the Partnership of this proceeding cannot be predicted with certainty, management believes a loss of up to $250,000 may be reasonably possible. Due to the uncertainty, no reserve has been established for this matter.
	The Partnership may be involved in other various routine legal proceedings incidental to its business from time to time. While the results of litigation and claims cannot be predicted with certainty, the Partnership believes the reasonably possible losses of such matters, individually and in the aggregate, are not material. Additionally, the Partnership believes the probable final outcome of such matters will not have a material adverse effect on the Partnership's consolidated financial position, results of operations, cash flow or liquidity.

Business_Segment_Information

Business Segment Information	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Business Segment Information	'
	Business Segment Information
	The Partnership operates in two business segments: (i) exploration and production and (ii) oilfield services. These segments represent the Partnership’s two main business units, each offering different products and services. The exploration and production segment is engaged in the development and production of oil and natural gas properties. The oilfield services segment provides full service blowout prevention installation and pressure testing services, including certain ancillary equipment necessary to perform such services, as well as well testing and flowback services.
	Management evaluates the performance of the Partnership’s business segments based on the excess of revenue over direct operating expenses or segment margin. Summarized financial information concerning the Partnership’s segments is shown in the following tables (in thousands):
			Exploration and Production			Oilfield Services (1)			Total
	Three Months Ended June 30, 2014
	Revenues		$	16,718		$	10,100		$	26,818
	Direct operating expenses		5,308			5,968			11,276
	Segment margin		$	11,410		$	4,132		$	15,542
	General and administrative expenses		2,022			1,467			3,489
	Depreciation, depletion, amortization and accretion		6,970			3,393			10,363
	Income (loss) from operations		$	2,418		$	(728	)	$	1,690
	Capital expenditures (2)		$	7,709		$	2,177		$	9,886
	Three Months Ended June 30, 2013
	Revenues		$	10,649		$	—		$	10,649
	Direct operating expenses		3,313			—			3,313
	Segment margin		$	7,336		$	—		$	7,336
	General and administrative expenses		1,246			—			1,246
	Depreciation, depletion, amortization and accretion		3,634			—			3,634
	Income from operations		$	2,456		$	—		$	2,456
	Capital expenditures (2)		$	3,170		$	—		$	3,170
	__________
	-1	The Partnership's oilfield services segment was established with the MCE Acquisition that occurred in November 2013. See Note 2 "Acquisitions" for discussion.
	-2	On an accrual basis and exclusive of acquisitions.
			Exploration and Production			Oilfield Services (1)			Total
	Six Months Ended June 30, 2014
	Revenues		$	35,569		$	18,676		$	54,245
	Direct operating expenses		10,690			10,534			21,224
	Segment margin		$	24,879		$	8,142		$	33,021
	General and administrative expenses		5,866			3,184			9,050
	Depreciation, depletion, amortization and accretion		12,857			6,853			19,710
	Income (loss) from operations		$	6,156		$	(1,895	)	$	4,261
	Capital expenditures (2)		$	18,460		$	2,991		$	21,451
	At June 30, 2014
	Total assets		$	199,387		$	237,450		$	436,837
	Six Months Ended June 30, 2013
	Revenues		$	20,009		$	—		$	20,009
	Direct operating expenses		6,713			—			6,713
	Segment margin		$	13,296		$	—		$	13,296
	General and administrative expenses (3)		10,100			—			10,100
	Depreciation, depletion, amortization and accretion		6,858			—			6,858
	Loss from operations		$	(3,662	)	$	—		$	(3,662	)
	Capital expenditures (2)		$	3,516		$	—		$	3,516
	At December 31, 2013
	Total assets		$	181,440		$	73,270		$	254,710
	__________
	-1	The Partnership's oilfield services segment was established with the MCE Acquisition that occurred in November 2013. See Note 2 "Acquisitions" for discussion.
	-2	On an accrual basis and exclusive of acquisitions.
	-3	Includes $7.7 million of compensation expense related to common units granted to consultants, officers, directors and employees in conjunction with our initial public offering.

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Distributions. On July 21, 2014, the Partnership declared quarterly distributions to unitholders of record, including holders of common, subordinated and general partner units for the three months ended June 30, 2014. The following distributions will be paid on August 15, 2014 to holders of record as of the close of business on August 1, 2014 (in thousands):
			Common Units		Subordinated Units		General Partner Units		Total
	Distributions		$	9,025	$	1,290	$	91	$	10,406
	__________
	-1	Distributions were not paid on 13,116 common units issued in conjunction with grants to certain employees made in the second quarter of 2014.

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Interim Financial Statements	'
	Interim Financial Statements. The accompanying condensed consolidated financial statements as of December 31, 2013 have been derived from the audited financial statements contained in the Partnership’s 2013 Form 10-K. The unaudited interim condensed consolidated financial statements have been prepared by the Partnership in accordance with the accounting policies stated in the audited consolidated financial statements contained in the 2013 Form 10-K. Certain information and disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") have been condensed or omitted, although the Partnership believes that the disclosures contained herein are adequate to make the information presented not misleading. In the opinion of management, all adjustments, which consist only of normal recurring adjustments, necessary to state fairly the information in the Partnership’s accompanying unaudited condensed consolidated financial statements have been included. These unaudited condensed consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in the 2013 Form 10-K.
Reclassifications	'
	Reclassifications. Certain reclassifications have been made to the prior period financial statements to conform to the current period presentation. These reclassifications have no effect on the Partnership's previously reported results of operations.
Use of Estimates	'
	Use of Estimates. The preparation of the Partnership’s consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities that exist at the date of the Partnership’s consolidated financial statements, as well as the reported amounts of revenue and expenses during the reporting periods. The Partnership’s consolidated financial statements are based on a number of significant estimates, including oil, natural gas and NGL reserves, revenue and expense accruals, depreciation, depletion and amortization, fair value of derivative instruments and contingent consideration, the allocation of purchase price to the fair value of assets acquired and liabilities assumed and asset retirement obligations. Actual results could differ from those estimates.
Recently Issued Accounting Standard	'
	Recently Issued Accounting Standard. In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers, ("ASU 2014-09"), which revises the guidance on revenue recognition by providing a single, principles-based method for companies to use to account for revenue arising from contracts with customers.  The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 also requires disclosures enabling users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. ASU 2014-09 is effective for fiscal years beginning after December 15, 2016 and is to be applied retrospectively. Early application is not permitted. We are in the process of assessing the potential impact of ASU 2014-09 on the Partnership's financial statements.

Acquisitions_Tables

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Schedule of Business Acquisitions, by Acquisition	'
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	8,165
	Asset retirement obligations	(19		)
	Other liabilities	(254		)
	Total net assets	$	7,892
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Consideration:
	Cash	$	4,260
	Fair value of common units granted (1)	8,608
	Contingent consideration (2)	1,600
	Total fair value of consideration	$	14,468
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	15,190
	Asset retirement obligations	(170		)
	Other liabilities	(552		)
	Total net assets	$	14,468
	__________
	-1	The fair value of the unit consideration was based upon 414,045 common units valued at $20.79 per unit (closing price on the date of the acquisition).
	-2	The Partnership agreed to provide additional consideration to Scintilla if average daily production attributable to the acquired working interests exceeds a specified average daily production during the specified period (the "Southern Dome Contingent Consideration"). See Note 3 "Contingent Consideration" for additional discussion of the Southern Dome Contingent Consideration.
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	29,049
	Other assets	754
	Asset retirement obligations	(1,333		)
	Other liabilities	(488		)
	Total net assets	$	27,982
	The following table summarizes the assets acquired and the liabilities assumed as of the acquisition date at estimated fair value (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Cash	$	109
	Accounts receivable	524
	Inventory	2,035
	Other current assets	14
	Property and equipment	107
	Intangible asset (1)	1,700
	Goodwill (2)	4,060
	Other assets	28
	Total assets acquired	8,577
	Accounts payable and accrued liabilities	(1,431		)
	Long-term debt	(791		)
	Total liabilities assumed	(2,222		)
	Net assets acquired	$	6,355
	__________
	-1	Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years.
	-2	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the acquisition of MCCS includes any intangible assets that do not qualify for separate recognition, such as the MCCS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships and integrating new product offerings into MCCS's business. Goodwill has been allocated to the oilfield services segment.
	otal consideration for the MCE Acquisition is as follows (in thousands):
	Consideration:
	Cash	$	3,781
	Fair value of common units granted (1)	41,822
	Common units granted to MCE employees (2)	2,259
	Contingent consideration (3)	6,320
	MCE Class B units granted (4)	13,988
	Total fair value of consideration	$	68,170
	__________
	-1	The fair value of the unit consideration was based upon 1,847,265 common units valued at $22.64 per unit (closing price on the date of the acquisition).
	-2	The fair value of the unit consideration was based upon 99,768 common units valued at $22.64 per unit (closing price on the date of the acquisition). These common units were issued to certain employees of MCE under the Partnership’s long-term incentive plan, primarily for service prior to the acquisition. Any forfeited common units do not revert to the Partnership, but would be distributed to the former owners of MCE.
	-3	The owners of MCE are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCES for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $120.0 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCE Contingent Consideration.
	-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 9 "Equity" for additional discussion of these incentive distributions. The Class B units were valued at $14.0 million at the acquisition date through the use of a Monte Carlo simulation.
	The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
	Fair value of assets acquired and liabilities assumed:
	Proved oil and natural gas properties	$	4,888
	Asset retirement obligations	(4		)
	Other liabilities	(18		)
Total net assets	$	4,866
The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition is as follows (in thousands):
Fair value of assets acquired and liabilities assumed:
Proved oil and natural gas properties	$	3,274
Asset retirement obligations	(24		)
Other liabilities	(20		)
Total net assets	$	3,230
The following table summarizes the assets acquired and the liabilities assumed as of the acquisition date at estimated fair value (in thousands):
Fair value of assets acquired and liabilities assumed:
Cash	$	1,668
Accounts receivable	21,611
Other current assets	247
Property and equipment	43,151
Goodwill (1)	11,665
Intangible assets (2)	68,700
Total assets acquired	147,042
Accounts payable and accrued liabilities	(6,080		)
Factoring payable	(15,840		)
Long-term debt	(16,800		)
Total liabilities assumed	(38,720		)
Net assets acquired	$	108,322
__________
-1	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the Services Acquisition includes any intangible assets that do not qualify for separate recognition, such as the EFS and RPS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships. Goodwill has been allocated to the oilfield services segment.
-2	Identifiable intangible assets include $64.2 million for customer relationships and $4.5 million for non-compete agreements. Customer relationships were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years. Non-compete agreements were valued based on an income approach and are amortized over the agreement period.
Consideration:
Fair value of common units granted (1)	$	789
Contingent consideration (2)	4,057
Noncontrolling interest (3)	1,509
Total fair value of consideration	$	6,355
__________
-1	The fair value of the unit consideration was based upon 33,646 common units valued at $23.45 per unit (closing price on the date of the acquisition).
-2	The owners of MCCS are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $4.5 million cap ("MCCS Contingent Consideration"). The MCCS Contingent Consideration was valued at $4.1 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCCS Contingent Consideration.
The total purchase price allocated to the assets acquired and liabilities assumed based upon fair value on the date of acquisition, net of purchase price adjustments, is as follows (in thousands):
Consideration:
Cash	$	5,503
Fair value of common units granted (1)	11,621
Contingent consideration (2)	—
Total fair value of consideration	$	17,124
Fair value of assets acquired and liabilities assumed:
Proved oil and natural gas properties	$	17,306
Asset retirement obligations	(182		)
Total net assets	$	17,124
__________
-1	The fair value of the unit consideration was based upon 488,667 common units valued at $23.78 per unit (closing price on the date of the acquisition).
-2	The Partnership agreed to provide additional consideration to CEU if average daily production attributable to the acquired working interests exceeds a specified average daily production during a specified period (the "CEU Contingent Consideration"). See Note 3 "Contingent Consideration" for additional discussion of the CEU Contingent Consideration.
Consideration:
Cash	$	57,348
Fair value of common units granted (1)	33,106
Common units granted for the benefit of EFS/RPS employees (2)	724
Contingent consideration (3)	17,144
Total fair value of consideration	$	108,322
__________
-1	The fair value of the unit consideration was based upon 1,411,777 common units valued at $23.45 per unit (closing price on the date of the acquisition).
-2	The fair value of the unit consideration was based upon 30,867 common units valued at $23.45 per unit (closing price on the date of the transaction). These units were issued to satisfy the settlement of phantom units granted to EFS employees with no service requirement. An additional 401,171 common units were issued and are held in escrow to satisfy the future settlement of phantom units granted to EFS and RPS employees in conjunction with the Services Acquisition are excluded from consideration based on the future service requirement for vesting. See Note 9 "Equity" for additional discussion of phantom units.
-3	The former owners of EFS and RPS are entitled to receive additional consideration in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments ("EFS/RPS Contingent Consideration"). The EFS/RPS Contingent Consideration was valued at $17.1 million at the acquisition date through the use of a probability analysis. See Note 3 "Contingent Consideration" for additional discussion of the EFS/RPS Contingent Consideration.
Fair value of assets acquired and liabilities assumed:
Cash	$	1,522
Accounts receivable	3,365
Other current assets	954
Property and equipment	7,923
Intangible asset (1)	36,772
Goodwill (2)	23,974
Other assets	19
Total assets acquired	74,529
Accounts payable and accrued liabilities	(2,345		)
Factoring payable	(1,679		)
Long-term debt	(2,335		)
Total liabilities assumed	(6,359		)
Net assets acquired	$	68,170
__________
-1	Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years.
-2	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. Such goodwill is not 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. Goodwill has been allocated to the oilfield services segment.
Business Acquisition, Pro Forma Information	'
		Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
		(in thousands)
	Revenue	$	55,881		$	116,166
	Net income (1)	$	4,079		$	6,186
	Net income per common unit (1):
	Basic	$	0.24		$	0.37
	Diluted	$	0.24		$	0.37
	__________
	-1	Excludes $23.9 million of acquisition costs and transaction bonuses paid to EFS and RPS employees that were included in the historical results of the Partnership, EFS or RPS.
		Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
		(in thousands)
	Revenue	$	2,692		$	2,777
	Excess of revenues over direct operating expenses	$	1,286		$	1,333
		Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
		(in thousands)
	Revenue	$	3,054		$	4,937
	Operating income	$	1,077		$	2,196
		Three Months Ended June 30, 2013			Six Months Ended June 30, 2013
		(in thousands)
	Revenue	$	48,942		$	102,993
	Net income (loss) (1)	$	1,776		$	(3,628	)
	Net income (loss) per common unit (1):
	Basic	$	0.11		$	(0.41	)
	Diluted	$	0.11		$	(0.41	)
	__________
	(1)    Includes $1.4 million of the Partnership's acquisition costs related to the 2014 Material Acquisitions in the six months ended June 30, 2013.

Contingent_Consideration_Table

Contingent Consideration (Tables)	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Schedule of Business Acquisitions by Acquisition, Contingent Consideration	'
	A reconciliation of the beginning and ending balances of acquisition-related contingent consideration for the three and six months ended June 30, 2014 is as follows (in thousands):
		Three Months Ended June 30, 2014			Six Months Ended June 30, 2014
	Contingent consideration, beginning balance	$	6,753		$	6,320
	Acquisition date fair value of contingent consideration - CEU Acquisition	—			—
	Acquisition date fair value of contingent consideration - MCCS Acquisition	4,057			4,057
	Acquisition date fair value of contingent consideration - Services Acquisition	17,144			17,144
	Change in fair value of contingent consideration	(1,345		)	(912		)
	Payment of contingent consideration	—			—
	Contingent consideration, ending balance	$	26,609		$	26,609

Debt_Tables

Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of Debt	'
	The Partnership's debt consists of the following (in thousands):
		30-Jun-14		31-Dec-13
	Credit facility	$	85,000	$	78,500
	Notes payable	21,335		2,233
	Line of credit	3,209		—
	Total debt	109,544		80,733
	Less: current maturities of long-term debt	21,677		719
	Long-term debt	$	87,867	$	80,014

Derivative_Contracts_Tables

Derivative Contracts (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative [Line Items]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	The following table summarizes our derivative contracts on a gross basis, the effects of netting assets and liabilities for which the right of offset exists (in thousands):
	30-Jun-14		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset				Net Amounts Presented
	Assets:
	Commodity derivatives - current assets		$	18,154		$	(18,103	)		$	51
	Commodity derivatives - long-term assets		9,652			(9,353		)		299
	Total		$	27,806		$	(27,456	)		$	350
	Liabilities:
	Commodity derivatives - current liabilities		$	21,238		$	(18,103	)		$	3,135
	Commodity derivatives - long-term liabilities		10,098			(9,353		)		745
	Total		$	31,336		$	(27,456	)		$	3,880
	31-Dec-13		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset				Net Amounts Presented
	Assets:
	Commodity derivatives - current assets		$	1,342		$	(1,212	)		$	130
	Commodity derivatives - long-term assets		1,638			(978		)		660
	Total		$	2,980		$	(2,190	)		$	790
	Liabilities:
	Commodity derivatives - current liabilities		$	4,379		$	(1,212	)		$	3,167
	Commodity derivatives - long-term liabilities		1,015			(978		)		37
	Total		$	5,394		$	(2,190	)		$	3,204
	The following table sets forth by level within the fair value hierarchy the Partnership’s financial assets and liabilities that were measured at fair value on a recurring basis (in thousands):
	30-Jun-14		Fair Value Measurements
	Description		Active Markets for Identical Assets (Level 1)			Observable Inputs (Level 2)				Unobservable Inputs (Level 3)				Total Carrying Value
	Oil and natural gas collars		$	—		$	(671	)		$	—			$	(671	)
	Oil, natural gas and NGL put options		—			230				—				230
	Oil, natural gas and NGL fixed price swaps		—			(3,089		)		—				(3,089		)
	Total		$	—		$	(3,530	)		$	—			$	(3,530	)
	31-Dec-13		Fair Value Measurements
	Description		Active Markets for Identical Assets (Level 1)			Observable Inputs (Level 2)				Unobservable Inputs (Level 3)				Total Carrying Value
	Oil collars		$	—		$	(57	)		$	—			$	(57	)
	Natural gas collars		—			—				(9		)		(9		)
	Oil put options		—			28				—				28
	Natural gas and NGL put options		—			—				403				403
	Oil and natural gas fixed price swaps		—			132				—				132
	NGL fixed price swaps		—			—				(2,911		)		(2,911		)
	Total		$	—		$	103			$	(2,517	)		$	(2,414	)
	The following table sets forth a reconciliation of our derivative contracts measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,							Six Months Ended June 30,
		2014			2013				2014				2013
	Beginning balance	$	(2,843	)	$	(2,854	)		$	(2,517	)		$	(112	)
	Gains (losses)	—			4,812				(2,432		)		1,755
	Transfers out (1)	2,843			—				2,843				—
	Cash (paid) received upon settlement	—			(92		)		2,106				223
	Ending balance	$	—		$	1,866			$	—			$	1,866
	Unrealized gains included in earnings relating to derivatives held at period end	$	—		$	4,720			$	—			$	1,978
Schedule of Derivative Instruments	'
	At June 30, 2014, the Partnership's derivative contracts consisted of collars, put options, and fixed price swaps, as described below:
	Collars	The instrument contains a fixed floor price (long put option) and ceiling price (short call option), where the purchase price of the put option equals the sales price of the call option. At settlement, if the market price exceeds the ceiling price, the Partnership pays the difference between the market price and the ceiling price. If the market price is less than the fixed floor price, the Partnership receives the difference between the fixed floor price and the market price. If the market price is between the ceiling and the fixed floor price, no payments are due from either party.
	Put options	The Partnership periodically buys put options. At the time of settlement, if market prices are below the fixed price of the put option, the Partnership is entitled to the difference between the put option and the fixed price.
	Fixed price swaps	The Partnership receives a fixed price for the contract and pays a floating market price to the counterparty over a specified period for a contracted volume.
Derivative Instruments, Gain (Loss)	'
	The following table presents (loss) gain on our derivative contracts as included in the accompanying unaudited statements of operations for the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,							Six Months Ended June 30,
		2014			2013				2014				2013
	Total (loss) gain on derivative contracts, net (1)	$	(1,396	)	$	6,182			$	(4,528	)		$	856
Oil Collar	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	The following tables present our derivative instruments outstanding as of June 30, 2014:
	Oil collars		Volumes		Floor Price				Ceiling Price
			(Bbls)
	2014		46,788		$	80			$	103.5
	2015		42,649		$	80			$	93.25
Natural Gas Collars	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	Natural gas collars		Volumes		Floor Price				Ceiling Price
			(MMBtu)
	2014		676,776		$	4			$	4.41
	2015		1,362,382		$	4			$	4.32
Oil Options	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	Oil put options		Volumes (Bbls)		Floor Price
	2014		17,548		$	80
Natural Gas Options	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	Natural gas put options		Volumes		Floor Price
			(MMBtu)
	2014		237,434		$	3.5
	2015		799,853		$	3.5
	2016		930,468		$	3.5
Natural Gas Liquid Options	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	NGL put options		Volumes (Bbls)		Average Floor
					Price
	2014		17,506		$	56.53
Oil Swaps	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	Oil fixed price swaps		Volumes (Bbls)		Weighted Average Fixed Price
	2014		2,382		$	90.2
	2015		39,411		$	88.9
	2016		36,658		$	86
Natural Gas Swaps	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	Natural gas fixed price swaps		Volumes		Weighted Average Fixed Price
			(MMBtu)
	2014		461,571		$	4.09
	2015		800,573		$	4.25
	2016		629,301		$	4.37
Natural Gas Liquid Swaps	'
Derivative [Line Items]	'
Schedule of Derivative Instruments	'
	NGL fixed price swaps		Volumes		Weighted Average Fixed Price
			(Bbls)
	2014		341,868		$	54.96
	2015		84,793		$	75.18

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	'
	The following table summarizes our derivative contracts on a gross basis, the effects of netting assets and liabilities for which the right of offset exists (in thousands):
	30-Jun-14		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset				Net Amounts Presented
	Assets:
	Commodity derivatives - current assets		$	18,154		$	(18,103	)		$	51
	Commodity derivatives - long-term assets		9,652			(9,353		)		299
	Total		$	27,806		$	(27,456	)		$	350
	Liabilities:
	Commodity derivatives - current liabilities		$	21,238		$	(18,103	)		$	3,135
	Commodity derivatives - long-term liabilities		10,098			(9,353		)		745
	Total		$	31,336		$	(27,456	)		$	3,880
	31-Dec-13		Gross Amounts of Recognized Assets and Liabilities			Gross Amounts Offset				Net Amounts Presented
	Assets:
	Commodity derivatives - current assets		$	1,342		$	(1,212	)		$	130
	Commodity derivatives - long-term assets		1,638			(978		)		660
	Total		$	2,980		$	(2,190	)		$	790
	Liabilities:
	Commodity derivatives - current liabilities		$	4,379		$	(1,212	)		$	3,167
	Commodity derivatives - long-term liabilities		1,015			(978		)		37
	Total		$	5,394		$	(2,190	)		$	3,204
	The following table sets forth by level within the fair value hierarchy the Partnership’s financial assets and liabilities that were measured at fair value on a recurring basis (in thousands):
	30-Jun-14		Fair Value Measurements
	Description		Active Markets for Identical Assets (Level 1)			Observable Inputs (Level 2)				Unobservable Inputs (Level 3)				Total Carrying Value
	Oil and natural gas collars		$	—		$	(671	)		$	—			$	(671	)
	Oil, natural gas and NGL put options		—			230				—				230
	Oil, natural gas and NGL fixed price swaps		—			(3,089		)		—				(3,089		)
	Total		$	—		$	(3,530	)		$	—			$	(3,530	)
	31-Dec-13		Fair Value Measurements
	Description		Active Markets for Identical Assets (Level 1)			Observable Inputs (Level 2)				Unobservable Inputs (Level 3)				Total Carrying Value
	Oil collars		$	—		$	(57	)		$	—			$	(57	)
	Natural gas collars		—			—				(9		)		(9		)
	Oil put options		—			28				—				28
	Natural gas and NGL put options		—			—				403				403
	Oil and natural gas fixed price swaps		—			132				—				132
	NGL fixed price swaps		—			—				(2,911		)		(2,911		)
	Total		$	—		$	103			$	(2,517	)		$	(2,414	)
	The following table sets forth a reconciliation of our derivative contracts measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,							Six Months Ended June 30,
		2014			2013				2014				2013
	Beginning balance	$	(2,843	)	$	(2,854	)		$	(2,517	)		$	(112	)
	Gains (losses)	—			4,812				(2,432		)		1,755
	Transfers out (1)	2,843			—				2,843				—
	Cash (paid) received upon settlement	—			(92		)		2,106				223
	Ending balance	$	—		$	1,866			$	—			$	1,866
	Unrealized gains included in earnings relating to derivatives held at period end	$	—		$	4,720			$	—			$	1,978

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Tables)	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill	'
	A reconciliation of the aggregate carry amount of goodwill for the period from December 31, 2013 to June 30, 2014 is as follows (in thousands):
	Goodwill at December 31, 2013	$	23,974
	Additions:
	Services Acquisition	11,664
	MCCS Acquisition	4,060
	Goodwill at June 30, 2014	$	39,698
Schedule of Finite-Lived Intangible Assets	'
	The Partnership's intangible assets at June 30, 2014 and December 31, 2013 consist of the following (in thousands):
		30-Jun-14		31-Dec-13
	Customer relationships - MCE Acquisition	$	36,772	$	36,772
	Customer relationships - Services Acquisition	64,200		—
	Non-compete agreements - Services Acquisition	4,500		—
	Customer relationships - MCCS Acquisition	1,700		—
	Total intangible assets	107,172		36,772
	Less: accumulated amortization	7,946		1,763
	Intangible assets, net	$	99,226	$	35,009

Equity_Tables

Equity (Tables)	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Schedule of Distributions Made to Units	'
	The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common, subordinated and general partner units during the three and six months ended June 30, 2014 and 2013, as shown in the following table (in thousands):
	Distributions	Common Units			Subordinated Units			General Partner Units			Total
	2014
	First Quarter (1)	$	4,681		$	1,268		$	89		$	6,038
	Second Quarter (2)	$	7,852		$	1,279		$	90		$	9,221
	2013
	Second Quarter (3)	$	1,857		$	604		$	43		$	2,504
	__________
	(1)    Reflects quarterly distributions of $0.575 per unit paid in the first quarter of 2014.
	(2)    Reflects quarterly distributions of $0.58 per unit paid in the second quarter of 2014.
	(3)    Prorated to reflect 47 days of the quarterly cash distribution of $0.525 per unit paid in the second quarter of 2013.
	The following distributions will be paid on August 15, 2014 to holders of record as of the close of business on August 1, 2014 (in thousands):
			Common Units			Subordinated Units			General Partner Units			Total
	Distributions		$	9,025		$	1,290		$	91		$	10,406
	__________
	-1	Distributions were not paid on 13,116 common units issued in conjunction with grants to certain employees made in the second quarter of 2014.
Schedule of Target Distributions to Unitholders	'
	The following table illustrates the 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, as adjusted based on the MCCS Acquisition.
					Marginal Percentage Interest in
					Distributions
		Total Quarterly Distributions per MCE Unit			MCE Class A Unitholders (the Partnership)		MCE Class B Unitholders
	Minimum Quarterly Distribution	$16,116			100%		—%
	First Target Distribution	$18,533	to	$20,144	85%		15%
	Second Target Distribution	$20,145	to	$24,173	75%		25%
	Third Target Distribution and Thereafter	$24,174	and above		50%		50%

Earnings_per_Unit_Tables

Earnings per Unit - (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Schedule of Earnings Per Share, Basic and Diluted	'
	Basic and diluted earnings per unit for the three and six months ended June 30, 2014 and 2013 were computed as follows (in thousands, except per unit amounts):
		Three Months Ended June 30, 2014						Six Months Ended June 30, 2014
		Common Units		Subordinated Units		General Partner		Common Units		Subordinated Units			General Partner
	Net income	$	1,334	$	235	$	17	$	97	$	(40	)	$	(3	)
	Weighted average units outstanding	12,529		2,205		155		11,232		2,205			155
	Basic and diluted income (loss) per unit	$	0.11	$	0.11	$	0.11	$	0.01	$	(0.02	)	$	(0.02	)
		Three Months Ended June 30, 2013						Six Months Ended June 30, 2013
		Common Units		Subordinated Units		General Partner		Common Units		Subordinated Units			General Partner
	Net income (1)	$	6,045	$	1,968	$	138	$	1,397	$	49		$	5
	Weighted average units outstanding	6,774		2,205		155		6,285		2,205			154
	Basic and diluted income per unit	$	0.89	$	0.89	$	0.89	$	0.22	$	0.02		$	0.03
	__________
	-1	Reflects net income from February 13, 2013 through June 30, 2013 for the six months ended June 30, 2013.

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Schedule of Related Party Transactions	'
	Under agreements with New Dominion, the Partnership incurred charges as follows for the three and six months ended June 30, 2014 and 2013 (in thousands):
		Three Months Ended June 30,				Six Months Ended June 30,
		2014		2013		2014		2013
	Producing overhead charges	$	454	$	86	$	829	$	256
	Drilling and completion overhead charges	39		97		48		114
	Saltwater disposal fees	443		94		858		173
	Total expenses incurred	$	936	$	277	$	1,735	$	543

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Change in Asset Retirement Obligation	'
	A reconciliation of the aggregate carry amounts of the asset retirement obligations for the period from December 31, 2013 to June 30, 2014 is as follows (in thousands):
	Asset retirement obligation at December 31, 2013	$	3,455
	Liabilities incurred upon acquiring and drilling wells	222
	Revision of previous estimates	(33		)
	Accretion	143
	Asset retirement obligation at June 30, 2014	$	3,787

Business_Segment_Information_T

Business Segment Information (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Schedule of Segment Reporting Information, by Segment	'
	Summarized financial information concerning the Partnership’s segments is shown in the following tables (in thousands):
			Exploration and Production			Oilfield Services (1)			Total
	Three Months Ended June 30, 2014
	Revenues		$	16,718		$	10,100		$	26,818
	Direct operating expenses		5,308			5,968			11,276
	Segment margin		$	11,410		$	4,132		$	15,542
	General and administrative expenses		2,022			1,467			3,489
	Depreciation, depletion, amortization and accretion		6,970			3,393			10,363
	Income (loss) from operations		$	2,418		$	(728	)	$	1,690
	Capital expenditures (2)		$	7,709		$	2,177		$	9,886
	Three Months Ended June 30, 2013
	Revenues		$	10,649		$	—		$	10,649
	Direct operating expenses		3,313			—			3,313
	Segment margin		$	7,336		$	—		$	7,336
	General and administrative expenses		1,246			—			1,246
	Depreciation, depletion, amortization and accretion		3,634			—			3,634
	Income from operations		$	2,456		$	—		$	2,456
	Capital expenditures (2)		$	3,170		$	—		$	3,170
	__________
	-1	The Partnership's oilfield services segment was established with the MCE Acquisition that occurred in November 2013. See Note 2 "Acquisitions" for discussion.
	-2	On an accrual basis and exclusive of acquisitions.
			Exploration and Production			Oilfield Services (1)			Total
	Six Months Ended June 30, 2014
	Revenues		$	35,569		$	18,676		$	54,245
	Direct operating expenses		10,690			10,534			21,224
	Segment margin		$	24,879		$	8,142		$	33,021
	General and administrative expenses		5,866			3,184			9,050
	Depreciation, depletion, amortization and accretion		12,857			6,853			19,710
	Income (loss) from operations		$	6,156		$	(1,895	)	$	4,261
	Capital expenditures (2)		$	18,460		$	2,991		$	21,451
	At June 30, 2014
	Total assets		$	199,387		$	237,450		$	436,837
	Six Months Ended June 30, 2013
	Revenues		$	20,009		$	—		$	20,009
	Direct operating expenses		6,713			—			6,713
	Segment margin		$	13,296		$	—		$	13,296
	General and administrative expenses (3)		10,100			—			10,100
	Depreciation, depletion, amortization and accretion		6,858			—			6,858
	Loss from operations		$	(3,662	)	$	—		$	(3,662	)
	Capital expenditures (2)		$	3,516		$	—		$	3,516
	At December 31, 2013
	Total assets		$	181,440		$	73,270		$	254,710
	__________
	-1	The Partnership's oilfield services segment was established with the MCE Acquisition that occurred in November 2013. See Note 2 "Acquisitions" for discussion.
	-2	On an accrual basis and exclusive of acquisitions.
	-3	Includes $7.7 million of compensation expense related to common units granted to consultants, officers, directors and employees in conjunction with our initial public offering.

Subsequent_Events_Tables

Subsequent Events (Tables)	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Schedule of Distributions Made to Units	'
	The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common, subordinated and general partner units during the three and six months ended June 30, 2014 and 2013, as shown in the following table (in thousands):
	Distributions	Common Units			Subordinated Units			General Partner Units			Total
	2014
	First Quarter (1)	$	4,681		$	1,268		$	89		$	6,038
	Second Quarter (2)	$	7,852		$	1,279		$	90		$	9,221
	2013
	Second Quarter (3)	$	1,857		$	604		$	43		$	2,504
	__________
	(1)    Reflects quarterly distributions of $0.575 per unit paid in the first quarter of 2014.
	(2)    Reflects quarterly distributions of $0.58 per unit paid in the second quarter of 2014.
	(3)    Prorated to reflect 47 days of the quarterly cash distribution of $0.525 per unit paid in the second quarter of 2013.
	The following distributions will be paid on August 15, 2014 to holders of record as of the close of business on August 1, 2014 (in thousands):
			Common Units			Subordinated Units			General Partner Units			Total
	Distributions		$	9,025		$	1,290		$	91		$	10,406
	__________
	-1	Distributions were not paid on 13,116 common units issued in conjunction with grants to certain employees made in the second quarter of 2014.

Acquisitions_Details

Acquisitions (Details) (USD $)

3 Months Ended

6 Months Ended

0 Months Ended

1 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

0 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Mar. 31, 2014

Dec. 31, 2013

Nov. 12, 2013

Nov. 30, 2013

Mar. 31, 2013

31-May-13

Jun. 30, 2013

Jun. 30, 2013

Jul. 31, 2013

Jul. 31, 2013

Oct. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Oct. 04, 2013

Nov. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Nov. 12, 2013

Nov. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Nov. 30, 2013

Nov. 30, 2013

Jan. 31, 2014

Jun. 30, 2014

Jun. 26, 2014

Jun. 30, 2014

Jun. 26, 2014

Jun. 30, 2014

Jun. 26, 2014

Jun. 26, 2014

Jun. 26, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 26, 2014

Jun. 26, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 26, 2014

Chief Executive Officer

Chief Executive Officer

March Acquired Properties

May Acquired Properties

March and May Acquisitions

March and May Acquisitions

July Acquired Properties

Orion Acquisition

Southern Dome

Southern Dome

Southern Dome

Southern Dome

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

CEU Paradigm

CEU Paradigm

MCCS

MCCS

MCCS

MCCS

EFS

RPS

EFS and RPS

EFS and RPS

EFS and RPS

EFS and RPS

EFS and RPS

2014 Acquisitions

2014 Acquisitions

CEU Paradigm and 2014 Acquisitions

Common Units

Phantom Units

MidCentral Energy Services

MidCentral Energy Services

producing_well

Customer Relationships

Customer Relationships

Customer Relationships

MCE Owners

Select MCE Employees

producing_well

Chief Executive Officer

Customer Relationships

Customer Relationships

Customer Relationships

Noncompete Agreements

Common Units

EFS and RPS

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of common units in acquisitions (in units)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

488,667

'

33,646

'

'

'

'

'

1,411,777

'

'

'

'

'

'

'

1,964,957

'

Total net assets

'

'

'

'

'

'

'

'

$27,982,000

$7,892,000

'

'

$4,866,000

$3,230,000

$14,468,000

'

'

'

$68,170,000

'

'

'

'

'

'

'

'

$17,124,000

'

$6,355,000

'

'

'

'

'

$108,322,000

'

'

'

'

'

'

'

'

'

Units issued in acquisition

'

'

'

'

'

'

'

'

1,378,500

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,847,265

99,768

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

432,038

Value of units issued in acquisition (in usd per unit)

'

'

'

'

'

'

'

'

$20.30

'

'

'

'

'

$20.79

'

'

'

'

'

'

'

'

'

'

$22.64

'

$23.78

'

$23.45

'

'

'

'

'

$23.45

'

'

'

'

'

'

'

'

'

Units measured at fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

401,171

Total fair value of consideration

'

'

'

'

'

'

'

'

'

7,900,000

'

'

'

'

14,468,000

'

'

'

68,170,000

'

'

'

'

'

'

'

'

17,124,000

'

6,355,000

'

'

'

'

108,300,000

108,322,000

'

'

'

'

'

'

'

'

'

Acquisition expense

'

'

'

'

'

'

'

'

'

'

500,000

500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

1,300,000

'

'

'

Percentage of working interest acquired

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of wells Company in which company has acquired working interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25

'

'

'

'

'

'

'

'

'

'

'

'

23

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common partnership units issued in acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

414,045

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30,867

'

'

'

'

'

'

'

'

'

'

'

Maximum cap on additional partnership units to be issued to former owners of MCE if conditions are met

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

120,000,000

120,000,000

'

'

'

'

'

'

'

'

'

'

4,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contingent consideration

26,609,000

'

26,609,000

'

6,753,000

6,320,000

'

'

'

'

'

'

'

'

'

0

0

1,600,000

6,320,000

[1]

5,400,000

6,300,000

6,320,000

'

'

'

'

'

0

0

4,057,000

[2]

'

'

'

'

'

17,144,000

[3]

'

'

'

'

'

'

'

'

'

Class B units issued in MCE acquisition

15,497,000

'

15,497,000

'

'

13,988,000

'

'

'

'

'

'

'

'

'

'

'

'

13,988,000

[4]

'

'

'

'

'

'

'

'

'

'

1,509,000

[5]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Useful life of finite-lived intangible asset

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'7 years

'

'

'

'

'

'

'

'

'

'7 years

'

'

'

'

'7 years

'

'

'

'

'

'

'

Amortization expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,100,000

6,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity interest percentage owned

'

'

'

'

'

'

'

36.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity method carrying basis in acquisition

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on investment in acquired business

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity interest percentage acquired in acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

100.00%

100.00%

'

'

'

'

'

'

'

'

'

'

Ownership percentage of acquired entity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on acquisition of business

2,298,000

0

2,298,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Intangible assets acquired in acquisition

'

'

'

'

'

'

'

'

754,000

'

'

'

'

'

'

'

'

'

19,000

'

'

'

'

'

'

'

'

'

'

28,000

'

'

'

'

'

68,700,000

[6]

'

'

64,200,000

4,500,000

'

'

'

'

'

Acquisition costs and transaction bonuses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$23,900,000

'

'

'

'

'

$1,400,000

'

'

[1]

The owners of MCE are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCES for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $120.0 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCE Contingent Consideration.

[2]

The owners of MCCS are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $4.5 million cap ("MCCS Contingent Consideration"). The MCCS Contingent Consideration was valued at $4.1 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCCS Contingent Consideration.

[3]

The former owners of EFS and RPS are entitled to receive additional consideration in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments ("EFS/RPS Contingent Consideration"). The EFS/RPS Contingent Consideration was valued at $17.1 million at the acquisition date through the use of a probability analysis. See Note 3 "Contingent Consideration" for additional discussion of the EFS/RPS Contingent Consideration.

[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 9 "Equity" for additional discussion of these incentive distributions. The Class B units were valued at $14.0 million at the acquisition date through the use of a Monte Carlo simulation.

[5]

As a condition of the acquisition agreement, MCCS was contributed to MCE by the Partnership, which increased the value of the noncontrolling interest held by MCE's Class B unitholders. The increase in the value of the noncontrolling interest that resulted from this is part of the total consideration paid for the MCCS Acquisition and was valued at the acquisition date through the use of a Monte Carlo simulation.

[6]

Identifiable intangible assets include $64.2 million for customer relationships and $4.5 million for non-compete agreements. Customer relationships were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years. Non-compete agreements were valued based on an income approach and are amortized over the agreement period.

Acquisitions_Purchase_Price_Al

Acquisitions - Purchase Price Allocation for March Acquisitions (Details) (March Acquired Properties, USD $)	Mar. 31, 2013
In Thousands, unless otherwise specified
March Acquired Properties	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$29,049
Other assets	754
Asset retirement obligations	-1,333
Other liabilities	-488
Total net assets	$27,982

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
Asset retirement obligations	-19
Other liabilities	-254
Total net assets	$7,892

Acquisitions_Amounts_of_Revenu

Acquisitions - Amounts of Revenues and Revenues in Excess of Direct Operating Expenses Included in Statement of Operations (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Business Acquisition [Line Items]	'	'	'	'
Revenue	$26,818	$10,649	$54,245	$20,009
Excess of revenues over direct operating expenses	15,542	7,336	33,021	13,296
Income (loss) from operations	1,690	2,456	4,261	-3,662
March and May Acquisitions	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenue	'	2,692	'	2,777
Excess of revenues over direct operating expenses	'	1,286	'	1,333
2014 Acquisitions	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenue	3,054	'	4,937	'
Income (loss) from operations	$1,077	'	$2,196	'

Acquisitions_Purchase_Price_Al2

Acquisitions - Purchase Price Allocation for July Acquisitions (Details) (July Acquired Properties, USD $)	Jul. 31, 2013
In Thousands, unless otherwise specified
July Acquired Properties	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$4,888
Asset retirement obligations	-4
Other liabilities	-18
Total net assets	$4,866

Acquisitions_Acquisitions_Purc

Acquisitions Acquisitions - Purchase Price Allocation for Orion Acquisition (Details) (Orion Acquisition, USD $)	Jul. 31, 2013
In Thousands, unless otherwise specified
Orion Acquisition	'
Business Acquisition [Line Items]	'
Proved oil and natural gas properties	$3,274
Asset retirement obligations	-24
Other liabilities	-20
Total net assets	$3,230

Acquisitions_Purchase_Price_Al3

Acquisitions - Purchase Price Allocation for Southern Dome Acquisition (Details) (Southern Dome, USD $)	1 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2013
Southern Dome	'
Consideration:	'
Cash	$4,260
Fair value of common units granted	8,608	[1]
Contingent consideration	1,600	[2]
Total fair value of consideration	14,468
Fair value of assets acquired and liabilities assumed:	'
Proved oil and natural gas properties	15,190
Asset retirement obligations	-170
Other liabilities	-552
Total net assets	$14,468
[1]	The fair value of the unit consideration was based upon 414,045 common units valued at $20.79 per unit (closing price on the date of the acquisition).
[2]	The Partnership agreed to provide additional consideration to Scintilla if average daily production attributable to the acquired working interests exceeds a specified average daily production during the specified period (the "Southern Dome Contingent Consideration"). See Note 3 "Contingent Consideration" for additional discussion of the Southern Dome Contingent Consideratio

Acquisitions_Purchase_Price_Al4

Acquisitions - Purchase Price Allocation for MCE Acquisition (Details) (USD $)

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Nov. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Nov. 12, 2013

Nov. 30, 2013

Nov. 30, 2013

MidCentral Energy Services

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

'

'

'

$3,781,000

'

'

'

'

'

Fair value of units granted

'

'

'

'

'

'

'

41,822,000

[1]

2,259,000

[2]

Contingent consideration

26,609,000

6,753,000

6,320,000

6,320,000

[3]

5,400,000

6,300,000

6,320,000

'

'

Class B units issued in MCE acquisition

15,497,000

'

13,988,000

13,988,000

[4]

'

'

'

'

'

Total fair value of consideration

'

'

'

$68,170,000

'

'

'

'

'

[1]

The fair value of the unit consideration was based upon 1,847,265 common units valued at $22.64 per unit (closing price on the date of the acquisition).

[2]

The fair value of the unit consideration was based upon 99,768 common units valued at $22.64 per unit (closing price on the date of the acquisition). These common units were issued to certain employees of MCE under the Partnershipbs long-term incentive plan, primarily for service prior to the acquisition. Any forfeited common units do not revert to the Partnership, but would be distributed to the former owners of MCE.

[3]

The owners of MCE are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCES for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $120.0 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCE Contingent Consideration.

[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 9 "Equity" for additional discussion of these incentive distributions. The Class B units were valued at $14.0 million at the acquisition date through the use of a Monte Carlo simulation.

Acquisitions_Summary_of_Assets

Acquisitions - Summary of Assets Acquired and Liabilities Assumed in MCE Acquisition (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Nov. 30, 2013		Nov. 30, 2013
In Thousands, unless otherwise specified			MidCentral Energy Services		Customer Relationships
					MidCentral Energy Services
Business Acquisition [Line Items]	'	'	'		'
Cash	'	'	$1,522		'
Accounts receivable	'	'	3,365		'
Other current assets	'	'	954		'
Property and equipment	'	'	7,923		'
Intangible Asset	'	'	'		36,772	[1]
Goodwill	39,698	23,974	23,974	[2]	'
Other assets	'	'	19		'
Fair value of assets acquired	'	'	74,529		'
Accounts payable and accrued liabilities	'	'	-2,345		'
Factoring payable	'	'	-1,679		'
Long-term debt	'	'	-2,335		'
Total liabilities assumed	'	'	-6,359		'
Total net assets	'	'	$68,170		'
[1]	Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years.
[2]	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. Such goodwill is not 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. Goodwill has been allocated to the oilfield services segment.

Acquisitions_Purchase_Price_Al5

Acquisitions - Purchase Price Allocation of CEU Acquisition (Details) (CEU Paradigm, USD $)	0 Months Ended
In Thousands, unless otherwise specified	Jan. 31, 2014
CEU Paradigm	'
Business Acquisition [Line Items]	'
Cash	$5,503
Fair value of common units granted	11,621	[1]
Contingent consideration	0	[2]
Total fair value of consideration	17,124
Property and equipment	17,306
Asset retirement obligations	-182
Total net assets	$17,124
[1]	The fair value of the unit consideration was based upon 488,667 common units valued at $23.78 per unit (closing price on the date of the acquisition).
[2]	The Partnership agreed to provide additional consideration to CEU if average daily production attributable to the acquired working interests exceeds a specified average daily production during a specified period (the "CEU Contingent Consideration"). See Note 3 "Contingent Consideration" for additional discussion of the CEU Contingent Consideration.

Acquisitions_Purchase_Price_Al6

Acquisitions - Purchase Price Allocation for MCCS Acquisition (Details) (USD $)	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 26, 2014
				MCCS
Business Acquisition [Line Items]	'	'	'	'
Fair value of common units granted	'	'	'	$789,000	[1]
Contingent consideration	26,609,000	6,753,000	6,320,000	4,057,000	[2]
Noncontrolling interest	15,497,000	'	13,988,000	1,509,000	[3]
Total fair value of consideration	'	'	'	$6,355,000
[1]	The fair value of the unit consideration was based upon 33,646 common units valued at $23.45 per unit (closing price on the date of the acquisition).
[2]	The owners of MCCS are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $4.5 million cap ("MCCS Contingent Consideration"). The MCCS Contingent Consideration was valued at $4.1 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCCS Contingent Consideration.
[3]	As a condition of the acquisition agreement, MCCS was contributed to MCE by the Partnership, which increased the value of the noncontrolling interest held by MCE's Class B unitholders. The increase in the value of the noncontrolling interest that resulted from this is part of the total consideration paid for the MCCS Acquisition and was valued at the acquisition date through the use of a Monte Carlo simulation.

Acquisitions_Summary_of_Assets1

Acquisitions - Summary of Assets Acquired and Liabilities Assumed in MCCS Acquisition (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 26, 2014
In Thousands, unless otherwise specified			MCCS
Business Acquisition [Line Items]	'	'	'
Cash	'	'	$109
Accounts receivable	'	'	524
Inventory	'	'	2,035
Other current assets	'	'	14
Property and equipment	'	'	107
Intangible asset	107,172	36,772	1,700	[1]
Goodwill	39,698	23,974	4,060	[2]
Other assets	'	'	28
Fair value of assets acquired	'	'	8,577
Accounts payable and accrued liabilities	'	'	-1,431
Long-term debt	'	'	-791
Total liabilities assumed	'	'	-2,222
Total net assets	'	'	$6,355
[1]	Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and
[2]	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the acquisition of MCCS includes any intangible assets that do not qualify for separate recognition, such as the MCCS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships and integrating new product offerings into MCCS's business. Goodwill has been allocated to the oilfield services segment.

Acquisitions_Purchase_Price_Al7

Acquisitions - Purchase Price Allocation of EFS and RPS Acquisition (Details) (USD $)	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 26, 2014		Jun. 26, 2014
				EFS and RPS		EFS and RPS Employees
						EFS and RPS
Business Acquisition [Line Items]	'	'	'	'		'
Cash	'	'	'	$57,348,000		'
Fair value of common units granted	'	'	'	33,106,000	[1]	'
Common units granted for the benefit of EFS and RPS employees	'	'	'	'		724,000	[2]
Contingent consideration	26,609,000	6,753,000	6,320,000	17,144,000	[3]	'
Total fair value of consideration	'	'	'	$108,322,000		'
[1]	The fair value of the unit consideration was based upon 1,411,777 common units valued at $23.45 per unit (closing price on the date of the acquisition).
[2]	The fair value of the unit consideration was based upon 30,867 common units valued at $23.45 per unit (closing price on the date of the transaction). These units were issued to satisfy the settlement of phantom units granted to EFS employees with no service requirement. An additional 401,171 common units were issued and are held in escrow to satisfy the future settlement of phantom units granted to EFS and RPS employees in conjunction with the Services Acquisition are excluded from consideration based on the future service requirement for vesting. See Note 9 "Equity" for additional discussion of phantom units
[3]	The former owners of EFS and RPS are entitled to receive additional consideration in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments ("EFS/RPS Contingent Consideration"). The EFS/RPS Contingent Consideration was valued at $17.1 million at the acquisition date through the use of a probability analysis. See Note 3 "Contingent Consideration" for additional discussion of the EFS/RPS Contingent Consideration.

Acquisitions_Summary_of_Assets2

Acquisitions - Summary of Assets Acquired and Liabilities Assumed in EFS and RPS Acquisition (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 26, 2014		Jun. 26, 2014	Jun. 26, 2014
In Thousands, unless otherwise specified			EFS and RPS		Customer Relationships	Noncompete Agreements
					EFS and RPS	EFS and RPS
Business Acquisition [Line Items]	'	'	'		'	'
Cash	'	'	$1,668		'	'
Accounts receivable	'	'	21,611		'	'
Other current assets	'	'	247		'	'
Property and equipment	'	'	43,151		'	'
Goodwill	39,698	23,974	11,665	[1]	'	'
Other assets	'	'	68,700	[2]	64,200	4,500
Fair value of assets acquired	'	'	147,042		'	'
Accounts payable and accrued liabilities	'	'	-6,080		'	'
Factoring payable	'	'	-15,840		'	'
Long-term debt	'	'	-16,800		'	'
Total liabilities assumed	'	'	-38,720		'	'
Total net assets	'	'	$108,322		'	'
[1]	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the Services Acquisition includes any intangible assets that do not qualify for separate recognition, such as the EFS and RPS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships. Goodwill has been allocated to the oilfield services segment.
[2]	Identifiable intangible assets include $64.2 million for customer relationships and $4.5 million for non-compete agreements. Customer relationships were valued based on the estimated free cash flows the customer relationships are expected to provide and are amortized using an accelerated method over seven years. Non-compete agreements were valued based on an income approach and are amortized over the agreement period.

Acquisitions_Pro_Forma_Results

Acquisitions - Pro Forma Results of Operations (Details) (CEU Paradigm and 2014 Acquisitions, USD $)	3 Months Ended			6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013
CEU Paradigm and 2014 Acquisitions	'		'	'		'
Business Acquisition [Line Items]	'		'	'		'
Revenue	$55,881		$48,942	$116,166		$102,993
Net income	$4,079	[1]	$1,776	$6,186	[1]	($3,628)
Net income per common unit (1):	'		'	'		'
Basic (in usd per unit)	$0.24	[1]	$0.11	$0.37	[1]	($0.41)
Diluted (in usd per unit)	$0.24	[1]	$0.11	$0.37	[1]	($0.41)
[1]	Excludes $23.9 million of acquisition costs and transaction bonuses paid to EFS and RPS employees that were included in the historical results of the Partnership, EFS or RPS.

Contingent_Consideration_Recon

Contingent Consideration - Reconciliation of Acquisition Related Accrued Earnouts (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jan. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 26, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 26, 2014

CEU Paradigm

CEU Paradigm

CEU Paradigm

MCCS

MCCS

MCCS

EFS and RPS

EFS and RPS

EFS and RPS

Business Acquisition, Contingent Consideration [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Contingent consideration, beginning balance

$6,753,000

$6,320,000

'

'

'

$0

'

'

$4,057,000

[1]

'

'

$17,144,000

[2]

Acquisition date fair value of contingent consideration

'

-912,000

0

0

0

'

4,057,000

4,057,000

'

17,144,000

17,144,000

'

Change in fair value of contingent consideration

-1,345,000

-912,000

'

'

'

'

'

'

'

'

'

'

Payment of contingent consideration

0

0

'

'

'

'

'

'

'

'

'

'

Contingent consideration, ending balance

$26,609,000

$26,609,000

'

$0

$0

$0

'

'

$4,057,000

[1]

'

'

$17,144,000

[2]

[1]

The owners of MCCS are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $4.5 million cap ("MCCS Contingent Consideration"). The MCCS Contingent Consideration was valued at $4.1 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCCS Contingent Consideration.

[2]

The former owners of EFS and RPS are entitled to receive additional consideration in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments ("EFS/RPS Contingent Consideration"). The EFS/RPS Contingent Consideration was valued at $17.1 million at the acquisition date through the use of a probability analysis. See Note 3 "Contingent Consideration" for additional discussion of the EFS/RPS Contingent Consideration.

Contingent_Consideration_Detai

Contingent Consideration (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Nov. 30, 2013

Nov. 12, 2013

Jun. 30, 2014

Dec. 31, 2013

Oct. 04, 2013

Jun. 30, 2014

Jan. 31, 2014

Jun. 26, 2014

Jun. 30, 2014

Jun. 26, 2014

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

MidCentral Energy Services

Southern Dome

Southern Dome

Southern Dome

CEU Paradigm

CEU Paradigm

EFS and RPS

MCCS

MCCS

Boe

Boe

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Average daily production needed to provide additional consideration for acquisition

'

'

'

'

'

'

'

'

'

383.5

'

'

566

'

'

'

'

Contingent consideration

$26,609,000

$26,609,000

$6,753,000

$6,320,000

$5,400,000

$5,400,000

$6,300,000

$6,320,000

[1]

$6,320,000

$0

$0

$1,600,000

$0

$0

$17,144,000

[2]

'

$4,057,000

[3]

Maximum cap on additional partnership units to be issued to former owners of MCE if conditions are met

'

'

'

'

120,000,000

120,000,000

'

120,000,000

'

'

'

'

'

'

'

4,500,000

'

Change in fair value of contingent consideration

($1,345,000)

($912,000)

'

'

($1,300,000)

($900,000)

'

'

'

'

'

'

'

'

'

'

'

[1]

The owners of MCE are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCES for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $120.0 million cap ("MCE Contingent Consideration"). The MCE Contingent Consideration was valued at $6.3 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCE Contingent Consideration.

[2]

The former owners of EFS and RPS are entitled to receive additional consideration in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of EFS and RPS for the year ending December 31, 2014, less certain adjustments ("EFS/RPS Contingent Consideration"). The EFS/RPS Contingent Consideration was valued at $17.1 million at the acquisition date through the use of a probability analysis. See Note 3 "Contingent Consideration" for additional discussion of the EFS/RPS Contingent Consideration.

[3]

The owners of MCCS are entitled to receive additional common units in the second quarter of 2015 based on a specified multiple of the annualized EBITDA of MCCS for the trailing nine month period ending March 31, 2015, less certain adjustments, subject to a $4.5 million cap ("MCCS Contingent Consideration"). The MCCS Contingent Consideration was valued at $4.1 million at the acquisition date through the use of a Monte Carlo simulation. See Note 3 "Contingent Consideration" for additional discussion of the MCCS Contingent Consideration.

Debt_Schedule_of_Debt_Details

Debt - Schedule of Debt (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Line of Credit Facility [Line Items]	'	'
Outstanding Credit	$85,000	$78,500
Notes payable	21,335	2,233
Total debt	109,544	80,733
Less: current maturities of long-term debt	21,677	719
Long-term debt	87,867	80,014
Revolving Credit Facility	'	'
Line of Credit Facility [Line Items]	'	'
Outstanding Credit	$3,209	$0

Debt_Details

Debt (Details) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Feb. 28, 2014

Jun. 30, 2014

Jun. 30, 2014

Notes Payable to Banks

Term Loans

Minimum

Minimum

Maximum

Federal Funds Rate

Base Rate

Base Rate

Base Rate

Base Rate

Base Rate

London Interbank Offered Rate (LIBOR)

London Interbank Offered Rate (LIBOR)

London Interbank Offered Rate (LIBOR)

Revolving Credit Facility

Revolving Credit Facility

Revolving Credit Facility

MidCentral Energy Services

MidCentral Energy Services

EFS and RPS

EFS and RPS

Notes Payable to Banks

Term Loans

Notes Payable to Banks

Term Loans

Term Loans

Minimum

Minimum

Maximum

Minimum

Maximum

Bank of Oklahoma Corporation National Prime Rate

Revolving Credit Facility

Revolving Credit Facility

Minimum

Maximum

Term Loans

Term Loans

Term Loans

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required ratio of EBITDA to interest expense

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required ratio of total debt to EBITDA

'

'

3.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required current ratio

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing base utilization permitted under credit facility

'

'

90.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis spread on debt instruments

'

'

'

'

'

'

'

'

'

'

0.50%

'

-2.30%

1.50%

'

2.25%

1.00%

2.50%

3.25%

'

'

'

'

'

'

'

Commitment fee percentage

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Average annual interest rate during period

3.27%

3.29%

3.30%

3.29%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of credit current borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$102,500,000

'

'

'

$4,000,000

'

'

Line of credit remaining borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,500,000

'

'

800,000

'

'

'

Available borrowing capacity before distribution restrictions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,300,000

'

'

'

'

'

'

Long-term Debt

'

'

'

'

'

4,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Durations of debt instruments

'

'

'

'

'

'

'

'36 months

'

'60 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated rates on debt instruments

'

'

'

'

'

'

'

5.50%

'

10.51%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Term loans balance

'

'

'

'

'

'

16,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stated rate on term loans

'

'

'

'

'

'

'

'

'

'

'

5.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rates on debt instruments

3.19%

'

3.19%

'

3.25%

'

'

'

'

'

'

'

'

'

5.50%

'

'

'

'

'

'

4.00%

'

'

'

'

Minimum balance required to be maintained on reserve bank account

'

'

'

'

'

'

'

'

300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of excess cash flow to be maintained as balance of reserve account if greater than $0.3 million

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted cash

975,000

'

975,000

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Required fixed-charge ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.25

'

Required leverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.5

Required working capital and cash balance

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

Line of credit maximum borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,000,000

'

'

Outstanding balance of line of credit

$85,000,000

'

$85,000,000

'

$78,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$3,209,000

$0

'

'

'

'

'

Required debt service coverage ratio

'

'

1.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Factoring_Payable_Details

Factoring Payable (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Debt Disclosure [Abstract]	'	'
Factoring payable	$16,164	$1,907
Percentage of funding from factoring payable received upfront	90.00%	'
Percentage of balance of payables factored that is reserved	10.00%	'
Interest margin on factoring payables	5.00%	'
Days till outstanding factored payable are repurchased	'90 days	'

Derivative_Contracts_Details_C

Derivative Contracts (Details) - Commodity Derivative Positions Oil Collars (Oil Collar)	6 Months Ended
	Jun. 30, 2014
	bbl
2014	'
Derivative [Line Items]	'
Volumes (Bbls)	46,788
Floor Price (in usd per Bbl)	80
Ceiling Price (in usd per Bbl)	103.5
2015	'
Derivative [Line Items]	'
Volumes (Bbls)	42,649
Floor Price (in usd per Bbl)	80
Ceiling Price (in usd per Bbl)	93.25

Derivative_Contracts_Details_C1

Derivative Contracts (Details) - Commodity Derivative Positions Natural Gas Collars (Natural Gas Collars)	6 Months Ended
	Jun. 30, 2014
	MMBTU
2014	'
Derivative [Line Items]	'
Volumes (MMBtu)	676,776
Floor Price (in usd per MMBtu)	4
Ceiling Price (in usd per MMBtu)	4.41
2015	'
Derivative [Line Items]	'
Volumes (MMBtu)	1,362,382
Floor Price (in usd per MMBtu)	4
Ceiling Price (in usd per MMBtu)	4.32

Derivative_Contracts_Details_C2

Derivative Contracts (Details) - Commodity Derivative Positions Oil Options (Oil Options, 2014)	6 Months Ended
	Jun. 30, 2014
	bbl
Oil Options | 2014	'
Derivative [Line Items]	'
Volumes (Bbls)	17,548
Floor Price (in usd per Bbl)	80

Derivative_Contracts_Details_C3

Derivative Contracts (Details) - Commodity Derivative Positions Natural Gas Options (Natural Gas Options)	6 Months Ended
	Jun. 30, 2014
	MMBTU
2014	'
Derivative [Line Items]	'
Volumes (MMBtu)	237,434
Floor Price (in usd per MMBtu)	3.5
2015	'
Derivative [Line Items]	'
Volumes (MMBtu)	799,853
Floor Price (in usd per MMBtu)	3.5
2016	'
Derivative [Line Items]	'
Volumes (MMBtu)	930,468
Floor Price (in usd per MMBtu)	3.5

Derivative_Contracts_Details_C4

Derivative Contracts (Details) - Commodity Derivative Positions Natural Gas Liquid Options (Natural Gas Liquid Options, 2014)	6 Months Ended
	Jun. 30, 2014
	bbl
Natural Gas Liquid Options | 2014	'
Derivative [Line Items]	'
Volumes (Bbls)	17,506
Average Floor Price (in usd per Bbl)	56.53

Derivative_Contracts_Details_C5

Derivative Contracts (Details) - Commodity Derivative Positions Oil Swaps (Oil Swaps)	6 Months Ended
	Jun. 30, 2014
	bbl
2014	'
Derivative [Line Items]	'
Volumes (Bbls)	2,382
Fixed Price (in usd per Bbl)	90.2
2015	'
Derivative [Line Items]	'
Volumes (Bbls)	39,411
Fixed Price (in usd per Bbl)	88.9
2016	'
Derivative [Line Items]	'
Volumes (Bbls)	36,658
Fixed Price (in usd per Bbl)	86

Derivative_Contracts_Details_C6

Derivative Contracts (Details) - Commodity Derivative Positions Natural Gas Swaps (Natural Gas Swaps)	6 Months Ended
	Jun. 30, 2014
	MMBTU
2014	'
Derivative [Line Items]	'
Volumes (MMBtu)	461,571
Weighted Average Fixed Price	4.09
2015	'
Derivative [Line Items]	'
Volumes (MMBtu)	800,573
Weighted Average Fixed Price	4.25
2016	'
Derivative [Line Items]	'
Volumes (MMBtu)	629,301
Weighted Average Fixed Price	4.37

Derivative_Contracts_Details_C7

Derivative Contracts (Details) - Commodity Derivative Positions Liquid Swaps (Natural Gas Liquid Swaps)	6 Months Ended
	Jun. 30, 2014
	bbl
2014	'
Derivative [Line Items]	'
Volumes (Bbls)	341,868
Weighted Average Fixed Price	54.96
2015	'
Derivative [Line Items]	'
Volumes (Bbls)	84,793
Weighted Average Fixed Price	75.18

Derivative_Contracts_Details_O

Derivative Contracts (Details) - Offsetting Commodity Derivative Assets and Liabilities (Commodity, USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]	'	'
Gross amounts of recognized assets	$27,806	$2,980
Gross Amounts Offset	-27,456	-2,190
Net Amounts Presented	350	790
Gross amounts of recognized liabilities	31,336	5,394
Gross Amounts Offset	-27,456	-2,190
Net Amounts Presented	3,880	3,204
Current Assets	'	'
Derivative [Line Items]	'	'
Gross amounts of recognized assets	18,154	1,342
Gross Amounts Offset	-18,103	-1,212
Net Amounts Presented	51	130
Long-term Assets	'	'
Derivative [Line Items]	'	'
Gross amounts of recognized assets	9,652	1,638
Gross Amounts Offset	-9,353	-978
Net Amounts Presented	299	660
Current Liabilities	'	'
Derivative [Line Items]	'	'
Gross amounts of recognized liabilities	21,238	4,379
Gross Amounts Offset	-18,103	-1,212
Net Amounts Presented	3,135	3,167
Long-term Liabilities	'	'
Derivative [Line Items]	'	'
Gross amounts of recognized liabilities	10,098	1,015
Gross Amounts Offset	-9,353	-978
Net Amounts Presented	$745	$37

Derivative_Contracts_Details_G

Derivative Contracts (Details) - Gains (Losses) on Derivative Contracts (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'		'		'		'
(Loss) gain on derivative contracts, net	($1,396)	[1]	$6,182	[1]	($4,528)	[1]	$856	[1]
[1]	Included in (loss) gain on derivative contracts for the three months ended June 30, 2014 and 2013 are net cash payments upon contract settlement of $1.0 million and $0.1 million, respectively. Included in (loss) gain on derivative contracts for the six months ended June 30, 2014 and 2013 are net cash payments upon contract settlement of $3.4 million and $0.3 million, respectively.

Derivative_Contracts_Details

Derivative Contracts (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'	'
Cash paid on settlement of derivative contracts	($983)	($100)	($3,412)	($341)

Fair_Value_Measurements_Deriva

Fair Value Measurements - Derivative Assets and Obligations Measured at Fair Value (Details) (USD $)	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	($3,530)	'	($2,414)	'	'	'
Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	0	'	'	'
Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	-3,530	'	103	'	'	'
Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	-2,843	-2,517	1,866	-2,854	-112
Oil Collar	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	-57	'	'	'
Oil Collar | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Oil Collar | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	-57	'	'	'
Oil Collar | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Natural Gas Collars	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	-9	'	'	'
Natural Gas Collars | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Natural Gas Collars | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Natural Gas Collars | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	-9	'	'	'
Oil Put Options	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	28	'	'	'
Oil Put Options | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Oil Put Options | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	28	'	'	'
Oil Put Options | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Natural Gas and NGL Puts	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	230	'	403	'	'	'
Natural Gas and NGL Puts | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	0	'	'	'
Natural Gas and NGL Puts | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	230	'	0	'	'	'
Natural Gas and NGL Puts | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	403	'	'	'
Oil And Natural Gas Collars	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	-671	'	'	'	'	'
Oil And Natural Gas Collars | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	'	'	'	'
Oil And Natural Gas Collars | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	-671	'	'	'	'	'
Oil And Natural Gas Collars | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	'	'	'	'
Oil and Natural Gas Swaps	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	132	'	'	'
Oil and Natural Gas Swaps | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Oil and Natural Gas Swaps | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	132	'	'	'
Oil and Natural Gas Swaps | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
Oil, Natural Gas and NGL Swaps	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	-3,089	'	'	'	'	'
Oil, Natural Gas and NGL Swaps | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	'	'	'	'
Oil, Natural Gas and NGL Swaps | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	-3,089	'	'	'	'	'
Oil, Natural Gas and NGL Swaps | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	0	'	'	'	'	'
NGL Swaps	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	-2,911	'	'	'
NGL Swaps | Fair Value, Inputs, Level 1	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
NGL Swaps | Fair Value, Inputs, Level 2	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	0	'	'	'
NGL Swaps | Fair Value, Inputs, Level 3	'	'	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'	'	'
Net fair value of derivative	'	'	($2,911)	'	'	'

Fair_Value_Measurements_Fair_V

Fair Value Measurements - Fair Value of Allocated Derivative Assets and Liabilities (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
In Thousands, unless otherwise specified			Fair Value, Inputs, Level 3		Fair Value, Inputs, Level 3		Fair Value, Inputs, Level 3		Fair Value, Inputs, Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'		'		'		'
Beginning balance	($3,530)	($2,414)	($2,843)		($2,854)		($2,517)		($112)
Gains (losses)	'	'	0		4,812		-2,432		1,755
Transfers out	'	'	2,843	[1]	0	[1]	2,843	[1]	0	[1]
Cash (paid) received upon settlement	'	'	0		-92		2,106		223
Ending balance	-3,530	-2,414	0		1,866		0		1,866
Unrealized gains included in earnings relating to derivatives held at period end	'	'	$0		$4,720		$0		$1,978
[1]	Fair values related to the Companybs natural gas collars, natural gas and NGL put options and NGL fixed price swaps were transferred from Level 3 to Level 2 in the second quarter of 2014 due to enhancements to the Companybs internal valuation process, including the use of observable inputs to assess the fair value. During the three and six months ended June 30, 2013, the Company did not have any transfers between Level 1, Level 2 or Level 3 fair value measurements. The Companybs policy is to recognize transfers in and/or out of fair value hierarchy levels as of the beginning of the quarterly reporting period in which the event or change in circumstances causing the transfer occurred.

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value Disclosures [Abstract]	'	'
Outstanding balance of line of credit	$85,000	$78,500
Notes payable	$21,335	$2,233

Goodwill_and_Intangible_Assets2

Goodwill and Intangible Assets - Schedule of Goodwill (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 26, 2014		Jun. 30, 2014	Jun. 26, 2014
In Thousands, unless otherwise specified			EFS and RPS	EFS and RPS		MCCS	MCCS
Goodwill [Roll Forward]	'	'	'	'		'	'
Goodwill at December 31, 2013	$39,698	$23,974	'	$11,665	[1]	'	$4,060	[2]
Additions	'	'	11,664	'		4,060	'
Goodwill at June 30, 2014	$39,698	$23,974	'	$11,665	[1]	'	$4,060	[2]
[1]	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the Services Acquisition includes any intangible assets that do not qualify for separate recognition, such as the EFS and RPS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships. Goodwill has been allocated to the oilfield services segment.
[2]	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. Such goodwill is not deductible for tax purposes. Specifically, the goodwill recorded as part of the acquisition of MCCS includes any intangible assets that do not qualify for separate recognition, such as the MCCS trained, skilled and assembled workforce, along with the expected synergies from leveraging the customer relationships and integrating new product offerings into MCCS's business. Goodwill has been allocated to the oilfield services segment.

Goodwill_and_Intangible_Assets3

Goodwill and Intangible Assets (Details) (MidCentral Energy Services, Customer Relationships, USD $)	3 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014
MidCentral Energy Services | Customer Relationships	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Amortization expense	$3.10	$6.20

Goodwill_and_Intangible_Assets4

Goodwill and Intangible Assets - Schedule of Finite-Lived Intangible Assets (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 26, 2014

Jun. 30, 2014

Dec. 31, 2013

In Thousands, unless otherwise specified

MidCentral Energy Services

MidCentral Energy Services

EFS and RPS

EFS and RPS

EFS and RPS

EFS and RPS

MCCS

MCCS

MCCS

Customer Relationships

Customer Relationships

Customer Relationships

Customer Relationships

Noncompete Agreements

Noncompete Agreements

Customer Relationships

Customer Relationships

Finite-Lived Intangible Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total intangible assets

$107,172

$36,772

$36,772

$36,772

$64,200

$0

$4,500

$0

$1,700

[1]

$1,700

$0

Less: accumulated amortization

7,946

1,763

'

'

'

'

'

'

'

'

'

Intangible assets, net

$99,226

$35,009

'

'

'

'

'

'

'

'

'

[1]

Customer relationships, an identifiable intangible asset, were valued based on the estimated free cash flows the customer relationships are expected to provide and

Equity_Details

Equity (Details) (USD $)

0 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

0 Months Ended

6 Months Ended

0 Months Ended

Apr. 29, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Jun. 30, 2013

Apr. 29, 2014

Jun. 30, 2014

Jan. 31, 2014

Jun. 26, 2014

Jun. 26, 2014

Jun. 26, 2014

Jun. 26, 2014

First Target Distribution

Second Target Distribution

Third and Thereafter Target Distribution

Cash Distribution

Cash Distribution

Cash Distribution

Common Units

Common Units

CEU Paradigm

MCCS

EFS and RPS

Phantom Units

Maximum

Class B Units

Class B Units

Class B Units

EFS and RPS

Phantom Units

Common Units

EFS and RPS

Common Units

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of common units in acquisitions (in units)

'

'

'

'

'

'

'

'

'

'

'

'

1,964,957

488,667

33,646

1,411,777

'

'

Common partnership units sold in public offering

'

'

'

'

'

'

'

'

'

'

'

3,450,000

'

'

'

'

'

'

Unit price of units sold in public offering

'

'

'

'

'

'

'

'

'

'

'

$23.25

'

'

'

'

'

'

Proceeds from public offering of common partnership units

'

'

'

'

'

'

'

'

'

'

'

$76,200,000

'

'

'

'

'

'

Underwriter's fees associated with public sale of common units

'

'

'

'

'

'

'

'

'

'

'

3,600,000

'

'

'

'

'

'

Offering costs associated with public sale of common units

'

'

'

'

'

'

'

'

'

'

'

300,000

'

'

'

'

'

'

Net proceeds from offering used to repay credit facility

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Days after quarter end in which distributions are declared and distributed

'

'

'

'45 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Prorated period of distribution

'

'

'

'

'

'

'

'

'

'

'47 days

'

'

'

'

'

'

'

Quarterly cash distribution per unit

'

'

'

'

'

'

'

'

$0.58

$0.57

$0.53

'

'

'

'

'

'

'

Increasing distribution percentage associated with Class B Units

'

'

'

'

'

15.00%

25.00%

50.00%

'

'

'

'

'

'

'

'

'

'

Equity-based compensation expense

'

400,000

0

644,000

7,738,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Compensation expense

'

'

'

'

400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Units issued in acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

432,038

'

Phantom unit vesting period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

Units measured at fair value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

401,171

'

Fair value of units granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,400,000

'

Fair value of units granted in acquisition to be expensed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$9,400,000

'

Equity_Schedule_of_Distributio

Equity - Schedule of Distributions (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Mar. 31, 2014		Jun. 30, 2013
Schedule of Incentive Distribution Made to Unitholders [Table] [Line Items]	'		'		'
Distributions	$9,221	[1]	$6,038	[2]	$2,504	[3]
General Partnership Units	'		'		'
Schedule of Incentive Distribution Made to Unitholders [Table] [Line Items]	'		'		'
Distributions	90	[1]	89	[2]	43	[3]
Common Units	'		'		'
Schedule of Incentive Distribution Made to Unitholders [Table] [Line Items]	'		'		'
Distributions	7,852	[1]	4,681	[2]	1,857	[3]
Subordinated Units	'		'		'
Schedule of Incentive Distribution Made to Unitholders [Table] [Line Items]	'		'		'
Distributions	$1,279	[1]	$1,268	[2]	$604	[3]
[1]	Reflects quarterly distributions of $0.58 per unit paid in the second quarter of 2014.
[2]	Reflects quarterly distributions of $0.575 per unit paid in the first quarter of 2014.
[3]	Prorated to reflect 47 days of the quarterly cash distribution of $0.525 per unit paid in the second quarter of 2013.

Equity_Allocation_of_Distribut

Equity - Allocation of Distributions (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Minimum Quarterly Distribution [Member]	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions	$16
Minimum | First Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions	19
Minimum | Second Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions	20
Minimum | Third and Thereafter Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions	24
Maximum | First Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions	20
Maximum | Second Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Distributions	$24
New Source Energy Partners LP | Minimum Quarterly Distribution [Member]	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	100.00%
New Source Energy Partners LP | First Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	85.00%
New Source Energy Partners LP | Second Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	75.00%
New Source Energy Partners LP | Third and Thereafter Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	50.00%
Class B | Minimum Quarterly Distribution [Member]	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	0.00%
Class B | First Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	15.00%
Class B | Second Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	25.00%
Class B | Third and Thereafter Target Distribution	'
Incentive Distribution Made to Managing Member or General Partner [Line Items]	'
Marginal percentage interest in distributions	50.00%

Earnings_per_Unit_Earnings_Per

Earnings per Unit - Earnings Per Unit (Details) (USD $)	1 Months Ended	3 Months Ended			5 Months Ended	6 Months Ended
In Thousands, except Share data, unless otherwise specified	Feb. 11, 2013	Jun. 30, 2014	Jun. 30, 2013		Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'	'		'	'	'
Net income (loss)	$5,303	$1,586	$8,151		$1,451	$54	$6,754
Common Stock Units	'	'	'		'	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'	'		'	'	'
Net income (loss)	'	1,334	6,045	[1]	'	97	1,397	[1]
Weighted average units outstanding	'	12,528,968	6,773,500		'	11,231,654	6,285,065
Basic and diluted income per unit (in usd per unit)	'	$0.11	$0.89		'	$0.01	$0.22
Subordinated Units	'	'	'		'	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'	'		'	'	'
Net income (loss)	'	235	1,968	[1]	'	-40	49	[1]
Weighted average units outstanding	'	2,205,000	2,205,000		'	2,205,000	2,205,000
Basic and diluted income per unit (in usd per unit)	'	$0.11	$0.89		'	($0.02)	$0.02
General Partnership Units	'	'	'		'	'	'
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]	'	'	'		'	'	'
Net income (loss)	'	$17	$138	[1]	'	($3)	$5	[1]
Weighted average units outstanding	'	155,102	155,102		'	155,102	154,104
Basic and diluted income per unit (in usd per unit)	'	$0.11	$0.89		'	($0.02)	$0.03
[1]	Reflects net income from February 13, 2013 through June 30, 2013 for the six months ended June 30, 2013.

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Chief Executive Officer

Board of Directors Chairman

General Partner

General Partner

Chief Financial Officer

Chief Financial Officer

Chief Financial Officer

Chief Financial Officer

New Dominion LLC

New Dominion LLC

General Partner

Subordinated Units

MidCentral Energy Services

MidCentral Energy Services

Chief Executive Officer

Board of Directors Chairman

Chief Executive Officer

President

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage of reporting company

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

69.40%

'

'

'

Percentage of common stock owned

'

'

'

'

'

5.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of common stock owned

'

'

'

'

'

'

17.20%

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of subordinate units owned

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

Number of subordinate units owned

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,205,000

'

'

Leasehold cost obligations

$300,000

'

$300,000

'

$400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Charges and fees due to related parties

8,901,000

'

8,901,000

'

8,221,000

'

'

'

'

'

'

'

'

3,400,000

1,300,000

'

'

'

'

Service management fees

'

700,000

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General and administrative expense

3,489,000

1,246,000

9,050,000

10,100,000

[1]

'

'

'

300,000

600,000

'

'

'

'

'

'

'

'

'

'

Proceeds from operational advances

'

'

'

'

'

'

'

'

1,500,000

'

'

'

'

'

'

'

'

'

'

Payments for operational advances

'

'

'

'

'

'

'

'

1,200,000

'

'

'

'

'

'

'

'

'

'

Professional fees paid

'

'

'

'

'

'

'

'

'

$200,000

$300,000

$700,000

$400,000

'

'

'

'

'

'

Ownership percentage of acquired entity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36.00%

36.00%

Ownership percentage in Finley & Cook

'

'

'

'

'

'

'

'

'

31.50%

'

31.50%

'

'

'

'

'

'

'

[1]

Includes $7.7 million of compensation expense related to common units granted to consultants, officers, directors and employees in conjunction with our initial public offering.

Related_Party_Transactions_Sum

Related Party Transactions - Summary of Related Party Transactions (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Related Party Transaction [Line Items]	'	'	'	'
Related Party Costs	$936	$277	$1,735	$543
Producing Overhead Charges | New Dominion LLC	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Related Party Costs	454	86	829	256
Drilling And Completion Overhead Charges | New Dominion LLC	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Related Party Costs	39	97	48	114
Saltwater Disposal Fees | New Dominion LLC	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Related Party Costs	$443	$94	$858	$173

Asset_Retirement_Obligations_C

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Asset retirement obligation at December 31, 2013	$3,455	'
Liabilities incurred upon acquiring and drilling wells	222	'
Revision of previous estimates	-33	'
Accretion	143	86
Asset retirement obligation at June 30, 2014	$3,787	'

Commitments_and_Contingencies_

Commitments and Contingencies (Details) (USD $)	6 Months Ended	16 Months Ended
	Jun. 30, 2014	Jun. 30, 2014
Loss Contingencies [Line Items]	'	'
Annual maintenance drilling budget	$8,200,000	'
Maintenance budget incurred to date	'	7,000,000
Estimated contingency loss	$250,000	$250,000

Business_Segment_Information_D

Business Segment Information (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
			segment
Segment Reporting Information [Line Items]	'	'	'	'
Number of operating segments	'	'	2	'
Equity-based compensation	$400	$0	$644	$7,738
General and Administrative Expenses	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Equity-based compensation	'	'	'	$7,700

Business_Segment_Information_S

Business Segment Information - Summary of Segment Operating Activities (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013		Dec. 31, 2013
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenue	$26,818		$10,649		$54,245		$20,009		'
Direct operating expenses	11,276		3,313		21,224		6,713		'
Segment margin	15,542		7,336		33,021		13,296		'
General and administrative	3,489		1,246		9,050		10,100	[1]	'
Depreciation, depletion, amortization and accretion	10,363		3,634		19,710		6,858		'
Income (loss) from operations	1,690		2,456		4,261		-3,662		'
Capital expenditures	9,886	[2]	3,170	[2]	21,451	[2]	3,516	[2]	'
Total assets	436,837		'		436,837		'		254,710
Exploration and Production	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenue	16,718		10,649		35,569		20,009		'
Direct operating expenses	5,308		3,313		10,690		6,713		'
Segment margin	11,410		7,336		24,879		13,296		'
General and administrative	2,022		1,246		5,866		10,100	[1]	'
Depreciation, depletion, amortization and accretion	6,970		3,634		12,857		6,858		'
Income (loss) from operations	2,418		2,456		6,156		-3,662		'
Capital expenditures	7,709	[2]	3,170	[2]	18,460	[2]	3,516	[2]	'
Total assets	199,387		'		199,387		'		181,440
Oilfield Services	'		'		'		'		'
Segment Reporting Information [Line Items]	'		'		'		'		'
Revenue	10,100	[3]	0	[3]	18,676	[3]	0	[3]	'
Direct operating expenses	5,968	[3]	0	[3]	10,534	[3]	0	[3]	'
Segment margin	4,132	[3]	0	[3]	8,142	[3]	0	[3]	'
General and administrative	1,467	[3]	0	[3]	3,184	[3]	0	[1],[3]	'
Depreciation, depletion, amortization and accretion	3,393	[3]	0	[3]	6,853	[3]	0	[3]	'
Income (loss) from operations	-728	[3]	0	[3]	-1,895	[3]	0	[3]	'
Capital expenditures	2,177	[2],[3]	0	[2],[3]	2,991	[2],[3]	0	[2],[3]	'
Total assets	$237,450	[3]	'		$237,450	[3]	'		$73,270	[3]
[1]	Includes $7.7 million of compensation expense related to common units granted to consultants, officers, directors and employees in conjunction with our initial public offering.
[2]	On an accrual basis and exclusive of acquisitions.
[3]	The Partnership's oilfield services segment was established with the MCE Acquisition that occurred in November 2013. See Note 2 "Acquisitions" for discussion.

Subsequent_Events_Details

Subsequent Events (Details) (Certain Employees)	3 Months Ended
	Jun. 30, 2014
Certain Employees	'
Subsequent Event [Line Items]	'
Common partnership units on which distributions were not paid	13,116

Subsequent_Events_Schedule_of_

Subsequent Events - Schedule of Distributions (Details) (Subsequent Event, USD $)	0 Months Ended
In Thousands, unless otherwise specified	Jul. 21, 2014
Subsequent Event [Line Items]	'
Distributions	$10,406	[1]
Common Units	'
Subsequent Event [Line Items]	'
Distributions	9,025	[1]
Subordinated Units	'
Subsequent Event [Line Items]	'
Distributions	1,290	[1]
General Partnership Units	'
Subsequent Event [Line Items]	'
Distributions	$91	[1]
[1]	Distributions were not paid on 13,116 common units issued in conjunction with grants to certain employees made in the second quarter of 2014.