Mid-Con Energy Partners (MCEP) 10-Q 5 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 05, 2014
Document Information [Line Items]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Trading Symbol	'MCEP	'
Entity Registrant Name	'Mid-Con Energy Partners, LP	'
Entity Central Index Key	'0001527709	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	21,128,516
General Partner Units [Member]	'	'
Document Information [Line Items]	'	'
Entity Common Stock, Shares Outstanding	'	360,000

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS:	'	'
Cash and cash equivalents	$1,840	$1,434
Accounts receivable:	'	'
Oil and natural gas sales	8,203	6,778
Other	75	104
Derivative financial instruments	0	153
Prepaids and other	392	191
Total current assets	10,510	8,660
Oil and natural gas properties, successful efforts method:	'	'
Proved properties	281,926	216,680
Accumulated depletion, depreciation and amortization	-44,483	-36,148
Total property and equipment, net	237,443	180,532
DERIVATIVE FINANCIAL INSTRUMENTS	0	48
OTHER ASSETS	841	843
Total assets	248,794	190,083
Accounts payable:	'	'
Trade	2,991	2,184
Related parties	5,497	2,982
Derivative financial instruments	5,372	1,627
Accrued liabilities	369	432
Total current liabilities	14,229	7,225
OTHER LONG-TERM LIABILITIES	115	128
LONG-TERM DEBT	139,000	112,000
ASSET RETIREMENT OBLIGATIONS	4,770	3,942
Commitments and Contingencies	'	'
Partnership equity	'	'
General partner interest	1,438	1,716
Limited partners- 21,059,141 and 19,319,362 units issued and outstanding as of June 30, 2014 and December 31, 2013, respectively	89,242	65,072
Total equity	90,680	66,788
Total liabilities and equity	$248,794	$190,083

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical)	Jun. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Limited partners, units issued	21,059,141	19,319,362
Limited partners, units outstanding	21,059,141	19,319,362

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (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	$24,216	$20,926	$45,854	$40,924
Natural gas sales	119	184	288	362
Net settlements on derivatives	-2,072	709	-2,993	1,382
Gain (loss) on unsettled derivatives, net	-2,819	960	-3,946	-833
Total revenues	19,444	22,779	39,203	41,835
Operating costs and expenses:	'	'	'	'
Lease operating expenses	6,596	3,745	11,287	7,091
Oil and natural gas production taxes	1,493	873	2,849	1,663
Impairment of proved oil and natural gas properties	0	1,578	0	1,578
Depreciation, depletion and amortization	4,672	3,908	8,335	7,371
Accretion of discount on asset retirement obligations	59	39	111	77
General and administrative	1,725	1,289	9,356	8,037
Total operating costs and expenses	14,545	11,432	31,938	25,817
Income from operations	4,899	11,347	7,265	16,018
Other income (expense):	'	'	'	'
Interest income and other	2	3	4	4
Interest expense	-1,054	-812	-1,861	-1,425
Total other expense	-1,052	-809	-1,857	-1,421
Net income	3,847	10,538	5,408	14,597
Computation of net income per limited partner unit:	'	'	'	'
General partnersb interest in net income	65	194	93	269
Limited partnersb interest in net income	$3,782	$10,344	$5,315	$14,328
Net income per limited partner unit:	'	'	'	'
Basic (in dollars per unit)	$0.18	$0.54	$0.26	$0.75
Diluted (in dollars per unit)	$0.18	$0.54	$0.26	$0.75
Weighted average limited partner units outstanding:	'	'	'	'
Common limited partner units (basic)	21,061	19,230	20,532	19,189
Common limited partner units (diluted)	21,082	19,230	20,557	19,189

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Cash Flows from Operating Activities:	'	'	'	'
Net income	$3,847	$10,538	$5,408	$14,597
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'	'
Depreciation, depletion and amortization	4,672	3,908	8,335	7,371
Debt placement fee amortization	'	'	92	84
Accretion of discount on asset retirement obligations	59	39	111	77
Impairment of proved oil and natural gas properties	0	1,578	0	1,578
Loss on unsettled derivative instruments, net	2,819	-960	3,946	833
Equity-based compensation	'	'	5,764	4,768
Changes in operating assets and liabilities:	'	'	'	'
Accounts receivable	'	'	-1,425	-364
Other receivables	'	'	29	403
Prepaid and other	'	'	-201	-363
Accounts payable and accrued liabilities	'	'	3,400	599
Net cash provided by operating activities	'	'	25,459	29,583
Cash Flows from Investing Activities:	'	'	'	'
Additions to oil and natural gas properties	'	'	-16,062	-14,533
Acquisitions of oil and natural gas properties	'	'	-14,607	-28,704
Net cash used in investing activities	'	'	-30,669	-43,237
Cash Flows from Financing Activities:	'	'	'	'
Proceeds from line of credit	'	'	61,000	66,000
Payments on line of credit	'	'	-34,000	-33,000
Distributions paid	'	'	-21,294	-19,588
Debt issuance costs	'	'	-90	0
Net cash provided by financing activities	'	'	5,616	13,412
Net increase (decrease) in cash and cash equivalents	'	'	406	-242
Beginning cash and cash equivalents	'	'	1,434	1,053
Ending cash and cash equivalents	1,840	811	1,840	811
Supplemental Cash Flow Information:	'	'	'	'
Cash paid for interest	'	'	1,823	1,339
Non-Cash Investing and Financing Activities:	'	'	'	'
Accrued capital expenditures - oil and natural gas properties	'	'	785	442
Limited partner units issued - acquisition of oil properties	$34,001	$0	$34,001	$0

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Changes in Equity (USD $)	Total	General Partner Units [Member]	Limited Partner [Member]
In Thousands, unless otherwise specified
Balance at Dec. 31, 2013	$66,788	$1,716	$65,072
Balance, Units at Dec. 31, 2013	'	'	19,319
Increase (Decrease) in Partners' Capital [Roll Forward]	'	'	'
Equity-based compensation	5,777	'	5,777
Equity-based compensation, Units	'	'	240
Issuance of limited partner units - acquisition	34,001	'	34,001
Issuance of limited partner units - acquisition, Units	'	'	1,500
Distributions	-21,294	-371	-20,923
Net income	5,408	93	5,315
Balance at Jun. 30, 2014	$90,680	$1,438	$89,242
Balance, Units at Jun. 30, 2014	'	'	21,059

Organization_and_Nature_of_Ope

Organization and Nature of Operations	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Organization and Nature of Operations	'
	Organization and Nature of Operations
	Nature of Operations
	Mid-Con Energy Partners, LP (“we,” “our,” “us,” the “Partnership,” the "Company") is a publicly held Delaware limited partnership formed in December 2011, that engages in the acquisition, development and production of oil and natural gas properties in North America, with a focus on the Mid-Continent region of the United States. Our limited partner units are traded on the NASDAQ Global Select Market under the symbol “MCEP”. Our general partner is Mid-Con Energy GP, LLC, a Delaware limited liability company.
	Basis of Presentation
	Our unaudited condensed consolidated financial statements included herein have been prepared pursuant to the rules and regulations of the SEC. These financial statements have not been audited by our independent registered public accounting firm, except that the condensed consolidated balance sheet at December 31, 2013 is derived from the audited financial statements.  Accordingly, certain information and footnote disclosures normally included in the financial statements prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") have been condensed or omitted in this Form 10-Q. We believe that the presentations and disclosures herein are adequate to make the information not misleading. The unaudited condensed consolidated financial statements reflect all adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the interim periods. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year. These interim financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2013.
	All intercompany transactions and account balances have been eliminated.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Acquisitions	'
	Acquisitions
	Southern Oklahoma acquisition
	During May 2014, we acquired additional working interest in some of our Southern Oklahoma core area properties ("Southern Oklahoma") for approximately $7.4 million, subject to customary post-closing adjustments. The acquisition was financed with borrowings under our revolving credit facility.
	Hugoton acquisition
	During February 2014, we acquired from our affiliate, Mid-Con Energy III, LLC , certain oil properties located in Cimarron, Love and Texas Counties, Oklahoma and Potter County, Texas ( "Hugoton") for an aggregate price of approximately $41.0 million, subject to customary post-closing purchase price adjustments. The results of operations of these properties have been included in the unaudited condensed consolidated financial statements since the acquisition date. The transaction was primarily funded with borrowings under our revolving credit facility of approximately $7.0 million and the issuance of 1,500,000 unregistered limited partner units, which will still receive the rights of a limited partner and represent limited partner interests in us, having an approximate value of $34.0 million. The value of the limited partner units issued as partial consideration was based on a 2.5% discount to the trailing twenty day volume weighted average price of the limited partner units as of February 26, 2014. The acquisition was accounted for under the acquisition method and the assets acquired and liabilities assumed were recorded at fair market value. The purchase price for these properties represented approximately 22% of the total value of our assets as of December 31, 2013.
	The recognized fair values of the Properties and liabilities assumed are as follows (in thousands):
	Fair Value of net assets:
	Oil properties	$	41,589
	Total assets acquired	$	41,589
	Fair Value of net liabilities assumed:
	Asset retirement obligation	589
	Net assets acquired	$	41,000
	Northeastern Oklahoma acquisition
	In May 2013, we acquired additional working interests in our Cushing properties located in the Northeastern Oklahoma core area and in certain Southern Oklahoma units. The results of operations of these properties have been included in the consolidated financial statements since the acquisition date. We paid approximately $27.4 million in aggregate consideration for the interests and the transaction was accounted for under the acquisition method. The transaction was financed using proceeds from our revolving credit facility. The recognized fair values of the identifiable assets of the Cushing properties acquired and liabilities assumed in connection with the acquisition are as follows (in thousands):
	Fair Value of net assets:
	Oil and natural gas properties	$	28,318
	Total assets acquired	$	28,318
	Fair Value of net liabilities assumed:
	Asset retirement obligation	906
	Net assets acquired	$	27,412
	The following table reflects pro forma revenues, net income and net income per limited partner unit for the three and six months ended June 30, 2014 and 2013, as if the acquisition of the Hugoton properties had taken place on January 1, 2013. Because we took over the interests at February 28, 2014, the values for the three and six months ended June 30, 2014 are reflected in the unaudited condensed consolidated statement of operations. The pro forma financial data does not include the results of operations for the Southern Oklahoma or Northeastern Oklahoma properties, as the results of operations were deemed not to be material. These unaudited pro forma amounts do not purport to be indicative of the results that would have actually been obtained during the period presented or that may be obtained in the future (in thousands):
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
	Revenues	$	19,444	$	25,667	$	41,112	$	47,214
	Net income	$	3,847	$	11,898	$	5,812	$	16,771
	Net income per limited partner unit:
	Basic	$	0.18	$	0.56	$	0.27	$	0.8
	Diluted	$	0.18	$	0.56	$	0.27	$	0.8

EquityBased_Compensation

Equity-Based Compensation	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Equity-Based Compensation	'
	Equity-Based Compensation
	We have a long-term incentive program (the “Long-Term Incentive Program”) for employees, officers, consultants and directors of our general partner and its affiliates, including Mid-Con Energy Operating, LLC (“Mid-Con Energy Operating”), who perform services for us. The Long-Term Incentive Program allows for the award of unit options, unit appreciation rights, unrestricted units, restricted units, phantom units, distribution equivalent rights granted with phantom units, and other types of awards and it is administered by the members of our general partner (the "Founders") and approved by the Board of Directors of the general partner. The Long-Term Incentive Program permits the grant of awards covering an aggregate of 1,764,000 units under the Form S-8 we filed with the SEC on January 25, 2012. If an employee terminates employment prior to the restriction lapse date, the awarded units are forfeited and canceled and are no longer considered issued and outstanding. The following table shows the number of existing awards and awards available under the Long-Term Incentive Program at June 30, 2014:
			Number of Common Units
	Approved and authorized awards		1,764,000
	Unrestricted units granted, including vested units		(803,051	)
	Restricted units granted, net of forfeitures and vesting		(116,090	)
	Phantom units issued, net of forfeitures		(40,750	)
	Awards available for future grant		804,109
	Equity Awards
	We account for restricted units as equity awards since these awards will be settled by issuing limited partner units. These restricted units vest over a three-year period and we assume a 10% forfeiture rate. A summary of our restricted units awarded for the six months ended June 30, 2014 is presented below:
	Restricted awards:	Number of Restricted Units			Average Grant Date Fair Value per Unit
	Outstanding at December 31, 2013	120,589
	Units granted	21,000			$23.36
	Units vested	(18,228	)		$21.79
	Units forfeited	(7,271	)		$24.02
	Outstanding at June 30, 2014	116,090
	We recognized $0.3 million and $6.0 million of total equity-based compensation expense for the three and six months ended June 30, 2014, respectively, and for the three and six months ended June 30, 2013 we recognized $0.2 million and $5.0 million of total equity-based compensation expense, respectively. These costs are reported as a component of general and administrative expense in our unaudited condensed consolidated statement of operations.
	Liability Awards
	We account for phantom units issued during 2013 as liability awards due to the Long-Term Incentive Program’s provision allowing the Board of Directors, at its discretion, to settle the award in either cash or limited partner units. The phantom units are an incentive based equity award that will be issued to employees or members of the board of directors over a three-year vesting period subject to attaining certain production target levels. The phantom units are not eligible to receive quarterly distributions until they vest. The fair value of these phantom units is remeasured at the end of each reporting period based on the current market price of our common units discounted for expected forfeitures and distribution payments during the vesting period in addition to an adjustment related to management's expectation of the Partnership's ability to attain the stated production target levels. These costs are reported as a component of general and administrative expense in our unaudited condensed consolidated statement of operations and are net of estimated forfeitures. These units are subject to forfeiture and we assume a 10% forfeiture rate. From the initial issuance of the the phantom units, we have recorded approximately $0.1 million of compensation expense through June 30, 2014.
	Activity related to these phantom units is as follows:
	Nonvested phantom awards:		Number of Units
	Outstanding at December 31, 2013		43,000
	Units forfeited		(2,250	)
	Outstanding at June 30, 2014		40,750
	Units not expected to vest		(24,450	)
	As of June 30, 2014, there was approximately $1.7 million of unrecognized compensation costs related to non-vested units. The cost is expected to be recognized over a weighted average period of approximately 2 years. Additionally, there was approximately $0.2 million of unrecognized compensation costs related to the phantom units based on the closing price of our common units at June 30, 2014. The cost is expected to be recognized over the next 2 years.

Derivative_Financial_Instrumen

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Financial Instruments	'
	Derivative Financial Instruments
	Our risk management program is intended to reduce our exposure to commodity prices and to assist with stabilizing cash flows. Accordingly, we utilize derivative financial instruments to manage our exposure to commodity price fluctuations and fluctuations in location differences between published index prices and the NYMEX futures prices. Our policies do not permit the use of derivatives for speculative purposes.
	At June 30, 2014, our open positions consisted of crude oil price collar (calls and puts) contracts and crude oil price swap contracts. Under commodity swap agreements, we exchange a stream of payments over time according to specified terms with another counterparty. In a typical commodity swap agreement, we agree to pay an adjustable or floating price tied to an agreed upon index for the oil commodity and in return receive a fixed price based on notional quantities. A collar is a combination of a put purchased by a party and a call option sold by the same party. In a typical collar transaction, if the floating price based on a market index is below the floor price, we receive from the counterparty an amount equal to this difference multiplied by the specified volume. If the floating price exceeds the floor price and is less than the ceiling price, no payment is required by either party. If the floating price exceeds the ceiling price, we must pay the counterparty an amount equal to the difference multiplied by the specific quantity.
	We have elected not to designate commodity derivatives contracts as hedges for accounting purposes, therefore, the mark-to-market adjustment reflecting the change in the fair value of unsettled derivative contracts is recorded in current period earnings as a non-cash gain or loss. When prices for oil are volatile, a significant portion of the effect of our hedging activities consists of non-cash income or expenses due to changes in the fair value of our commodity derivative contracts. Net settlement gains or losses on derivative contracts only arise from net payments made or received on monthly settlements or if a commodity derivative contract is terminated prior to its expiration. Pursuant to the accounting standard that permits netting of assets and liabilities where the right of offset exists, we present the fair value of derivative financial instruments on a net basis by counterparty.
	As of June 30, 2014, we had the following oil derivative open positions:
	Period Covered	Weighted		Weighted	Weighted		Total
		Average		Average	Average		Bbls
		Fixed		Floor	Ceiling		Hedged/day
		Price		Price	Price
	Swaps - 2014	$93.79					2,446
	Swaps - 2015	$92.83					411
	Collars - 2015			$85.00	$95.13		123
	Our oil derivative contracts expose us to credit risk in the event of nonperformance by counterparties. While we do not require our counterparties to our derivative contracts to post collateral, it is our policy to enter into derivative contracts only with counterparties that are major, creditworthy financial institutions deemed by management as competent and competitive market makers. We evaluate the credit standing of such counterparties by reviewing their credit rating. The counterparties to our derivative contracts currently in place are lenders under our revolving credit facility and have investment grade ratings.
	The following table summarizes the gross fair value by the appropriate balance sheet classification, even when the derivative instruments are subject to netting arrangements and qualify for net presentation in our unaudited condensed consolidated balance sheets at June 30, 2014 and December 31, 2013 (in thousands):
		Gross			Gross Amounts			Net Amounts
		Amounts			Offset in the			Presented in  the
		Recognized			Unaudited			Unaudited
					Condensed			Condensed
					Consolidated			Consolidated
					Balance Sheet			Balance Sheet
	June 30, 2014:
	Assets
	Derivative financial instruments - current asset	$	—		$	—		$	—
	Derivative financial instruments - long-term asset	—			—			—
	Total	$	—		$	—		$	—
	Liabilities
	Derivative financial instruments - current liability	$	(5,372	)	$	—		$	(5,372	)
	Derivative financial instruments - long-term liability	—			—			—
	Total	$	(5,372	)	$	—		$	(5,372	)
	Net liability	$	(5,372	)	$	—		$	(5,372	)
		Gross			Gross Amounts			Net Amounts
		Amounts			Offset in the			Presented in  the
		Recognized			Unaudited			Unaudited
					Condensed			Condensed
					Consolidated			Consolidated
					Balance Sheet			Balance Sheet
	December 31, 2013:
	Assets
	Derivative financial instruments - current asset	$	541		$	388		$	153
	Derivative financial instruments - long-term asset	48			—			48
	Total	$	589		$	388		$	201
	Liabilities
	Derivative financial instruments - current liability	$	(2,015	)	$	(388	)	$	(1,627	)
	Derivative financial instruments - long-term liability	—			—			—
	Total	$	(2,015	)	$	(388	)	$	(1,627	)
	Net liability	$	(1,426	)	$	—		$	(1,426	)
	The following table presents the impact of derivative financial instruments and their location within the unaudited condensed consolidated statements of operations (in thousands):
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net settlements on derivatives	$	(2,072	)	$	709		$	(2,993	)	$	1,382
	Gain (loss) on unsettled derivatives, net	(2,819		)	960			(3,946		)	(833		)
	Total gain (loss) on derivatives, net	$	(4,891	)	$	1,669		$	(6,939	)	$	549

Fair_Value_Disclosures

Fair Value Disclosures	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Disclosures	'
	Fair Value Disclosures
	Fair Value of Financial Instruments
	The carrying amounts reported in our balance sheet for cash, accounts receivable, accounts payable and derivative financial instruments approximate their fair values. The carrying amount of long-term debt under our revolving credit facility approximates fair value because the revolving credit facility’s variable interest rate resets frequently and approximates current market rates available to us.
	We account for our oil and natural gas commodity derivatives at fair value. The fair value of our derivative financial instruments is determined utilizing NYMEX closing prices for the contract period.
	Fair Value Measurements
	Fair value is the price that would be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. GAAP establishes a three-tier fair value hierarchy that is intended to increase consistency and comparability in fair value measurements and related disclosures. The hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).
	Our assets and liabilities recorded in the balance sheet are categorized based on the inputs to the valuation technique as follows:
	Level 1—Financial assets and liabilities for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access.
	Level 2—Financial assets and liabilities for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the asset or liability.
	Level 3—Financial assets and liabilities for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.
	When the inputs used to measure fair value fall within different levels of the hierarchy in a liquid environment, the level within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement in its entirety. Changes in the observability of valuation inputs may result in a reclassification for certain financial assets or liabilities.
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	We account for our commodity derivatives at fair value on a recurring basis. We use certain pricing models to determine the fair value of our derivative financial instruments. Inputs to the pricing models include publicly available prices from a compilation of data gathered from third parties and brokers. We validate 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 that those securities trade in active markets. See Note 4 for a summary of our derivative financial instruments.
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	We estimate the fair value of the asset retirement obligations based on discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation; amounts and timing of settlements; the credit-adjusted risk-free rate to be used; and inflation rates. See Note 6 for a summary of changes in asset retirement obligations.
	We review our long-lived assets to be held and used, including proved oil and natural gas properties, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected undiscounted future net cash flows is less than the carrying amount of the assets. In this circumstance, we recognize an impairment loss for the amount by which the carrying amount of the asset exceeds the estimated fair value of the asset. Estimating future cash flows involves the use of judgments, including estimation of the proved oil and natural gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs. There were no impairment charges for the three and six months ended June 30, 2014. During the three and six months ended June 30, 2013, we recorded a non-cash impairment charge of $1.6 million within our miscellaneous core area due to a decline in reserve estimates.
	The following sets forth, by level within the hierarchy, the fair value of our assets and liabilities measured at fair value as of June 30, 2014 and December 31, 2013 (in thousands):
		Level 1		Level 2			Level 3
	June 30, 2014
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative financial instruments- asset	$	—	$	—		$	—
	Derivative financial instruments- liability	—		(5,372		)	—
	Net financial liabilities	$	—	$	(5,372	)	$	—
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Asset retirement obligations	$	—	$	—		$	717
	December 31, 2013
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative financial instruments- asset	$	—	$	201		$	—
	Derivative financial instruments- liability	—		(1,627		)	—
	Net financial liabilities	$	—	$	(1,426	)	$	—
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Asset retirement obligations	$	—	$	—		$	879
	Impairment of proved oil and natural gas properties	$	—	$	—		$	1,578
	Our estimates of fair value have been determined at discrete points in time based on relevant market data. These estimates involve uncertainty and cannot be determined with precision. There were no changes in valuation techniques or related inputs for the six months ended June 30, 2014 and 2013.

Asset_Retirement_Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	Asset Retirement Obligations
	Our asset retirement obligations ("ARO") represent the estimated present value of the amount we will incur to plug, abandon and remediate our producing properties at the end of their production lives, in accordance with applicable state laws. We determine our ARO by calculating the present value of estimated cash flow related to the liability. Each year we review and to the extent necessary, revise our ARO estimates.
	ARO are recorded as a liability at their estimated present value at the various assets’ inception, with the offsetting charge to oil and natural gas properties. Periodic accretion of the discounted estimated liability is recorded in our consolidated statement of operations. The discounted capitalized cost is amortized to expense through the depreciation calculation over the life of the assets based on proved developed reserves.
	Changes in our ARO for the periods indicated are presented in the following table:
		Six Months Ended		Year Ended
		June 30, 2014		December 31, 2013
		(in thousands)
	Asset retirement obligation - beginning of period	$	3,942	$	2,890
	Liabilities incurred for new wells and interest	717		1,009
	Revision of estimates	—		(130		)
	Accretion expense	111		173
	Asset retirement obligation - end of period	$	4,770	$	3,942
	As of June 30, 2014 and December 31, 2013, all of our ARO were classified as long-term and were reported as “Asset Retirement Obligations” in our unaudited condensed consolidated balance sheets.

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	As of June 30, 2014, our credit facility consists of a $250.0 million senior secured revolving credit facility that expires in November 2018. Borrowings under the facility are secured by liens on not less than 80% of our assets and the assets of our subsidiaries. We may use borrowings under the facility for acquiring and developing oil and natural gas properties, for working capital purposes, for general partnership purposes and for funding distributions to our unitholders. At June 30, 2014, we had $139.0 million of borrowings outstanding under the revolving credit facility. The facility requires us and our subsidiaries to maintain a leverage ratio of Consolidated Funded Indebtedness to Consolidated EBITDAX (as defined in the facility) of not more than 4.0 to 1.0, and a current ratio of not less than 1.0 to 1.0.
	Borrowings under the revolving credit facility bear interest at a floating rate based on, at our election: (i) the greater of the prime rate of the Royal Bank of Canada, the federal funds effective rate plus 0.50%, or the one month adjusted London Interbank Offered Rate (“LIBOR”) plus 1.0%, all of which are subject to a margin that varies from 0.75% to 1.75% per annum according to the borrowing base usage (which is the ratio of outstanding borrowings and letters of credit to the borrowing base then in effect), or (ii) the applicable LIBOR plus a margin that varies from 1.75% to 2.75% per annum according to the borrowing base usage. For the three months ended June 30, 2014, the average effective interest rate was approximately 2.81%. The unused portion of the borrowing base is subject to a commitment fee that varies from 0.375% to 0.50% per annum according to the borrowing base usage.
	The borrowing base is determined by the lenders based on the value of our proved oil and natural gas reserves using assumptions regarding future prices, costs and other matters that may vary. The borrowing base is subject to scheduled redeterminations on or about April 30th and October 31st of each year with an additional redetermination during the period between each scheduled borrowing base determination, either at our request or at the request of the lenders. An additional borrowing base redetermination may be made at the request of the lenders in connection with a material disposition of our properties or a material liquidation of a hedge contract.
	During the 2013 borrowing base determination, our borrowing base under the revolving credit facility was increased from $130.0 million to $150.0 million in November 2013. Effective with this increase, the maturity terms of our revolving credit facility were extended to November 5, 2018 and the Bank of Nova Scotia ("Scotiabank") was added to the lender group. No other material terms of the original credit agreement were amended. During 2013, in connection with the amendments to our revolving credit facility, we incurred financing fees and expenses of approximately $0.4 million, which will be amortized over the life of the revolving credit facility. Such amortized expenses are recorded in "interest expense" on our consolidated statements of operations.
	On April 11, 2014, the borrowing base was increased from $150.0 million to $170.0 million and we incurred financing fees and expenses of approximately $0.1 million, which will be amortized over the life of the revolving credit facility. No other material terms of the original credit agreement were amended. Borrowings under the facility may not exceed our current borrowing base of $170.0 million.
	The revolving credit facility includes customary affirmative and negative covenants, such as limitations on the creation of new indebtedness and on certain liens, restrictions on certain transactions and payments. If we fail to perform our obligations under these and other covenants, the revolving credit commitments may be terminated and any outstanding indebtedness under the credit agreement, together with accrued interest could be declared immediately due and payable. We were in compliance with all debt covenants throughout the period ended June 30, 2014.

Commitment_and_Contingencies

Commitment and Contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitment and Contingencies	'
	Commitment and Contingencies
	We entered into a service agreement with Mid-Con Energy Operating, pursuant to which Mid-Con Energy Operating will provide certain services to us, our subsidiaries and our general partner, including management, administrative and operations services, which include marketing, geological and engineering services. Under the services agreement, we reimburse Mid-Con Energy Operating, on a monthly basis, for the allocable expenses it incurs in its performance under the services agreement. These expenses include, among other things, salary, bonus, incentive compensation and other amounts paid to persons who perform services for or on our behalf and other expenses allocated by Mid-Con Energy Operating to us.
	We are party to various claims, legal actions and complaints arising in the ordinary course of business. In the opinion of management, the ultimate resolution of all claims, legal actions and complaints after consideration of amounts accrued, insurance coverage or other indemnification arrangements will not have a material adverse effect on our financial position, results of operations or cash flows.
	Our general partner has entered into employment agreements with certain executive officers. The employment agreements provide for a term that commenced on August 1, 2011 and expire on August 1, 2014, unless earlier terminated, with automatic one-year renewal terms unless either we or the employee gives written notice of termination at least by February 1st preceding any such August 1st, for Charles R. Olmstead and Jeffrey R. Olmstead, and at least by May 1st preceding any August 1st, for S. Craig George. Pursuant to the employment agreements, each employee will serve in his respective position with our general partner, as set forth above, and has duties, responsibilities, and authority as the board of directors of our general partner may specify from time to time, in roles consistent with such positions that are assigned to him. The agreement stipulates that if there is a change of control, termination of employment with cause or without cause, or death of the executive certain payments will be made to the executive officer. These payments, depending on the reason for termination, currently range from $1.6 million to $1.9 million, including the value of vesting of any outstanding units.
	On May 1, 2014, the Partnership announced that Mr. S. Craig George informed the Board of Directors that he intends to resign from his role as Executive Chairman of the Board, effective August 1, 2014. Mr. George will remain as a Director of the Board.
	Additionally, on May 5, 2014, the Board approved the following changes to the executive officer positions of the Partnership, effective August 1, 2014.
	•	Mr. Charles R. Olmstead will resign as Chief Executive Officer and will be named as Executive Chairman of the Board;
	•	Mr. Jeffrey R. Olmstead will resign as President and Chief Financial Officer and will assume the position of Chief Executive Officer,while remaining as a Director of the Board.
	•	Dr. Michael L. Wiggins will be named President & Chief Engineer, while remaining as a Director of the Board; and
	•	Mr. Michael D. Peterson will be named to the position of Chief Financial Officer.
	Please refer to our Form 8-K filed with the SEC on May 6, 2014.

Equity

Equity	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Equity	'
	Equity
	Limited Partner Units
	At June 30, 2014 and December 31, 2013, Partnership’s equity consisted of 21,059,141 and 19,319,362 limited partner units, respectively, representing approximately a 98% limited partnership interest in us.
	In February 2014, we issued 1,500,000 unregistered limited partner units related to the acquisition of properties from one of our affiliates. These unregistered limited partner units will still receive the rights of a limited partner and will become registered in the future. See Note 2 for an explanation of the acquisition.
	Cash Distributions
	The following sets forth the distributions we paid during the six months ended June 30, 2014 (in thousands, except per unit distribution):
	Date Paid	Period Covered	Distribution	Total
			per Unit	Distribution
	February 14, 2014	October 1, 2013 - December 31, 2013	$0.52	$10,262
	May 15, 2014	January 1, 2014 - March 31, 2014	$0.52	$11,032
	On July 24, 2014, the Board of Directors of our general partner approved a quarterly cash distribution for the second quarter of 2014 of $0.515 per unit, or $2.06 on an annualized basis, which will be paid on August 11, 2014 to unitholders of record at the close of business on August 4, 2014. The aggregate amount of the distribution will be approximately $11.1 million.
	Allocation of Net Income
	Net income is allocated between our general partner and the limited partner unitholders in proportion to their pro rata ownership during the period.

Related_Party_Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	The following agreements were negotiated among affiliated parties and, consequently, are not the result of arm’s length negotiations. The following is a description of those agreements that have been entered into with the affiliates of our general partner and with our general partner.
	Services Agreement
	We are party to a services agreement with Mid-Con Energy Operating pursuant to which Mid-Con Energy Operating provides certain services to us, including management, administrative and operational services. The operational services include marketing, geological and engineering services. Under the services agreement, we reimburse Mid-Con Energy Operating, on a monthly basis, for the allocable expenses it incurs in its performance under the services agreement. These expenses include, among other things, salary, bonus, incentive compensation and other amounts paid to persons who perform services for us or on our behalf and other expenses allocated by Mid-Con Energy Operating to us. During the three and six months ended June 30, 2014, we reimbursed Mid-Con Energy Operating approximately $0.7 and $1.7 million, for direct expenses, respectively. These costs are included in the general and administrative expenses in our unaudited condensed consolidated statements of operations.
	Other Transactions with Related Persons
	We, various third parties with an ownership interest in the same property and our affiliate, Mid-Con Energy Operating, are party to standard oil and natural gas joint operating agreements, pursuant to which we and those third parties pay Mid-Con Energy Operating overhead charges associated with operating our properties (commonly referred to as the Council of Petroleum Accountants Societies, or COPAS, fee). We and those third parties will also pay Mid-Con Energy Operating for its direct and indirect expenses that are chargeable to the wells under their respective operating agreements.
	On February 28, 2014, we acquired from Mid-Con Energy III, LLC, an affiliated company, certain oil properties located in Cimarron, Love and Texas Counties, Oklahoma and Potter County, Texas. The terms of the acquisition were approved by the Conflicts Committee of the Board of Directors of the General Partner (the “Conflicts Committee”). The Conflicts Committee, which is composed entirely of independent directors, retained independent legal and financial counsel to assist it in evaluating and negotiating the purchase agreement and the acquisition. The purchase agreement contains representations and warranties, covenants and indemnification provisions that are typical for transactions of this nature and that were made or agreed to, among other things, to provide the parties thereto with specified rights and obligations and to allocate risk among them. For more detail and information, please see Note 2 to the Unaudited Condensed Consolidated Financial Statements included herein.
	On July 24, 2014, we entered into a definitive purchase and sale agreement to acquire an oil property located in Creek County, Oklahoma from Mid-Con Energy III, LLC, an affiliated company, The terms of the acquisition were approved by the Conflicts Committee. , For more detail and information, please see Note 12 to the Unaudited Condensed Consolidated Financial Statements included herein.
	At June 30, 2014, we had a payable to Mid-Con Energy Operating of approximately $5.5 million which was comprised of a joint interest billing payable of approximately $5.2 million and a payable for operating services of approximately $0.3 million. These amounts are included in the accounts payable-related parties in our unaudited condensed consolidated balance sheets.

New_Accounting_Standards

New Accounting Standards	6 Months Ended
	Jun. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	'
	New Accounting Standards
	In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers, which provides a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and will supersede most current revenue recognition guidance.  The standard is effective for public entities for annual and interim periods beginning after December 15, 2016.  Early adoption is not permitted. We are currently evaluating the impact the pronouncement will have on our consolidated financial statements and related disclosures.

Subsequent_Events

Subsequent Events	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Distributions
	On July 24, 2014, the Board of Directors of our general partner approved a quarterly cash distribution for the second quarter of 2014 of $0.515 per unit, or $2.06 on an annualized basis, which will be paid on August 11, 2014 to unitholders of record at the close of business on August 4, 2014. The aggregate amount of the distribution will be approximately $11.1 million.
	Acquisitions
	On July 24, 2014, we entered into a definitive purchase and sale agreement (the “Purchase Agreement”) with one of our Mid-Con Affiliates, Mid-Con Energy III, LLC to acquire an oil property located in Creek County, Oklahoma for an aggregate purchase price of approximately $56.5 million, subject to customary post-closing purchase price adjustments (collectively, the “Acquisition”). The Acquisition was closed on August 5, 2014, and will have the same effective date. We paid the aggregate purchase price with (i) approximately $4.5 million in cash, financed through borrowings under our revolving credit facility, and (ii) the issuance of 2,214,659 unregistered common units representing limited partner interests in the Partnership, having an approximate value of $52.0 million. The value of the common units issued as partial consideration for the Acquisition was based on the trailing ten day volume weighted average price of the common units.
	The terms of the Purchase Agreement were approved by the Conflicts Committee . The Conflicts Committee, which is composed entirely of independent directors, retained independent legal and financial counsel to assist in evaluating and negotiating the Purchase Agreement and the Acquisition. The purchase agreement contains representations and warranties, covenants and indemnification provisions that are typical for transactions of this nature and that were made or agreed to, among other things, to provide the parties thereto with specified rights and obligations and to allocate risk among them.
	On August 4, 2014, we entered into a definitive purchase and sale agreement to acquire working interests in the South Liberty Waterflood Unit in Liberty County, Texas for an aggregate purchase price of approximately $19.4 million. The acquisition is expected to close on August 29, 2014.
	Commodity Derivatives
	During July 2014, we entered into a series of oil derivative contracts covering a total of; (1) approximately 150,000 barrels of future production between January and March 2015 with a weighted average price of $95.73 per barrel, (2) approximately 150,000 barrels of future production between April and June 2015 with a weighted average price of $95.00 per barrel and (3) approximately 120,000 barrels of future production between July and December 2015 with a weighted average price of $91.04 per barrel.

Organization_and_Nature_of_Ope1

Organization and Nature of Operations (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of Presentation	'
	Basis of Presentation
	Our unaudited condensed consolidated financial statements included herein have been prepared pursuant to the rules and regulations of the SEC. These financial statements have not been audited by our independent registered public accounting firm, except that the condensed consolidated balance sheet at December 31, 2013 is derived from the audited financial statements.  Accordingly, certain information and footnote disclosures normally included in the financial statements prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP") have been condensed or omitted in this Form 10-Q. We believe that the presentations and disclosures herein are adequate to make the information not misleading. The unaudited condensed consolidated financial statements reflect all adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the interim periods. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year. These interim financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2013.

Acquisitions_Tables

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2014
Hugoton	'
Business Acquisition [Line Items]	'
Schedule of assets acquired and liabilities assumed	'
	The recognized fair values of the Properties and liabilities assumed are as follows (in thousands):
	Fair Value of net assets:
	Oil properties	$	41,589
	Total assets acquired	$	41,589
	Fair Value of net liabilities assumed:
	Asset retirement obligation	589
	Net assets acquired	$	41,000
Schedule of pro forma revenues	'
	The following table reflects pro forma revenues, net income and net income per limited partner unit for the three and six months ended June 30, 2014 and 2013, as if the acquisition of the Hugoton properties had taken place on January 1, 2013. Because we took over the interests at February 28, 2014, the values for the three and six months ended June 30, 2014 are reflected in the unaudited condensed consolidated statement of operations. The pro forma financial data does not include the results of operations for the Southern Oklahoma or Northeastern Oklahoma properties, as the results of operations were deemed not to be material. These unaudited pro forma amounts do not purport to be indicative of the results that would have actually been obtained during the period presented or that may be obtained in the future (in thousands):
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
	Revenues	$	19,444	$	25,667	$	41,112	$	47,214
	Net income	$	3,847	$	11,898	$	5,812	$	16,771
	Net income per limited partner unit:
	Basic	$	0.18	$	0.56	$	0.27	$	0.8
	Diluted	$	0.18	$	0.56	$	0.27	$	0.8
NE Oklahoma	'
Business Acquisition [Line Items]	'
Schedule of assets acquired and liabilities assumed	'
	The recognized fair values of the identifiable assets of the Cushing properties acquired and liabilities assumed in connection with the acquisition are as follows (in thousands):
	Fair Value of net assets:
	Oil and natural gas properties	$	28,318
	Total assets acquired	$	28,318
	Fair Value of net liabilities assumed:
	Asset retirement obligation	906
	Net assets acquired	$	27,412

EquityBased_Compensation_Equit

Equity-Based Compensation Equity-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Number of existing awards and awards available under Long-Term Incentive Program	'
	The following table shows the number of existing awards and awards available under the Long-Term Incentive Program at June 30, 2014:
			Number of Common Units
	Approved and authorized awards		1,764,000
	Unrestricted units granted, including vested units		(803,051	)
	Restricted units granted, net of forfeitures and vesting		(116,090	)
	Phantom units issued, net of forfeitures		(40,750	)
	Awards available for future grant		804,109
Summary of restricted units awarded	'
	A summary of our restricted units awarded for the six months ended June 30, 2014 is presented below:
	Restricted awards:	Number of Restricted Units			Average Grant Date Fair Value per Unit
	Outstanding at December 31, 2013	120,589
	Units granted	21,000			$23.36
	Units vested	(18,228	)		$21.79
	Units forfeited	(7,271	)		$24.02
	Outstanding at June 30, 2014	116,090
Phantom Share Units (PSUs) [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Summary of phantom units	'
	Activity related to these phantom units is as follows:
	Nonvested phantom awards:		Number of Units
	Outstanding at December 31, 2013		43,000
	Units forfeited		(2,250	)
	Outstanding at June 30, 2014		40,750
	Units not expected to vest		(24,450	)

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Commodity Contracts	'
	As of June 30, 2014, we had the following oil derivative open positions:
	Period Covered	Weighted		Weighted	Weighted		Total
		Average		Average	Average		Bbls
		Fixed		Floor	Ceiling		Hedged/day
		Price		Price	Price
	Swaps - 2014	$93.79					2,446
	Swaps - 2015	$92.83					411
	Collars - 2015			$85.00	$95.13		123
Estimated Fair Value of Derivative Assets and Liabilities	'
	The following table summarizes the gross fair value by the appropriate balance sheet classification, even when the derivative instruments are subject to netting arrangements and qualify for net presentation in our unaudited condensed consolidated balance sheets at June 30, 2014 and December 31, 2013 (in thousands):
		Gross			Gross Amounts			Net Amounts
		Amounts			Offset in the			Presented in  the
		Recognized			Unaudited			Unaudited
					Condensed			Condensed
					Consolidated			Consolidated
					Balance Sheet			Balance Sheet
	June 30, 2014:
	Assets
	Derivative financial instruments - current asset	$	—		$	—		$	—
	Derivative financial instruments - long-term asset	—			—			—
	Total	$	—		$	—		$	—
	Liabilities
	Derivative financial instruments - current liability	$	(5,372	)	$	—		$	(5,372	)
	Derivative financial instruments - long-term liability	—			—			—
	Total	$	(5,372	)	$	—		$	(5,372	)
	Net liability	$	(5,372	)	$	—		$	(5,372	)
		Gross			Gross Amounts			Net Amounts
		Amounts			Offset in the			Presented in  the
		Recognized			Unaudited			Unaudited
					Condensed			Condensed
					Consolidated			Consolidated
					Balance Sheet			Balance Sheet
	December 31, 2013:
	Assets
	Derivative financial instruments - current asset	$	541		$	388		$	153
	Derivative financial instruments - long-term asset	48			—			48
	Total	$	589		$	388		$	201
	Liabilities
	Derivative financial instruments - current liability	$	(2,015	)	$	(388	)	$	(1,627	)
	Derivative financial instruments - long-term liability	—			—			—
	Total	$	(2,015	)	$	(388	)	$	(1,627	)
	Net liability	$	(1,426	)	$	—		$	(1,426	)
Impact of Derivative Financial Instruments within Condensed Consolidated Statement of Operations	'
	The following table presents the impact of derivative financial instruments and their location within the unaudited condensed consolidated statements of operations (in thousands):
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net settlements on derivatives	$	(2,072	)	$	709		$	(2,993	)	$	1,382
	Gain (loss) on unsettled derivatives, net	(2,819		)	960			(3,946		)	(833		)
	Total gain (loss) on derivatives, net	$	(4,891	)	$	1,669		$	(6,939	)	$	549

Fair_Value_Disclosures_Tables

Fair Value Disclosures (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of fair value measurements	'
	The following sets forth, by level within the hierarchy, the fair value of our assets and liabilities measured at fair value as of June 30, 2014 and December 31, 2013 (in thousands):
		Level 1		Level 2			Level 3
	June 30, 2014
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative financial instruments- asset	$	—	$	—		$	—
	Derivative financial instruments- liability	—		(5,372		)	—
	Net financial liabilities	$	—	$	(5,372	)	$	—
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Asset retirement obligations	$	—	$	—		$	717
	December 31, 2013
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative financial instruments- asset	$	—	$	201		$	—
	Derivative financial instruments- liability	—		(1,627		)	—
	Net financial liabilities	$	—	$	(1,426	)	$	—
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Asset retirement obligations	$	—	$	—		$	879
	Impairment of proved oil and natural gas properties	$	—	$	—		$	1,578

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Changes in Asset Retirement Obligations	'
	Changes in our ARO for the periods indicated are presented in the following table:
		Six Months Ended		Year Ended
		June 30, 2014		December 31, 2013
		(in thousands)
	Asset retirement obligation - beginning of period	$	3,942	$	2,890
	Liabilities incurred for new wells and interest	717		1,009
	Revision of estimates	—		(130		)
	Accretion expense	111		173
	Asset retirement obligation - end of period	$	4,770	$	3,942

Equity_Tables

Equity (Tables)	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Cash Distributions	'
	The following sets forth the distributions we paid during the six months ended June 30, 2014 (in thousands, except per unit distribution):
	Date Paid	Period Covered	Distribution	Total
			per Unit	Distribution
	February 14, 2014	October 1, 2013 - December 31, 2013	$0.52	$10,262
	May 15, 2014	January 1, 2014 - March 31, 2014	$0.52	$11,032

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail) (USD $)	1 Months Ended	0 Months Ended	1 Months Ended
	31-May-13	2-May-14	Feb. 28, 2014
	NE Oklahoma [Member]	Southern Oklahoma [Member]	Hugoton
Business Acquisition [Line Items]	'	'	'
Aggregate consideration for acquired properties	'	'	$41,000,000
Consideration transferred, cash portion	27,400,000	7,400,000	7,000,000
Consideration transferred, stock issued, value	'	'	$34,000,000
Number of limited partner units issued to acquire oil properties	'	'	1,500,000
Weighted average price adjustment	'	'	2.50%
Period of weighted average price	'	'	'20 days
Purchase price, percent of total assets	'	'	22.00%

Acquisitions_Acquisitions_Asse

Acquisitions Acquisitions - Assets Acquired and Liabilities Assumed (Details) (USD $)	Feb. 28, 2014	31-May-13
In Thousands, unless otherwise specified
Fair Value of net assets:	'	'
Total assets acquired	$41,589	$28,318
Fair Value of net liabilities assumed:	'	'
Asset retirement obligation	589	906
Net assets acquired	41,000	27,412
Hugoton	'	'
Fair Value of net assets:	'	'
Oil properties	41,589	'
NE Oklahoma [Member]	'	'
Fair Value of net assets:	'	'
Oil properties	'	$28,318

Acquisitions_Acquisitions_Pro_

Acquisitions Acquisitions - Pro Forma (Details) (Hugoton, 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
Hugoton	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	$19,444	$25,667	$41,112	$47,214
Net income	$3,847	$11,898	$5,812	$16,771
Net income per limited partner unit:	'	'	'	'
Basic (in dollars per share)	$0.18	$0.56	$0.27	$0.80
Diluted (in dollars per share)	$0.18	$0.56	$0.27	$0.80

EquityBased_Compensation_Addit

Equity-Based Compensation - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity-based compensation expense	$0.30	$0.20	$6	$5
Restricted common units [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Vesting period	'	'	'3 years	'
Forfeiture rate	'	'	10.00%	'
Nonvested Units [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Unrecognized compensation costs	1.7	'	1.7	'
Weighted average period over which the unrecognized cost are expected to be recognized	'	'	'2 years	'
Phantom Share Units (PSUs) [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Vesting period	'	'	'3 years	'
Forfeiture rate	'	'	10.00%	'
Equity-based compensation expense	'	'	0.1	'
Unrecognized compensation costs	$0.20	'	$0.20	'
Weighted average period over which the unrecognized cost are expected to be recognized	'	'	'2 years	'
Long-Term Incentive Plan [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Approved and authorized awards	1,764,000	'	1,764,000	'

EquityBased_Compensation_Equit1

Equity-Based Compensation Equity-Based Compensation - Awards available for future grant (Details)	Jun. 30, 2014	Dec. 31, 2013
Restricted common units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Restricted units granted, net of forfeitures and vesting	-116,090	-120,589
Phantom Share Units (PSUs) [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Restricted units granted, net of forfeitures and vesting	-40,750	-43,000
Long-Term Incentive Plan [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Approved and authorized awards	1,764,000	'
Unrestricted Units granted, included vested units	-803,051	'
Awards available for future grant	804,109	'
Long-Term Incentive Plan [Member] | Restricted common units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Restricted units granted, net of forfeitures and vesting	-116,090	'
Long-Term Incentive Plan [Member] | Phantom Share Units (PSUs) [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Restricted units granted, net of forfeitures and vesting	-40,750	'

EquityBased_Compensation_Equit2

Equity-Based Compensation Equity-Based Compensation - Restricted Units (Details) (Restricted common units [Member], USD $)	6 Months Ended
	Jun. 30, 2014
Restricted common units [Member]	'
Number of units	'
Outstanding, beginning of period	120,589
Units granted	21,000
Units vested	-18,228
Units forfeited	-7,271
Outstanding, end of period	116,090
Average grant date fair value per unit, granted	$23.36
Average grant date fair value per unit, vested	$21.79
Average grant date fair value per unit, forfeited	$24.02

EquityBased_Compensation_Equit3

Equity-Based Compensation Equity-Based Compensation - Phantom Units (Details) (Phantom Share Units (PSUs) [Member])	6 Months Ended
	Jun. 30, 2014
Phantom Share Units (PSUs) [Member]	'
Number of units	'
Outstanding, beginning of period	43,000
Units forfeited	-2,250
Outstanding, end of period	40,750
Units not expected to vest	-24,450

Derivative_Financial_Instrumen2

Derivative Financial Instruments - Commodity Contracts (Detail)	6 Months Ended
	Jun. 30, 2014
	Bbls
Swap [Member] | Period Covered-2014 [Member]	'
Derivative [Line Items]	'
Weighted Average Fixed Price	93.79
Total Bbls Hedged/day	2,446
Swap [Member] | Period Covered-2015 [Member]	'
Derivative [Line Items]	'
Weighted Average Fixed Price	92.83
Total Bbls Hedged/day	411
Collars [Member] | Period Covered-2015 [Member]	'
Derivative [Line Items]	'
Weighted Average Floor Price	85
Weighted Average Ceiling Price	95.13
Total Bbls Hedged/day	123

Derivative_Financial_Instrumen3

Derivative Financial Instruments - Summary of Gross Fair Value by Appropriate Balance Sheet Classification (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Assets [Abstract]	'	'
Gross Amounts of Recognized Assets	$0	$589
Gross Amounts Offset in the Unaudited Consolidated Balance Sheet	0	388
Net financial assets	0	201
Liabilities [Abstract]	'	'
Gross Amounts of Recognized Liabilities	-5,372	-2,015
Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheet	0	-388
Net Amounts of Liabilities Presented in the Unaudited Condensed Consolidated Balance Sheet	-5,372	-1,627
Gross Amount of Recognized Assets and Liabilities	-5,372	-1,426
Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheet	0	0
Net amounts of Assets Presented in the Unaudited Condensed Consolidated Balance Sheet	-5,372	-1,426
Current Asset [Member]	'	'
Assets [Abstract]	'	'
Gross Amounts of Recognized Assets	0	541
Gross Amounts Offset in the Unaudited Consolidated Balance Sheet	0	388
Net financial assets	0	153
Long Term Asset [Member]	'	'
Assets [Abstract]	'	'
Gross Amounts of Recognized Assets	0	48
Gross Amounts Offset in the Unaudited Consolidated Balance Sheet	0	0
Net financial assets	0	48
Current Liability [Member]	'	'
Liabilities [Abstract]	'	'
Gross Amounts of Recognized Liabilities	-5,372	-2,015
Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheet	0	-388
Net Amounts of Liabilities Presented in the Unaudited Condensed Consolidated Balance Sheet	-5,372	-1,627
Long Term Liability [Member]	'	'
Liabilities [Abstract]	'	'
Gross Amounts of Recognized Liabilities	0	0
Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Unaudited Condensed Consolidated Balance Sheet	$0	$0

Derivative_Financial_Instrumen4

Derivative Financial Instruments - Impact of Derivative Financial Instruments within Condensed Consolidated Statement of Operations (Detail) (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]	'	'	'	'
Net settlements on derivatives	($2,072)	$709	($2,993)	$1,382
Gain (loss) on unsettled derivatives, net	-2,819	960	-3,946	-833
Total gain on derivatives, net	($4,891)	$1,669	($6,939)	$549

Fair_Value_Disclosures_Additio

Fair Value Disclosures - Additional Information (Detail) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset Impairment Charges	$0	$1,578	$0	$1,578
Miscellaneous [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset Impairment Charges	$0	$1,578	$0	$1,578

Fair_Value_Disclosures_Assets_

Fair Value Disclosures - Assets and Liabilities Measured at Fair Value on Recurring Basis and Nonrecurring Basis (Detail) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	$0	$201
Derivative Liability	-5,372	-1,627
Level 1 [Member] | Assets and Liabilities Measured at Fair Value on a Recurring Basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	0	0
Derivative Liability	0	0
Fair Value, Net Asset (Liability)	0	0
Level 1 [Member] | Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Impairment of proved oil and gas properties	'	0
Asset Retirement Obligations Fair Value Disc	0	0
Level 2 [Member] | Assets and Liabilities Measured at Fair Value on a Recurring Basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	0	201
Derivative Liability	-5,372	-1,627
Fair Value, Net Asset (Liability)	-5,372	-1,426
Level 2 [Member] | Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Impairment of proved oil and gas properties	'	0
Asset Retirement Obligations Fair Value Disc	0	0
Level 3 [Member] | Assets and Liabilities Measured at Fair Value on a Recurring Basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Asset	0	0
Derivative Liability	0	0
Fair Value, Net Asset (Liability)	0	0
Level 3 [Member] | Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Impairment of proved oil and gas properties	'	1,578
Asset Retirement Obligations Fair Value Disc	$717	$879

Asset_Retirement_Obligations_C

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Detail) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Asset Retirement Obligation [Roll Forward]	'	'	'	'	'
Asset Retirement Obligation	'	'	$3,942	$2,890	$2,890
Liabilities incurred for new wells and interests	'	'	717	'	1,009
Revision of estimates	'	'	0	'	-130
Accretion expense	59	39	111	77	173
Asset Retirement Obligation	$4,770	'	$4,770	'	$3,942

Debt_Additional_Information_De

Debt - Additional Information (Detail) (USD $)	3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Apr. 11, 2014	Mar. 31, 2014	Nov. 30, 2013	Apr. 30, 2013
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Line of credit facility, maximum borrowing capacity	$250,000,000	$250,000,000	'	'	'	'
Borrowings under the facility secure by liens	'	'not less than 80%	'	'	'	'
Senior secured revolving facility, expiring date	'	5-Nov-18	'	'	'	'
Revolving credit facility borrowings, outstanding	139,000,000	139,000,000	'	'	'	'
Minimum current ratio required under credit facility	'	1	'	'	'	'
Average effective rate	2.81%	'	'	'	'	'
Line of credit facility, borrowing capacity	170,000,000	170,000,000	170,000,000	150,000,000	150,000,000	130,000,000
Deferred Finance Costs, Gross	'	'	$100,000	'	$400,000	'
Minimum [Member]	'	'	'	'	'	'
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Margin	'	0.75%	'	'	'	'
Unused portion of borrowing base, percentage fee	'	0.38%	'	'	'	'
Maximum [Member]	'	'	'	'	'	'
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Leverage ratio required under credit facility	'	4.00%	'	'	'	'
Margin	'	1.75%	'	'	'	'
Unused portion of borrowing base, percentage fee	'	0.50%	'	'	'	'
Federal Funds Effective Swap Rate [Member]	'	'	'	'	'	'
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Federal fund effective rate	'	0.50%	'	'	'	'
London Interbank Offered Rate (LIBOR) [Member]	'	'	'	'	'	'
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Federal fund effective LIBOR	'	1.00%	'	'	'	'
London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]	'	'	'	'	'	'
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Applicable margin rate	'	1.75%	'	'	'	'
London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]	'	'	'	'	'	'
Line of Credit Facility [Line Items]	'	'	'	'	'	'
Applicable margin rate	'	2.75%	'	'	'	'

Commitment_and_Contingencies_A

Commitment and Contingencies - Additional Information (Detail) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Other Commitments [Line Items]	'
Employment agreements expiration date	1-Aug-14
Employment Agreements [Member]	'
Other Commitments [Line Items]	'
Employment agreements beginning date	1-Aug-11
Minimum [Member]	'
Other Commitments [Line Items]	'
Employee agreement termination payments	1.6
Maximum [Member]	'
Other Commitments [Line Items]	'
Employee agreement termination payments	1.9

Equity_Additional_Information_

Equity - Additional Information (Detail) (USD $)	0 Months Ended		6 Months Ended		0 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	15-May-14	Feb. 14, 2014	Jun. 30, 2014	Dec. 31, 2013	Jul. 24, 2014	Feb. 28, 2014
					Subsequent Event [Member]	Hugoton
Equity [Line Items]	'	'	'	'	'	'
Owners Equity	'	'	21,059,141	19,319,362	'	'
Limited partnership interest	'	'	98.00%	'	'	'
Distribution to holders	'	'	'	'	$11.10	'
Cash distribution	'	'	'	'	$0.52	'
Cash distribution on annualized basis	'	'	'	'	$2.06	'
Distribution to unitholders, payment date	15-May-14	14-Feb-14	'	'	11-Aug-14	'
Distribution to unitholders, record date	'	'	'	'	4-Aug-14	'
Number of limited partner units issued to acquire oil properties	'	'	'	'	'	1,500,000

Equity_Summary_of_Cash_Distrib

Equity - Summary of Cash Distributions (Detail) (USD $)	0 Months Ended
In Thousands, except Per Share data, unless otherwise specified	15-May-14	Feb. 14, 2014
Equity [Abstract]	'	'
Date Paid	15-May-14	14-Feb-14
Period Covered	'January 1, 2014 - March 31, 2014	'October 1, 2013 - December 31, 2013
Distribution per Unit	$0.52	$0.52
Total Distribution	$11,032	$10,262

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	3 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014
Related Party Transaction [Line Items]	'	'
Direct administrative expenses incurred and reimbursed to related party	$0.70	$1.70
Mid-Con Energy Operating [Member]	'	'
Related Party Transaction [Line Items]	'	'
Other transactions of related party	5.5	5.5
Payment of joint interest billing	'	5.2
Payment of operating services	'	$0.30

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)	0 Months Ended					1 Months Ended
	15-May-14	Feb. 14, 2014	Jul. 24, 2014	Jul. 24, 2014	Aug. 01, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 31, 2014
			Subsequent Event [Member]	Creek County, Oklahoma [Member]	Liberty County, Texas [Member]	January and March 2015 [Member]	April and June 2015 [Member]	July and December 2015 [Member]
				Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]	Subsequent Event [Member]
						Bbls	Bbls	Bbls
Subsequent Event [Line Items]	'	'	'	'	'	'	'	'
Cash distribution	'	'	$0.52	'	'	'	'	'
Cash distribution on annualized basis	'	'	$2.06	'	'	'	'	'
Distribution to unitholders, payment date	15-May-14	14-Feb-14	11-Aug-14	'	'	'	'	'
Distribution to unitholders, record date	'	'	4-Aug-14	'	'	'	'	'
Distribution to unit holders	'	'	$11,100,000	'	'	'	'	'
Aggregate consideration for acquired properties	'	'	'	56,500,000	'	'	'	'
Consideration transferred, cash portion	'	'	'	4,500,000	19,400,000	'	'	'
Consideration transferred, stock issued, value	'	'	'	$52,000,000	'	'	'	'
Number of limited partner units issued to acquire oil properties	'	'	'	2,214,659	'	'	'	'
Period of weighted average price	'	'	'	'10 days	'	'	'	'
Total Bbls Hedged/day	'	'	'	'	'	150,000	150,000	120,000
Weighted Average Fixed Price	'	'	'	'	'	95.73	95	91.04