Mid-Con Energy Partners (MCEP) 10-Q 3 Nov 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2014	Nov. 03, 2014
Document Information [Line Items]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Sep-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'
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	'	23,336,578
General Partner Units [Member]	'	'
Document Information [Line Items]	'	'
Entity Common Stock, Shares Outstanding	'	360,000

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS:	'	'
Cash and cash equivalents	$1,570	$1,434
Accounts receivable:	'	'
Oil and natural gas sales	8,495	6,778
Other	222	104
Derivative financial instruments	4,261	153
Prepaids and other	286	191
Total current assets	14,834	8,660
Oil and natural gas properties, successful efforts method:	'	'
Proved properties	366,692	216,680
Accumulated depletion, depreciation and amortization	-50,048	-36,148
Total property and equipment, net	316,644	180,532
DERIVATIVE FINANCIAL INSTRUMENTS	407	48
OTHER ASSETS	869	843
Total assets	332,754	190,083
Accounts payable:	'	'
Trade	2,592	2,184
Related parties	6,706	2,982
Derivative financial instruments	0	1,627
Accrued liabilities	189	432
Total current liabilities	9,487	7,225
OTHER LONG-TERM LIABILITIES	108	128
LONG-TERM DEBT	168,000	112,000
ASSET RETIREMENT OBLIGATIONS	5,401	3,942
Commitments and Contingencies	'	'
Partnership equity	'	'
General partner interest	1,534	1,716
Limited partners- 23,337,511 and 19,319,362 units issued and outstanding as of September 30, 2014 and December 31, 2013, respectively	148,224	65,072
Total equity	149,758	66,788
Total liabilities and equity	$332,754	$190,083

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical)	Sep. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Limited partners, units issued	23,337,511	19,319,362
Limited partners, units outstanding	23,337,511	19,319,362

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues:	'	'	'	'
Oil sales	$26,011	$22,831	$71,865	$63,755
Natural gas sales	162	151	450	513
Net settlements on derivatives	-760	-1,293	-3,753	89
Gain (loss) on unsettled derivatives, net	10,040	-5,501	6,094	-6,334
Total revenues	35,453	16,188	74,656	58,023
Operating costs and expenses:	'	'	'	'
Lease operating expenses	6,849	4,768	18,136	11,859
Oil and natural gas production taxes	1,845	1,007	4,694	2,670
Impairment of proved oil and natural gas properties	303	0	303	1,578
Depreciation, depletion and amortization	5,565	3,586	13,900	10,957
Accretion of discount on asset retirement obligations	64	47	175	124
General and administrative	2,602	1,630	11,958	9,667
Total operating costs and expenses	17,228	11,038	49,166	36,855
Income from operations	18,225	5,150	25,490	21,168
Other income (expense):	'	'	'	'
Interest income and other	3	2	7	6
Interest expense	-1,226	-895	-3,087	-2,320
Total other expense	-1,223	-893	-3,080	-2,314
Net income	17,002	4,257	22,410	18,854
Computation of net income per limited partner unit:	'	'	'	'
General partnersb interest in net income	268	77	375	346
Limited partnersb interest in net income	$16,734	$4,180	$22,035	$18,508
Net income per limited partner unit:	'	'	'	'
Basic (in dollars per unit)	$0.75	$0.22	$1.04	$0.96
Diluted (in dollars per unit)	$0.74	$0.22	$1.04	$0.96
Weighted average limited partner units outstanding:	'	'	'	'
Common limited partner units (basic)	22,450	19,269	21,175	19,213
Common limited partner units (diluted)	22,467	19,296	21,198	19,219

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Cash Flows from Operating Activities:	'	'	'	'
Net income	$17,002	$4,257	$22,410	$18,854
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'	'
Depreciation, depletion and amortization	5,565	3,586	13,900	10,957
Debt issuance costs amortization	'	'	144	126
Accretion of discount on asset retirement obligations	64	47	175	124
Impairment of proved oil and natural gas properties	303	0	303	1,578
(Gain) loss on unsettled derivative instruments, net	-10,040	5,501	-6,094	6,334
Equity-based compensation	'	'	6,900	5,419
Changes in operating assets and liabilities:	'	'	'	'
Accounts receivable	'	'	-1,717	-603
Other receivables	'	'	-118	603
Prepaids and other	'	'	-95	-259
Accounts payable and accrued liabilities	'	'	3,772	-648
Net cash provided by operating activities	'	'	39,580	42,485
Cash Flows from Investing Activities:	'	'	'	'
Additions to oil and natural gas properties	'	'	-24,079	-19,146
Acquisitions of oil and natural gas properties	'	'	-38,834	-28,022
Net cash used in investing activities	'	'	-62,913	-47,168
Cash Flows from Financing Activities:	'	'	'	'
Proceeds from line of credit	'	'	109,000	87,000
Payments on line of credit	'	'	-53,000	-53,000
Distributions paid	'	'	-32,361	-29,711
Debt issuance costs	'	'	-170	0
Net cash provided by financing activities	'	'	23,469	4,289
Net increase (decrease) in cash and cash equivalents	'	'	136	-394
Beginning cash and cash equivalents	'	'	1,434	1,053
Ending cash and cash equivalents	1,570	659	1,570	659
Supplemental Cash Flow Information:	'	'	'	'
Cash paid for interest	'	'	3,156	2,200
Non-Cash Investing and Financing Activities:	'	'	'	'
Accrued capital expenditures - oil and natural gas properties	'	'	1,043	373
Limited partner units issued - acquisition of oil properties	$86,001	$0	$86,001	$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	6,920	'	6,920
Equity-based compensation, Units	'	'	304
Issuance of limited partner units - acquisition	86,001	'	86,001
Issuance of limited partner units - acquisition, Units	'	'	3,714
Distributions	-32,361	-556	-31,805
Net income	22,410	374	22,036
Balance at Sep. 30, 2014	$149,758	$1,534	$148,224
Balance, Units at Sep. 30, 2014	'	'	23,337

Organization_and_Nature_of_Ope

Organization and Nature of Operations	9 Months Ended
	Sep. 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 July 2011, that engages in the acquisition, exploitation and development of producing oil and natural gas properties in North America, with a focus on Enhanced Oil Recovery ("EOR"). 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	9 Months Ended
	Sep. 30, 2014
Business Combinations [Abstract]	'
Acquisitions	'
	Acquisitions
	Creek County, Oklahoma acquisition
	During August 2014, we acquired from our affiliate, Mid-Con Energy III, LLC, a certain oil property located in Creek County, Oklahoma for an aggregate price of approximately $56.5 million, subject to customary post-closing purchase price adjustments. The results of operations of this property 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 $4.5 million in cash and the issuance of 2,214,659 unregistered limited partner units having an approximate value of $52.0 million. The acquisition was accounted for under the acquisition method and the assets acquired and liabilities assumed were recorded at fair market value.
	The recognized fair values of the property acquired and liabilities assumed are as follows (in thousands):
	Fair Value of net assets:
	Oil property	$	57,074
	Total assets acquired	$	57,074
	Fair Value of net liabilities assumed:
	Asset retirement obligation	574
	Net assets acquired	$	56,500
	Liberty County, Texas acquisition
	During August 2014, we acquired a waterflood unit in Liberty County, Texas for approximately $19.4 million, subject to customary post-closing adjustments. The acquisition was financed with borrowings under our revolving credit facility.
	Southern Oklahoma acquisition
	During May 2014, we acquired additional working interest in some of our Southern Oklahoma core area properties 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. 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 having an approximate value of $34.0 million. The acquisition was accounted for under the acquisition method and the assets acquired and liabilities assumed were recorded at fair market value.
	The recognized fair values of the Hugoton properties acquired 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 nine months ended September 30, 2014 and 2013, as if the acquisitions of the Creek County property and Hugoton properties had taken place on January 1, 2013. Because we took over the interests at August 1, 2014 for the Creek County property, the values for August and September 2014 are included in the unaudited condensed consolidated statement of operations. Because we took over the interests at February 28, 2014 for the Hugoton properties, the values for March 2014 through September 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 Liberty County, Texas, 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				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
	Revenues	$	36,647	$	22,565	$	84,436	$	74,202
	Net income	$	17,915	$	7,385	$	28,018	$	25,614
	Net income per limited partner unit:
	Basic	$	0.76	$	0.32	$	1.19	$	1.1
	Diluted	$	0.76	$	0.32	$	1.19	$	1.1

EquityBased_Compensation

Equity-Based Compensation	9 Months Ended
	Sep. 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 September 30, 2014:
			Number of Common Units
	Approved and authorized awards		1,764,000
	Unrestricted units granted, including vested restricted units		(866,253	)
	Restricted units granted, net of forfeitures and vesting		(116,599	)
	Phantom units issued, net of forfeitures		(25,666	)
	Awards available for future grant		755,482
	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 nine months ended September 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	53,375			$23.11
	Units vested	(44,430	)		$23.09
	Units forfeited	(12,935	)		$23.52
	Outstanding at September 30, 2014	116,599
	We account for unrestricted units as equity awards since these awards will be settled by issuing limited partner units. A summary of our unrestricted units awarded for the nine months ended September 30, 2014 is presented below:
	Unrestricted awards:	Number of Unrestricted Units			Average Grant Date Fair Value per Unit
	Unrestricted units granted at December 31, 2013	558,773
	Unrestricted units granted	263,050			$23.30
	Restricted units vested	44,430			$23.09
	Total unrestricted units at September 30, 2014	866,253
	We recognized $1.1 million and $7.1 million of total equity-based compensation expense for the three and nine months ended September 30, 2014, respectively, and for the three and nine months ended September 30, 2013 we recognized $0.6 million and $5.6 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 limited partner 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 September 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		(17,334	)
	Outstanding at September 30, 2014		25,666
	Outstanding units not expected to vest		(16,812	)
	As of September 30, 2014, there was approximately $1.9 million of unrecognized compensation costs related to non-vested restricted units. The cost is expected to be recognized over a weighted average period of approximately 1.9 years. Additionally, there was approximately $0.1 million of unrecognized compensation costs related to the phantom units based on the closing price of our common units at September 30, 2014. The cost is expected to be recognized over the next 1.7 years.

Derivative_Financial_Instrumen

Derivative Financial Instruments	9 Months Ended
	Sep. 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 price volatility 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 or physical delivery points and NYMEX futures prices. Our policies do not permit the use of derivatives for speculative purposes.
	At September 30, 2014, our open positions consisted of 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.
	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 September 30, 2014, we had the following oil derivative open positions:
	Period Covered	Weighted		Total
		Average		Bbls
		Fixed		Hedged/day
		Price
	Swaps - 2014	$93.79		2,446
	Swaps - 2015	$93.29		1,932
	Swaps - 2016	$90.20		82
	In July 2014, we restructured 123 barrels per day of 2015 crude oil collar contracts into 2015 swap contracts covering the same volumes. These restructurings were effected between contracts of equal value and accordingly, did not require any cash settlements.
	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 credit 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 September 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
	September 30, 2014:
	Assets
	Derivative financial instruments - current asset	$	4,290		$	29		$	4,261
	Derivative financial instruments - long-term asset	407			—			407
	Total	$	4,697		$	29		$	4,668
	Liabilities
	Derivative financial instruments - current liability	$	(29	)	$	(29	)	$	—
	Derivative financial instruments - long-term liability	—			—			—
	Total	$	(29	)	$	(29	)	$	—
	Net asset	$	4,668		$	—		$	4,668
		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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Net settlements on derivatives	$	(760	)	$	(1,293	)	$	(3,753	)	$	89
	Gain (loss) on unsettled derivatives, net	10,040			(5,501		)	6,094			(6,334		)
	Total gain (loss) on derivatives, net	$	9,280		$	(6,794	)	$	2,341		$	(6,245	)

Fair_Value_Disclosures

Fair Value Disclosures	9 Months Ended
	Sep. 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 and accounts payable 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 derivative financial instruments 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. During the three and nine months ended September 30, 2014, we recorded a non-cash impairment charge of $0.3 million within our Southern Oklahoma core area due to a decline in reserve estimates. There were no impairment charges for the three months ended September 30, 2013. During the nine months ended September 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 September 30, 2014 and December 31, 2013 (in thousands):
		Level 1		Level 2			Level 3
	September 30, 2014
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative financial instruments- asset	$	—	$	4,668		$	—
	Derivative financial instruments- liability	—		—			—
	Net financial assets	$	—	$	4,668		$	—
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Asset retirement obligations	$	—	$	—		$	1,284
	Impairment of proved oil and natural gas properties	$	—	$	—		$	303
	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 nine months ended September 30, 2014 and 2013.

Asset_Retirement_Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 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:
		Nine Months Ended		Year Ended
		September 30, 2014		December 31, 2013
		(in thousands)
	Asset retirement obligation - beginning of period	$	3,942	$	2,890
	Liabilities incurred for new wells and interest	1,284		1,009
	Revision of estimates	—		(130		)
	Accretion expense	175		173
	Asset retirement obligation - end of period	$	5,401	$	3,942
	As of September 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	9 Months Ended
	Sep. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	As of September 30, 2014, our credit facility consists of a $250.0 million senior secured revolving credit facility that expires in November 2018. Borrowings under the revolving credit facility may not exceed our current borrowing base of $190.0 million as determined at August 29, 2014. 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 September 30, 2014, we had $168.0 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 September 30, 2014, the average effective interest rate was approximately 2.83%. 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 November 2013 borrowing base determination, our borrowing base under the revolving credit facility was increased from $130.0 million to $150.0 million. 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 are 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. No other material terms of the original credit agreement were amended. In connection with the amendment to our revolving credit facility, we incurred financing fees and expenses of approximately $0.1 million, which are amortized over the life of the revolving credit facility. Such amortized expenses are recorded in "interest expense" on our consolidated statements of operations. No other material terms of the original credit agreement were amended.
	On August 29, 2014, the borrowing base was increased from $170.0 million to $190.0 million and we incurred financing fees and expenses of approximately $0.1 million, which are amortized over the life of the revolving credit facility. Such amortized expenses are recorded in "interest expense" on our consolidated statements of operations. No other material terms of the original credit agreement were amended.
	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 September 30, 2014.

Commitment_and_Contingencies

Commitment and Contingencies	9 Months Ended
	Sep. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitment and Contingencies	'
	Commitments and Contingencies
	We have 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 automatically renewed on August 1, 2014 for an additional year, unless earlier terminated, and will continue to automatically renew for one-year 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. 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.

Equity

Equity	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
Equity	'
	Equity
	Limited Partner Units
	At September 30, 2014 and December 31, 2013, the Partnership’s equity consisted of 23,337,511 and 19,319,362 limited partner units, respectively, representing approximately a 98% limited partnership interest in us.
	In February 2014 and August 2014, we issued 1,500,000 and 2,214,659 unrestricted limited partner units, respectively, related to the acquisition of properties from one of our affiliates. See Note 2 for an explanation of these acquisitions.
	Cash Distributions
	The following sets forth the distributions we paid during the nine months ended September 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
	August 11, 2014	April 1, 2014 - June 30, 2014	$0.52	$11,067
				$32,361
	On October 22, 2014, the Board of Directors of our general partner approved a quarterly cash distribution for the third quarter of 2014 of $0.515 per unit, or $2.06 on an annualized basis, which will be paid on November 14, 2014 to unitholders of record at the close of business on November 3, 2014. The aggregate amount of the distribution will be approximately $12.2 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	9 Months Ended
	Sep. 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 nine months ended September 30, 2014, we reimbursed Mid-Con Energy Operating approximately $0.8 and $2.5 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.
	During February and August, 2014, we acquired from Mid-Con Energy III, LLC, an affiliated company, certain oil properties located in Oklahoma and Texas. The terms of the acquisitions 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 agreements and the acquisitions. The purchase agreements contained 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.
	At September 30, 2014, we had a payable to Mid-Con Energy Operating of approximately $6.7 million which was comprised of a joint interest billing payable of approximately $6.4 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	9 Months Ended
	Sep. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
New Accounting Standards	'
	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	9 Months Ended
	Sep. 30, 2014
Subsequent Events [Abstract]	'
Subsequent Events	'
	Subsequent Events
	Distributions
	On October 22, 2014, the Board of Directors of our general partner approved a quarterly cash distribution for the third quarter of 2014 of $0.515 per unit, or $2.06 on an annualized basis, which will be paid on November 14, 2014 to unitholders of record at the close of business on November 3, 2014. The aggregate amount of the distribution will be approximately $12.2 million.
	Acquisitions
	On October 7, 2014, we entered into a definitive purchase and sale agreement to acquire multiple oil and natural gas properties covering approximately 18,000 net acres located in Coke, Coleman, Fisher, Haskell, Jones, Kent, Nolan, Runnels, Stonewall, Taylor, and Tom Green Counties, Texas ("Eastern Shelf Acquisition") for an aggregate purchase price of approximately $120.0 million, subject to customary post-closing adjustments. The acquisition is expected to close in November 2014, with an effective date of September 1, 2014. Please refer to our Form 8-K filed with the SEC on October 14, 2014.
	Revolving Credit Facility
	Contingent upon completion of the Eastern Shelf Acquisition, the Partnership has secured lender commitments to increase its borrowing base to $240.0 million, up 26% from the $190.0 million in commitments established under its existing revolving credit facility. The borrowing base increase will become effective upon closing of the acquisition, at which time a $100.0 million Second Lien Term Loan, maturing in May of 2019, will also become available to the Partnership. The borrowing base increase and senior secured Second Lien Term Loan have been fully underwritten by the Royal Bank of Canada acting in its capacity as Administrative Agent along with other participating lenders.

Organization_and_Nature_of_Ope1

Organization and Nature of Operations (Policies)	9 Months Ended
	Sep. 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)	9 Months Ended
	Sep. 30, 2014
Creek County	'
Business Acquisition [Line Items]	'
Schedule of assets acquired and liabilities assumed	'
	The recognized fair values of the property acquired and liabilities assumed are as follows (in thousands):
	Fair Value of net assets:
	Oil property	$	57,074
	Total assets acquired	$	57,074
	Fair Value of net liabilities assumed:
	Asset retirement obligation	574
	Net assets acquired	$	56,500
Hugoton	'
Business Acquisition [Line Items]	'
Schedule of assets acquired and liabilities assumed	'
	The recognized fair values of the Hugoton properties acquired 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 nine months ended September 30, 2014 and 2013, as if the acquisitions of the Creek County property and Hugoton properties had taken place on January 1, 2013. Because we took over the interests at August 1, 2014 for the Creek County property, the values for August and September 2014 are included in the unaudited condensed consolidated statement of operations. Because we took over the interests at February 28, 2014 for the Hugoton properties, the values for March 2014 through September 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 Liberty County, Texas, 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				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
	Revenues	$	36,647	$	22,565	$	84,436	$	74,202
	Net income	$	17,915	$	7,385	$	28,018	$	25,614
	Net income per limited partner unit:
	Basic	$	0.76	$	0.32	$	1.19	$	1.1
	Diluted	$	0.76	$	0.32	$	1.19	$	1.1
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_Table

Equity-Based Compensation (Tables)	9 Months Ended
	Sep. 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 September 30, 2014:
			Number of Common Units
	Approved and authorized awards		1,764,000
	Unrestricted units granted, including vested restricted units		(866,253	)
	Restricted units granted, net of forfeitures and vesting		(116,599	)
	Phantom units issued, net of forfeitures		(25,666	)
	Awards available for future grant		755,482
Summary of restricted units awarded	'
	A summary of our restricted units awarded for the nine months ended September 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	53,375			$23.11
	Units vested	(44,430	)		$23.09
	Units forfeited	(12,935	)		$23.52
	Outstanding at September 30, 2014	116,599
Summary of unrestricted units	'
	A summary of our unrestricted units awarded for the nine months ended September 30, 2014 is presented below:
	Unrestricted awards:	Number of Unrestricted Units			Average Grant Date Fair Value per Unit
	Unrestricted units granted at December 31, 2013	558,773
	Unrestricted units granted	263,050			$23.30
	Restricted units vested	44,430			$23.09
	Total unrestricted units at September 30, 2014	866,253
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		(17,334	)
	Outstanding at September 30, 2014		25,666
	Outstanding units not expected to vest		(16,812	)

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Commodity Contracts	'
	As of September 30, 2014, we had the following oil derivative open positions:
	Period Covered	Weighted		Total
		Average		Bbls
		Fixed		Hedged/day
		Price
	Swaps - 2014	$93.79		2,446
	Swaps - 2015	$93.29		1,932
	Swaps - 2016	$90.20		82
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 September 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
	September 30, 2014:
	Assets
	Derivative financial instruments - current asset	$	4,290		$	29		$	4,261
	Derivative financial instruments - long-term asset	407			—			407
	Total	$	4,697		$	29		$	4,668
	Liabilities
	Derivative financial instruments - current liability	$	(29	)	$	(29	)	$	—
	Derivative financial instruments - long-term liability	—			—			—
	Total	$	(29	)	$	(29	)	$	—
	Net asset	$	4,668		$	—		$	4,668
		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						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Net settlements on derivatives	$	(760	)	$	(1,293	)	$	(3,753	)	$	89
	Gain (loss) on unsettled derivatives, net	10,040			(5,501		)	6,094			(6,334		)
	Total gain (loss) on derivatives, net	$	9,280		$	(6,794	)	$	2,341		$	(6,245	)

Fair_Value_Disclosures_Tables

Fair Value Disclosures (Tables)	9 Months Ended
	Sep. 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 September 30, 2014 and December 31, 2013 (in thousands):
		Level 1		Level 2			Level 3
	September 30, 2014
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative financial instruments- asset	$	—	$	4,668		$	—
	Derivative financial instruments- liability	—		—			—
	Net financial assets	$	—	$	4,668		$	—
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Asset retirement obligations	$	—	$	—		$	1,284
	Impairment of proved oil and natural gas properties	$	—	$	—		$	303
	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)	9 Months Ended
	Sep. 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:
		Nine Months Ended		Year Ended
		September 30, 2014		December 31, 2013
		(in thousands)
	Asset retirement obligation - beginning of period	$	3,942	$	2,890
	Liabilities incurred for new wells and interest	1,284		1,009
	Revision of estimates	—		(130		)
	Accretion expense	175		173
	Asset retirement obligation - end of period	$	5,401	$	3,942

Equity_Tables

Equity (Tables)	9 Months Ended
	Sep. 30, 2014
Equity [Abstract]	'
Cash Distributions	'
	The following sets forth the distributions we paid during the nine months ended September 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
	August 11, 2014	April 1, 2014 - June 30, 2014	$0.52	$11,067
				$32,361

Acquisitions_Additional_Inform

Acquisitions - Additional Information (Detail) (USD $)	1 Months Ended
In Millions, except Share data, unless otherwise specified	Aug. 31, 2014	Aug. 31, 2014	31-May-13	31-May-14	Feb. 28, 2014
	Creek County	Liberty County, Texas	NE Oklahoma	Southern Oklahoma	Hugoton
Business Acquisition [Line Items]	'	'	'	'	'
Aggregate consideration for acquired properties	$56.50	'	'	'	$41
Payments to Acquire Oil and Gas Property	4.5	19.4	27.4	7.4	7
Number of limited partner units issued to acquire oil properties	2,214,659	'	'	'	1,500,000
Consideration transferred, stock issued, value	$52	'	'	'	$34

Acquisitions_Assets_Acquired_a

Acquisitions - Assets Acquired and Liabilities Assumed (Details) (USD $)	Aug. 31, 2014	Feb. 28, 2014	31-May-13
In Thousands, unless otherwise specified	Creek County	Hugoton	NE Oklahoma
Fair Value of net assets:	'	'	'
Oil properties	$57,074	$41,589	$28,318
Total assets acquired	57,074	41,589	28,318
Fair Value of net liabilities assumed:	'	'	'
Asset retirement obligation	574	589	906
Net assets acquired	$56,500	$41,000	$27,412

Acquisitions_Acquisitions_Pro_

Acquisitions Acquisitions - Pro Forma (Details) (Hugoton, USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Hugoton	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	$36,647	$22,565	$84,436	$74,202
Net income	$17,915	$7,385	$28,018	$25,614
Net income per limited partner unit:	'	'	'	'
Basic (in dollars per share)	$0.76	$0.32	$1.19	$1.10
Diluted (in dollars per share)	$0.76	$0.32	$1.19	$1.10

EquityBased_Compensation_Addit

Equity-Based Compensation - Additional Information (Detail) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Equity-based compensation expense	$1.10	$0.60	$7.10	$5.60
Nonvested Units [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Unrecognized compensation costs	1.9	'	1.9	'
Weighted average period over which the unrecognized cost are expected to be recognized	'	'	'1 year 11 months 5 days	'
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	$0.10	'	$0.10	'
Weighted average period over which the unrecognized cost are expected to be recognized	'	'	'1 year 8 months 23 days	'
Restricted Common Units [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Vesting period	'	'	'3 years	'
Forfeiture rate	'	'	10.00%	'
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_Award

Equity-Based Compensation - Awards available for future grant (Details)	Sep. 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	-116,599	-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	-25,666	-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	-866,253	'
Awards available for future grant	755,482	'
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	-116,599	'
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	-25,666	'

EquityBased_Compensation_Restr

Equity-Based Compensation - Restricted Units (Details) (Restricted Common Units [Member], USD $)	9 Months Ended
	Sep. 30, 2014
Restricted Common Units [Member]	'
Number of units	'
Outstanding, beginning of period	120,589
Units granted	53,375
Units vested	-44,430
Units forfeited	-12,935
Outstanding, end of period	116,599
Average grant date fair value per unit, granted	$23.11
Average grant date fair value per unit, vested	$23.09
Average grant date fair value per unit, forfeited	$23.52

EquityBased_Compensation_Unres

Equity-Based Compensation - Unrestricted Units (Details) (USD $)	9 Months Ended
	Sep. 30, 2014
Unrestricted Common Units [Member]	'
Number of units	'
Outstanding, beginning of period	558,773
Units granted	263,050
Outstanding, end of period	866,253
Average grant date fair value per unit, granted	$23.30
Average grant date fair value per unit, vested	$23.09
Restricted Common Units [Member]	'
Number of units	'
Outstanding, beginning of period	120,589
Units granted	53,375
Units vested	-44,430
Outstanding, end of period	116,599
Average grant date fair value per unit, granted	$23.11
Average grant date fair value per unit, vested	$23.09

EquityBased_Compensation_Phant

Equity-Based Compensation - Phantom Units (Details) (Phantom Share Units (PSUs) [Member])	9 Months Ended
	Sep. 30, 2014
Phantom Share Units (PSUs) [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Weighted average period over which the unrecognized cost are expected to be recognized	'1 year 8 months 23 days
Number of units	'
Outstanding, beginning of period	43,000
Units forfeited	-17,334
Outstanding, end of period	25,666
Units not expected to vest	-16,812

Derivative_Financial_Instrumen2

Derivative Financial Instruments - Commodity Contracts (Detail) (Swap [Member])	9 Months Ended
	Sep. 30, 2014
	Bbls
Period Covered-2014 [Member]	'
Derivative [Line Items]	'
Weighted Average Fixed Price	93.79
Total Bbls Hedged/day	2,446
Period Covered-2015 [Member]	'
Derivative [Line Items]	'
Weighted Average Fixed Price	93.29
Total Bbls Hedged/day	1,932
Period Covered-2016 [Member]	'
Derivative [Line Items]	'
Weighted Average Fixed Price	90.2
Total Bbls Hedged/day	82

Derivative_Financial_Instrumen3

Derivative Financial Instruments Restructured Commodity Contracts (Details) (Period Covered-2015 [Member], Swap [Member])	Jul. 31, 2014
	Bbls
Period Covered-2015 [Member] | Swap [Member]	'
Derivative Instruments and Hedging Activities Disclosures [Line Items]	'
Restructured swaps	123

Derivative_Financial_Instrumen4

Derivative Financial Instruments - Summary of Gross Fair Value by Appropriate Balance Sheet Classification (Detail) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Assets [Abstract]	'	'
Gross Amounts of Recognized Assets	$4,697	$589
Gross Amounts Offset in the Unaudited Consolidated Balance Sheet	29	388
Net financial assets	4,668	201
Liabilities [Abstract]	'	'
Gross Amounts of Recognized Liabilities	-29	-2,015
Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheet	-29	-388
Net Amounts of Liabilities Presented in the Unaudited Condensed Consolidated Balance Sheet	0	-1,627
Gross Amount of Recognized Assets and Liabilities	4,668	-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	4,668	-1,426
Current Asset [Member]	'	'
Assets [Abstract]	'	'
Gross Amounts of Recognized Assets	4,290	541
Gross Amounts Offset in the Unaudited Consolidated Balance Sheet	29	388
Net financial assets	4,261	153
Long Term Asset [Member]	'	'
Assets [Abstract]	'	'
Gross Amounts of Recognized Assets	407	48
Gross Amounts Offset in the Unaudited Consolidated Balance Sheet	0	0
Net financial assets	407	48
Current Liability [Member]	'	'
Liabilities [Abstract]	'	'
Gross Amounts of Recognized Liabilities	-29	-2,015
Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheet	-29	-388
Net Amounts of Liabilities Presented in the Unaudited Condensed Consolidated Balance Sheet	0	-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_Instrumen5

Derivative Financial Instruments - Impact of Derivative Financial Instruments within Condensed Consolidated Statement of Operations (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'	'
Net settlements on derivatives	($760)	($1,293)	($3,753)	$89
Gain (loss) on unsettled derivatives, net	10,040	-5,501	6,094	-6,334
Total gain on derivatives, net	$9,280	($6,794)	$2,341	($6,245)

Fair_Value_Disclosures_Additio

Fair Value Disclosures - Additional Information (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset Impairment Charges	$303	$0	$303	$1,578
Miscellaneous [Member]	'	'	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'	'	'
Asset Impairment Charges	$303	$0	$303	$1,578

Fair_Value_Disclosures_Assets_

Fair Value Disclosures - Assets and Liabilities Measured at Fair Value on Recurring Basis and Nonrecurring Basis (Detail) (USD $)	Sep. 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	$4,668	$201
Derivative Liability	0	-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	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	4,668	201
Derivative Liability	0	-1,627
Fair Value, Net Asset (Liability)	4,668	-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	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	303	1,578
Asset Retirement Obligations Fair Value Disc	$1,284	$879

Asset_Retirement_Obligations_C

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Detail) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Asset Retirement Obligation [Roll Forward]	'	'	'	'	'
Asset retirement obligation - beginning of period	'	'	$3,942	$2,890	$2,890
Liabilities incurred for new wells and interests	'	'	1,284	'	1,009
Revision of estimates	'	'	0	'	-130
Accretion expense	64	47	175	124	173
Asset retirement obligation - end of period	$5,401	'	$5,401	'	$3,942

Debt_Additional_Information_De

Debt - Additional Information (Detail) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2014	Aug. 29, 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	'	'	'	'	'	'
Senior secured revolving facility, expiring date	'	5-Nov-18	'	'	'	'	'	'
Line of Credit Facility, Current Borrowing Capacity	190,000,000	190,000,000	'	170,000,000	170,000,000	150,000,000	150,000,000	130,000,000
Deferred Finance Costs, Gross	'	'	100,000	'	100,000	'	400,000	'
Borrowings under the facility secure by liens	'	'not less than 80%	'	'	'	'	'	'
Revolving credit facility borrowings, outstanding	$168,000,000	$168,000,000	'	'	'	'	'	'
Minimum current ratio required under credit facility	'	1	'	'	'	'	'	'
Average effective rate	2.83%	'	'	'	'	'	'	'
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	'	400.00%	'	'	'	'	'	'
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 $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 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			9 Months Ended		0 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Aug. 11, 2014	15-May-14	Feb. 14, 2014	Sep. 30, 2014	Dec. 31, 2013	Oct. 22, 2014	Feb. 28, 2014	Aug. 31, 2014
						Distributions	Hugoton	Creek County
Equity [Line Items]	'	'	'	'	'	'	'	'
Owners Equity	'	'	'	23,337,511	19,319,362	'	'	'
Limited partnership interest	'	'	'	98.00%	'	'	'	'
Number of limited partner units issued to acquire oil properties	'	'	'	'	'	'	1,500,000	2,214,659
Cash distribution	'	'	'	'	'	$0.52	'	'
Cash distribution on annualized basis	'	'	'	'	'	$2.06	'	'
Distribution to unitholders, payment date	11-Aug-14	15-May-14	14-Feb-14	'	'	14-Nov-14	'	'
Distribution to unitholders, record date	'	'	'	'	'	3-Nov-14	'	'
Distribution to holders	'	'	'	'	'	$12.20	'	'

Equity_Summary_of_Cash_Distrib

Equity - Summary of Cash Distributions (Detail) (USD $)	0 Months Ended			9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Aug. 11, 2014	15-May-14	Feb. 14, 2014	Sep. 30, 2014
Equity [Abstract]	'	'	'	'
Date Paid	11-Aug-14	15-May-14	14-Feb-14	'
Period Covered	'April 1, 2014 - June 30, 2014	'January 1, 2014 - March 31, 2014	'October 1, 2013 - December 31, 2013	'
Distribution per Unit	$0.52	$0.52	$0.52	'
Total Distribution	$11,067	$11,032	$10,262	$32,361

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	3 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2014
Related Party Transaction [Line Items]	'	'
Direct administrative expenses incurred and reimbursed to related party	$0.80	$2.50
Mid-Con Energy Operating [Member]	'	'
Related Party Transaction [Line Items]	'	'
Other transactions of related party	6.7	6.7
Payment of joint interest billing	'	6.4
Payment of operating services	'	$0.30

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (USD $)

0 Months Ended

0 Months Ended

1 Months Ended

Aug. 11, 2014

15-May-14

Feb. 14, 2014

Sep. 30, 2014

Jun. 30, 2014

Apr. 11, 2014

Mar. 31, 2014

Nov. 30, 2013

Apr. 30, 2013

Oct. 22, 2014

Nov. 30, 2014

Nov. 05, 2014

Distributions

Forecast

Forecast

South Texas

South Texas

acre

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Cash distribution

'

'

'

'

'

'

'

'

'

$0.52

'

'

Cash distribution on annualized basis

'

'

'

'

'

'

'

'

'

$2.06

'

'

Distribution to unitholders, payment date

11-Aug-14

15-May-14

14-Feb-14

'

'

'

'

'

'

14-Nov-14

'

'

Distribution to unitholders, record date

'

'

'

'

'

'

'

'

'

3-Nov-14

'

'

Distribution to unit holders

'

'

'

'

'

'

'

'

'

$12,200,000

'

'

Net acres

'

'

'

'

'

'

'

'

'

'

18,000

'

Payments to Acquire Oil and Gas Property

'

'

'

'

'

'

'

'

'

'

120,000,000

'

Line of Credit Facility, Current Borrowing Capacity

'

'

'

190,000,000

170,000,000

170,000,000

150,000,000

150,000,000

130,000,000

'

'

240,000,000

Line of Credit Facility, Increase in Current Borrowing Capacity, Percent

'

'

'

'

'

'

'

'

'

'

'

26.00%

Term Loan

'

'

'

'

'

'

'

'

'

'

'

$100,000,000