Mid-Con Energy Partners (MCEP) 10-Q 2 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Aug. 02, 2017
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
Trading Symbol	MCEP
Entity Registrant Name	Mid-Con Energy Partners, LP
Entity Central Index Key	1,527,709
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding		30,091,463

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 486	$ 2,359
Accounts receivable:
Oil and natural gas sales	4,254	5,302
Other	83	233
Derivative financial instruments	348	0
Prepaids and other	288	512
Total current assets	5,459	8,406
Oil and natural gas properties, successful efforts method:
Proved properties	450,576	441,479
Other property and equipment	852	289
Accumulated depletion, depreciation, amortization and impairment	(203,723)	(176,551)
Total property and equipment, net	247,705	265,217
Derivative financial instruments	458	0
Other assets	1,983	2,663
Total Assets	255,605	276,286
Accounts payable:
Trade	257	256
Related parties	1,364	3,431
Derivative financial instruments	580	5,314
Accrued liabilities	498	146
Total current liabilities	2,699	9,147
Derivative financial instruments	0	2,495
Long-term debt	121,000	122,000
Other long term liabilities	81	93
Asset retirement obligations	12,119	11,331
Commitments and contingencies
Class A convertible preferred units - 11,627,906 issued and outstanding, respectively	19,970	19,570
Partnership equity
General partner interest	(376)	(248)
Limited partners- 29,944,796 and 29,912,230 units issued and outstanding, respectively	100,112	111,898
Total equity	99,736	111,650
Total liabilities, convertible preferred units and equity	$ 255,605	$ 276,286

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - shares	Jun. 30, 2017	Dec. 31, 2016
Statement Of Financial Position [Abstract]
Limited partners, units issued	29,944,796	29,912,230
Limited partners, units outstanding	29,944,796	29,912,230
Class A Convertible Preferred Units, shares issued	11,627,906	11,627,906
Class A Convertible Preferred Units, shares outstanding	11,627,906	11,627,906

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Revenues
Oil sales	$ 13,657	$ 14,447	$ 28,612	$ 25,553
Natural gas sales	288	330	684	493
Gain (loss) on derivatives, net	2,533	(10,088)	5,665	(7,520)
Total revenues	16,478	4,689	34,961	18,526
Operating costs and expenses
Lease operating expenses	5,581	5,777	10,573	11,842
Oil and natural gas production taxes	707	732	1,509	1,324
Impairment of proved oil and natural gas properties	17,672	895	17,672	895
Impairment of proved oil and natural gas properties sold	0	3,578	0	3,578
Depreciation, depletion and amortization	4,631	5,800	9,500	11,885
Accretion of discount on asset retirement obligations	136	159	244	316
General and administrative	1,471	1,478	3,297	3,566
Total operating costs and expenses	30,198	18,419	42,795	33,406
Gain on sale of oil and natural gas properties, net	0	13	0	13
Loss from operations	(13,720)	(13,717)	(7,834)	(14,867)
Other (expense) income
Interest income	2	2	5	5
Interest expense	(1,539)	(2,054)	(2,989)	(4,253)
Other income	66	0	66	33
Loss on settlements of asset retirement obligations	(8)	0	(5)	0
Total other expense	(1,479)	(2,052)	(2,923)	(4,215)
Net loss	(15,199)	(15,769)	(10,757)	(19,082)
Less: Distributions to preferred unitholders	694	0	1,492	0
Less: General partner's interest in net loss	(181)	(188)	(128)	(227)
Limited partners' interest in net loss	$ (15,712)	$ (15,581)	$ (12,121)	$ (18,855)
Limited partners' interest in net loss per unit:
Basic and diluted	$ (0.52)	$ (0.52)	$ (0.40)	$ (0.63)
Weighted average limited partner units outstanding:
Limited partner units (basic and diluted)	29,945	29,785	29,936	29,777

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash Flows from Operating Activities:
Net loss	$ (10,757)	$ (19,082)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion and amortization	9,500	11,885
Debt issuance costs amortization	680	674
Accretion of discount on asset retirement obligations	244	316
Impairment of proved oil and natural gas properties	17,672	895
Impairment of proved oil and natural gas properties sold	0	3,578
Loss on settlements of asset retirement obligations	5	0
Cash paid for settlements of asset retirement obligations	(21)
(Gain) loss on derivatives, net	(5,665)	7,520
Cash settlements received for matured derivatives	201	17,285
Cash premiums paid for derivatives, net	(2,571)	(2,257)
Gain on sale of oil and natural gas properties	0	(13)
Non-cash equity-based compensation	335	650
Changes in operating assets and liabilities:
Accounts receivable	1,048	(682)
Other receivables	150	3,822
Prepaids and other	224	146
Accounts payable - trade and accrued liabilities	308	1,032
Accounts payable - related parties	(2,027)	(870)
Net cash provided by operating activities	9,326	24,899
Cash Flows from Investing Activities:
Acquisitions of oil and natural gas properties	(4,666)
Additions to oil and natural gas properties	(4,341)	(3,495)
Additions to other property and equipment	(133)
Proceeds from sale of oil and natural gas properties		7
Net cash used in investing activities	(9,140)	(3,488)
Cash Flows from Financing Activities:
Proceeds from line of credit	4,000
Payments on line of credit	(5,000)	(17,982)
Offering costs	(59)	(16)
Debt issuance costs		(9)
Distributions to Class A convertible preferred units	(1,000)
Net cash used in financing activities	(2,059)	(18,007)
Net (decrease) increase in cash and cash equivalents	(1,873)	3,404
Beginning cash and cash equivalents	2,359	615
Ending cash and cash equivalents	$ 486	$ 4,019

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Changes in Equity - 6 months ended Jun. 30, 2017 - USD ($) shares in Thousands, $ in Thousands	Total	General Partner	Limited Partner
Balance at Dec. 31, 2016	$ 111,650	$ (248)	$ 111,898
Balance, Units at Dec. 31, 2016			29,912
Increase (Decrease) in Partners' Capital [Roll Forward]
Equity-based compensation	335		$ 335
Equity-based compensation, Units			33
Distributions to Class A convertible preferred units	(1,000)		$ (1,000)
Accretion of beneficial conversion feature of Class A convertible preferred units	(492)		(492)
Net loss	(10,757)	(128)	(10,629)
Balance at Jun. 30, 2017	$ 99,736	$ (376)	$ 100,112
Balance, Units at Jun. 30, 2017			29,945

Organization and Nature of Oper

Organization and Nature of Operations	6 Months Ended
	Jun. 30, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Organization and Nature of Operations	Note 1. Organization and Nature of Operations Nature of Operations Mid-Con Energy Partners, LP (“we,” “our,” “us,” the “Partnership,” or the “Company”) is a publicly held Delaware limited partnership formed in July 2011 that engages in the ownership, acquisition, exploitation and development of producing oil and natural gas properties in North America, with a focus on enhanced oil recovery (“EOR”). Our common units representing limited partner interests in us (“common units”) are listed on the National Association of Securities Dealers Automated Quotation System Global Select Market (“NASDAQ”) 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 are 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, 2016, 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 made are adequate to make the information not misleading. The unaudited condensed consolidated financial statements include 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. All intercompany transactions and account balances have been eliminated. Reclassifications Certain amounts in the financial statements for the prior years have been reclassified to conform to the 2017 presentation. These reclassifications have no impact on previously reported total assets, total liabilities, net income (loss) or total operating cash flows. Non-cash Investing, Financing and Supplemental Cash Flow Information The following presents the non-cash investing, financing and supplemental cash flow information for the periods presented: Six Months Ended June 30, 2017 2016 (in thousands) Non-cash investing and financing information: Change in oil and natural gas properties - accrued capital expenditures $ (40 ) $ (379 ) Supplemental cash flow information: Cash paid for interest $ 2,305 $ 3,700

Acquisitions and Divestitures

Acquisitions and Divestitures	6 Months Ended
	Jun. 30, 2017
Business Combinations [Abstract]
Acquisitions and Divestitures	Note 2. Acquisitions and Divestitures Acquisitions Acquisitions are accounted for under the acquisition method of accounting. The assets acquired and liabilities assumed in acquisitions are recorded in our unaudited condensed consolidated balance sheets at their estimated fair values as of the acquisition date using assumptions that represent Level 3 fair value measurement inputs. See Note 5 in this section for additional discussion of our fair value measurements. Results of operations attributable to the acquisition subsequent to the closing are included in our unaudited condensed consolidated statements of operations. Permian Bolt-On In August 2016, we acquired multiple oil and natural gas properties located in Nolan County, Texas (the “Permian Bolt-On”) for cash consideration of approximately $18.7 million, after post-closing purchase price adjustments. The transaction was funded by a private offering of $25.0 million Class A Convertible Preferred Units (“Preferred Units”). See Note 9 in this section for additional information regarding the issuance of Preferred Units. The recognized fair values of the assets acquired and liabilities assumed are as follows (in thousands): Fair value of net assets acquired: Oil and natural gas properties $ 19,323 Total assets acquired 19,323 Fair value of net liabilities assumed: Asset retirement obligation 622 Net assets acquired $ 18,701 Wheatland In June 2017, we acquired multiple oil and natural gas properties located in Oklahoma County and Cleveland County, Oklahoma (“Wheatland”) for cash consideration of approximately $4.2 million, prior to post-closing purchase price adjustments. The recognized fair values of the assets acquired and liabilities assumed are as follows (in thousands): Fair value of net assets acquired: Oil and natural gas properties $ 4,465 Other property and equipment 127 Total assets acquired 4,592 Fair value of net liabilities assumed: Asset retirement obligation 407 Net assets acquired $ 4,185 Divestitures Hugoton In July 2016, we sold the properties located in our Hugoton core area for cash proceeds of approximately $17.6 million, including post-closing purchase price adjustments and recognized a loss of approximately $0.6 million. Additionally, we recorded impairment of proved oil and natural gas properties of approximately $3.6 million when these properties were originally reported as held for sale. For the three months ended June 30, 2016, our unaudited condensed consolidated statements of operations included revenues of approximately $1.8 million $5.3 million $3.0 million $7.1 million

Equity Awards

Equity Awards	6 Months Ended
	Jun. 30, 2017
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Equity Awards	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”) and ME3 Oilfield Service, LLC (“ME3 Oilfield Service”), 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. The Long-Term Incentive Program is administered by Charles R. Olmstead, Executive Chairman of the Board, and Jeffrey R. Olmstead, President and Chief Executive Officer, and approved by the Board of Directors of our general partner (the “Board”). We account for unrestricted, restricted and equity-settled phantom unit awards as equity awards since they are settled by issuing common units. 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. On January 1, 2017, we adopted ASU 2016-09 Compensation - Stock Compensation : Improvements to Employee Share-Based Payment Accounting The following table shows the number of existing awards and awards available under the Long-Term Incentive Program at June 30, 2017: Number of Common Units Approved and authorized awards 3,514,000 Unrestricted units granted (1,212,706 ) Restricted units granted, net of forfeitures (400,424 ) Equity-settled phantom units granted, net of forfeitures (456,500 ) Awards available for future grant 1,444,370 We recognized approximately $0.1 million and $0.3 million of total equity-based compensation expense for the three and six months ended June 30, 2017, respectively, and we recognized approximately $0.3 million and $0.7 million of total equity-based compensation expense for the three and six months ended June 30, 2016, respectively. These costs are reported as a component of general and administrative expenses (“G&A”) in our unaudited condensed consolidated statements of operations. Unrestricted Unit Awards During the six months ended June 30, 2017, we granted 25,400 unrestricted units with an average grant date fair value of $2.65 per unit. During the six months ended June 30, 2016, we granted 70,000 unrestricted units with an average grant date fair value of $1.16 per unit. Restricted Unit Awards Restricted units vest over a two- or three-year period. As of June 30, 2017, there were approximately $0.04 million of unrecognized compensation costs related to non-vested restricted units. These costs are expected to be recognized over a weighted average period of approximately five months. A summary of our restricted unit awards for the six months ended June 30, 2017, is presented below: Number of Restricted Units Average Grant Date Fair Value per Unit Outstanding at December 31, 2016 76,922 $ 5.67 Units granted — — Units vested (66,030 ) 4.96 Units forfeited — — Outstanding at June 30, 2017 10,892 $ 9.99 Equity-Settled Phantom Unit Awards Equity-settled phantom units vest over a two- or three-year period and do not have any rights or privileges of a common unitholder, including right to distributions, until vesting and the resulting conversion into common units. During the six months ended June 30, 2017, we granted 9,000 equity-settled phantom units with a three-year vesting period. During the six months ended June 30, 2016, we granted 24,500 equity-settled phantom units with one-third vesting immediately and the other two-thirds vesting over two years. As of June 30, 2017, there were approximately $0.2 million of unrecognized compensation costs related to non-vested equity-settled phantom units. These costs are expected to be recognized over a weighted average period of approximately one year, three months. A summary of our equity-settled phantom unit awards for the six months ended June 30, 2017, is presented below: Number of Equity- Settled Phantom Units Average Grant Date Fair Value per Unit Outstanding at December 31, 2016 287,659 $ 1.64 Units granted 9,000 2.65 Units vested (7,166 ) 1.16 Units forfeited (10,000 ) 2.94 Outstanding at June 30, 2017 279,493 $ 1.64

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2017
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	Note 4. 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 commodity derivative contracts (swaps, calls, puts and collars) to manage a portion of our exposure to commodity prices and specific delivery points. We enter into commodity derivative contracts or modify our portfolio of existing commodity derivative contracts when we believe market conditions or other circumstances suggest that it is prudent to do so, or as required by our lenders. These contracts are presented as derivative financial instruments on our unaudited condensed consolidated financial statements. We account for our commodity derivative contracts at fair value. See Note 5 in this section for a description of our fair value measurements. We do not designate derivatives as hedges for accounting purposes; therefore, the mark-to-market adjustment reflecting the change in the fair value of our commodity derivative contracts is recorded in current period earnings. When prices for oil are volatile, a significant portion of the effect of our hedging activities consists of non-cash gains or losses due to changes in the fair value of our commodity derivative contracts. In addition to mark-to-market adjustments, gains or losses arise from net payments made or received on monthly settlements, proceeds from or payments for termination of contracts prior to their expiration and premiums paid or received for new contracts. Any deferred premiums are recorded as a liability and recognized in earnings as the related contracts mature. Gains and losses on derivatives are included in cash flows from operating activities. Pursuant to the accounting standard that permits netting of assets and liabilities where the right of offset exists, we present the fair value of commodity derivative contracts on a net basis. At June 30, 2017, our commodity derivative contracts were in a net asset position with a fair value of approximately $0.2 million and at December 31, 2016, a net liability position with a fair value of approximately $7.8 million. All of our commodity derivative contracts are with major financial institutions that are also lenders under our revolving credit facility. Should one of these financial counterparties not perform, we may not realize the benefit of some of our commodity derivative contracts under lower commodity prices and we could incur a loss. As of June 30, 2017, all of our counterparties have performed pursuant to the terms of their commodity derivative contracts. The following tables summarize the gross fair value by the appropriate balance sheet classification, even when the derivative financial instruments are subject to netting arrangements and qualify for net presentation, in our unaudited condensed consolidated balance sheets at June 30, 2017, and December 31, 2016: Gross Amounts Recognized Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheets Net Amounts Presented in the Unaudited Condensed Consolidated Balance Sheets (in thousands) June 30, 2017: Assets Derivative financial instruments - current asset $ 2,516 $ (2,168 ) $ 348 Derivative financial instruments - long-term asset 948 (490 ) 458 Total 3,464 (2,658 ) 806 Liabilities Derivative financial instruments - current liability (271 ) (309 ) (580 ) Derivative deferred premium - current liability (2,477 ) 2,477 — Derivative financial instruments - long-term liability (89 ) 89 — Derivative deferred premium - long-term liability (401 ) 401 — Total (3,238 ) 2,658 (580 ) Net Asset $ 226 $ — $ 226 Gross Amounts Recognized Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheets Net Amounts Presented in the Unaudited Condensed Consolidated Balance Sheets (in thousands) December 31, 2016: Assets Derivative financial instruments - current asset $ 1,570 $ (1,570 ) $ — Derivative financial instruments - long-term asset 406 (406 ) — Total 1,976 (1,976 ) — Liabilities Derivative financial instruments - current liability (1,836 ) (3,478 ) (5,314 ) Derivative deferred premium - current liability (5,048 ) 5,048 — Derivative financial instruments - long-term liability (2,500 ) 5 (2,495 ) Derivative deferred premium - long-term liability (401 ) 401 — Total (9,785 ) 1,976 (7,809 ) Net Liability $ (7,809 ) $ — $ (7,809 ) The following table presents the impact of derivative financial instruments and their location within the unaudited condensed consolidated statements of operations: Three Months Ended Six Months Ended June 30, June 30, 2017 2016 2017 2016 (in thousands) Net settlements on matured derivatives (1) $ 357 $ 6,191 $ 201 $ 17,285 Net change in fair value of derivatives 2,176 (16,279 ) 5,464 (24,805 ) Total gain (loss) on derivatives, net $ 2,533 $ (10,088 ) $ 5,665 $ (7,520 ) (1) . At June 30, 2017, and December 31, 2016, our commodity derivative contracts had maturities at various dates through December 2019 and were comprised of commodity price put and collar contracts. At June 30, 2017, we had the following oil derivatives net positions: Period Covered Weighted Average Floor Price Weighted Average Ceiling Price Total Bbls Hedged/day NYMEX Index Collars - 2017 45.00 51.78 652 WTI Puts - 2017 50.00 — 1,875 WTI Collars - 2018 44.38 55.52 1,315 WTI Puts - 2018 45.00 — 164 WTI Collars - 2019 50.00 60.52 427 WTI At December 31, 2016, we had the following oil derivatives net positions: Period Covered Weighted Average Floor Price Weighted Average Ceiling Price Total Bbls Hedged/day NYMEX Index Collars - 2017 $ 43.75 $ 50.68 658 WTI Puts - 2017 $ 50.00 $ — 1,932 WTI Collars - 2018 $ 44.38 $ 55.52 1,315 WTI Puts - 2018 $ 45.00 $ — 164 WTI Collars - 2019 $ 50.00 $ 60.52 427 WTI

Fair Value Disclosures

Fair Value Disclosures	6 Months Ended
	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Fair Value Disclosures	Note 5. Fair Value Disclosures Fair Value of Financial Instruments The carrying amounts reported in our unaudited condensed consolidated balance sheets for cash, accounts receivable and accounts payable approximate their fair values. The carrying amount of 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 commodity derivative contracts at fair value as discussed in “Assets and Liabilities Measured at Fair Value on a Recurring Basis” below. 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). 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. We consider active markets to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an on-going basis. 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 2 instruments primarily include swap, call, put and collar contracts. Level 3 —Financial assets and liabilities for which values are based on prices or valuation approaches 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. We had no transfers in or out of Levels 1, 2 or 3 at June 30, 2017, and December 31, 2016. 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 material changes in valuation approach or related inputs for the six months ended June 30, 2017, and for the year ended December 31, 2016. Assets and Liabilities Measured at Fair Value on a Recurring Basis We account for commodity derivative contracts and their corresponding deferred premiums at fair value on a recurring basis utilizing certain pricing models. 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. The Partnership’s deferred premiums associated with its commodity derivative contracts are categorized as Level 3, as the Partnership utilizes a net present value calculation to determine the valuation. See Note 4 in this section for a summary of our derivative financial instruments. The following sets forth, by level within the hierarchy, the fair value of our assets and liabilities measured at fair value on a recurring basis as of June 30, 2017, and December 31, 2016: Level 1 Level 2 Level 3 Fair Value (in thousands) June 30, 2017 Assets and Liabilities Measured at Fair Value on a Recurring Basis Derivative financial instruments - asset $ — $ 3,464 $ — $ 3,464 Derivative financial instruments - liability $ — $ 360 $ — $ 360 Derivative deferred premiums - liability $ — $ — $ 2,878 $ 2,878 December 31, 2016 Assets and Liabilities Measured at Fair Value on a Recurring Basis Derivative financial instruments - asset $ — $ 1,976 $ — $ 1,976 Derivative financial instruments - liability $ — $ 4,336 $ — $ 4,336 Derivative deferred premiums - liability $ — $ — $ 5,449 $ 5,449 A summary of the changes in Level 3 fair value measurements for the periods presented are as follows: Six Months Ended Year Ended June 30, 2017 December 31, 2016 (in thousands) Balance of Level 3 at beginning of period $ (5,449 ) $ (9,973 ) Derivative deferred premiums - purchases — (516 ) Derivative deferred premiums - settlements 2,571 5,040 Balance of Level 3 at end of period $ (2,878 ) $ (5,449 ) Assets and Liabilities Measured at Fair Value on a Non-recurring Basis Asset Retirement Obligations We estimate the fair value of our Asset Retirement Obligations (“ARO”) based on discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for ARO, amounts and timing of settlements, the credit-adjusted risk-free rate to be used and inflation rates. See Note 6 in this section for a summary of changes in ARO. Acquisitions The estimated fair values of proved oil and natural gas properties acquired in business combinations are based on a discounted cash flow model and market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates and risk-adjusted discount rates. Based on the unobservable nature of certain of the inputs, the estimated fair value of the oil and natural gas properties acquired is deemed to use Level 3 inputs. See Note 2 in this section for further discussion of the Partnership’s acquisitions. Reserves We calculate the estimated fair values of reserves and properties using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount. Significant inputs used to determine the fair values of proved properties include estimates of reserves, future operating and developmental costs, future commodity prices, a market-based weighted average cost of capital rate and the rate at which future cash flows are discounted to estimate present value. We discount future values by a per annum rate of 10%. We believe this rate approximates our long-term cost of capital and accordingly, is well aligned with our internal business decisions. The underlying commodity prices embedded in our estimated cash flows begin with Level 1 NYMEX-WTI forward curve pricing, less Level 3 assumptions that include location, pricing adjustments and quality differentials. Impairment The need to test an asset for impairment may result from significant declines in sales prices or downward revisions in estimated quantities of oil and natural gas reserves. If the carrying value of the long-lived assets exceeds the estimated undiscounted future net cash flows, an impairment loss is recognized for the difference between the estimated fair value and the carrying value of the assets. For the three and six months ended June 30, 2017, we recorded a non-cash impairment expense of approximately $ 17.7

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 6. Asset Retirement Obligations We have obligations under our lease agreements and federal regulations to remove equipment and restore land at the end of oil and natural gas operations. These ARO are primarily associated with plugging and abandoning wells. We typically incur this liability upon acquiring or drilling a well and determine our ARO by calculating the present value of estimated cash flow related to the estimated future liability. Determining the removal and future restoration obligation requires management to make estimates and judgments, including the ultimate settlement amounts, inflation factors, credit adjusted risk-free rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. We are required to record the fair value of a liability for the ARO in the period in which it is incurred with a corresponding increase in the carrying amount of the related long-lived asset. We review our assumptions and estimates of future ARO on an annual basis, or more frequently, if an event or circumstances occur that would impact our assumptions. To the extent future revisions to these assumptions impact the present value of the abandonment liability, management will make corresponding adjustments to both the ARO and the related oil and natural gas property asset balance. The liability is accreted each period toward its future value and is recorded in our unaudited condensed consolidated statements 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. Upon settlement of the liability, a gain or loss is recognized to the extent the actual costs differ from the recorded liability. As of June 30, 2017, and December 31, 2016, our ARO were reported as “Asset retirement obligations” in our unaudited condensed consolidated balance sheets. Changes in our ARO for the periods indicated are presented in the following table: Six Months Ended Year Ended June 30, 2017 December 31, 2016 (in thousands) Asset retirement obligations - beginning of period $ 11,331 $ 12,679 Liabilities incurred for new wells and interest 636 747 Liabilities settled upon plugging and abandoning wells (17 ) — Liabilities removed upon sale of wells — (2,827 ) Revision of estimates (75 ) 155 Accretion expense 244 577 Asset retirement obligations - end of period $ 12,119 $ 11,331

Debt

Debt	6 Months Ended
	Jun. 30, 2017
Debt Disclosure [Abstract]
Debt	Note 7. Debt We had outstanding borrowings under our revolving credit facility of $121.0 million and $122.0 million at June 30, 2017, and December 31, 2016, respectively. Our revolving credit facility matures in November 2018. The borrowing base of our revolving credit facility is collectively determined by our 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 in the spring and fall of each year with an additional redetermination, either at our request or at the request of the lenders, during the period between each scheduled borrowing base redetermination. 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. Borrowings under the revolving credit facility bear interest at a floating rate based on, at our election, the greater of the prime rate of Wells Fargo Bank, National Association, the federal funds effective rate plus 0.50% and the one month adjusted London Interbank Offered Rate (“LIBOR”) plus 1.0%, all of which are subject to a margin that varies from 1.00% to 2.75% 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 the applicable LIBOR plus a margin that varies from 2.00% to 3.75% per annum according to the borrowing base usage. For the three months ended June 30, 2017, the average effective rate was approximately 3.81% 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. The revolving credit facility includes customary affirmative and negative covenants, such as limitations on the creation of new indebtedness and on certain liens, leverage ratios and restrictions on certain transactions and payments, including distributions. 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 these covenants as of and during the six months ended June 30, 2017. During the spring 2016 semi-annual redetermination and amendment to the credit agreement completed in May 2016, the effective borrowing base as of June 1, 2016, was reduced to $163.0 million and was comprised of a $110.0 million conforming tranche and a permitted overadvance of $53.0 million. The permitted overadvance was scheduled to mature on November 1, 2016. During August 2016, we completed a non-scheduled redetermination and amendment to the credit agreement in conjunction with our Permian Bolt-On acquisition. Among other changes, this amendment to the credit agreement increased the conforming borrowing base of the Partnership’s revolving credit facility to $140.0 million as of August 11, 2016, modified the definition of “Indebtedness” to exclude the Preferred Units and modified the limitations on restricted payments to specifically provide for the payment of cash distributions on the Preferred Units. The amendment also required that by August 18, 2016, we enter into commodity derivative contracts of not less than 75% of our 2017 projected monthly production and not less than 50% of our 2018 projected monthly production, calculated based on proved developed producing reserves at the time of the agreement. These requirements were satisfied with the execution of additional commodity derivative contracts maturing in 2018. The amendment also required that within 30 days we extend our collateral coverage to include the reserves acquired in the Permian Bolt-On acquisition. During the fall 2016 semi-annual borrowing base redetermination of our revolving credit facility completed in October 2016, the lender group reaffirmed the existing conforming borrowing base of $140.0 million effective October 28, 2016. There were no changes to the terms or conditions of the credit agreement. During the spring 2017 semi-annual borrowing base redetermination of our revolving credit facility completed in May 2017, the lender group reaffirmed the Partnership’s $140.0 million conforming borrowing base effective May 24, 2017. There were no changes to the terms or conditions of the credit agreement. The next regularly scheduled borrowing base redetermination will occur on or about October 31, 2017.

Commitment and Contingencies

Commitment and Contingencies	6 Months Ended
	Jun. 30, 2017
Commitments And Contingencies Disclosure [Abstract]
Commitment and Contingencies	Note 8. Commitments and Contingencies Leases We lease corporate office space in Tulsa, Oklahoma and Abilene, Texas. We were also allocated office rent from Mid-Con Energy Operating through August 2016 for office space in Dallas, Texas. Total lease expenses were approximately $0.1 million Future minimum lease payments under the non-cancellable operating leases are presented in the following table (in thousands): Remaining 2017 244 2018 490 2019 413 2020 418 2021 423 Total $ 1,988 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. 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. See Note 10 in this section for additional information. Employment Agreements Our general partner has entered into employment agreements with Charles R. Olmstead, Executive Chairman of the Board and Jeffrey R. Olmstead, President and Chief Executive Officer. The employment agreements automatically renew for one-year terms on August 1st of each year unless either we or the employee gives written notice of termination by at least the preceding February. 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 may specify from time to time, in roles consistent with such positions that are assigned to them. 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 $0.4 million to $0.7 million, including the value of vesting of any outstanding units. Legal We are party to various claims, legal actions and complaints arising in the ordinary course of business. In the opinion of management and our General Counsel, 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.

Equity

Equity	6 Months Ended
	Jun. 30, 2017
Equity [Abstract]
Equity	Note 9. Equity Common Units At June 30, 2017, and December 31, 2016, the Partnership’s equity consisted of 29,944,796 On May 5, 2015, we entered into an Equity Distribution Agreement to sell, from time to time through or to the Managers (as defined in the agreement), up to $50.0 million in common units representing limited partner interests. In connection with the Preferred Units purchase agreement described below, the Partnership suspended sales of common units pursuant to the Equity Distribution Agreement effective as of the closing date of the issuance of the Preferred Units until the fifth anniversary thereof, unless the Partnership obtains the consent of a majority of the holders of the outstanding Preferred Units. Our partnership agreement requires us to distribute all of our available cash on a quarterly basis. Our available cash is our cash on hand at the end of a quarter after the payment of our expenses and the establishment of reserves for future capital expenditures and operational needs, including cash from working capital borrowings. There is no assurance as to the future cash distributions since they are dependent upon our projections for future earnings, cash flows, capital requirements, financial conditions and other factors. As of June 30, 2017, cash distributions to our common units continued to be indefinitely suspended. Our credit agreement stipulates written consent from our lenders is required in order to reinstate common unit distributions and also prohibits us from making common unit cash distributions if any potential default or event of default, as defined in the credit agreement, occurs or would result from the cash distribution. Management and the Board will continue to evaluate, on a quarterly basis, the appropriate level of cash reserves in determining future distributions. The suspension of common unit cash distributions is designed to preserve liquidity and reallocate excess cash flow towards capital expenditure projects and debt reduction to maximize long-term value for our unitholders. Preferred Units On August 11, 2016, we completed a private placement of 11,627,906 Preferred Units for an aggregate offering price of $25.0 million. The Preferred Units were issued at a price of $2.15 per Preferred Unit (the “Unit Purchase Price”). Proceeds from this issuance were used to fund the Permian Bolt-On acquisition and for general partnership purposes, including the reduction of borrowings under our revolving credit facility. We received net proceeds of approximately $24.6 million (net of issuance costs of approximately $0.4 million) in connection with the issuance of Preferred Units. We allocated these net proceeds, on a relative fair value basis, to the Preferred Units (approximately $18.6 million) and the beneficial conversion feature (approximately $6.0 million). A beneficial conversion feature is defined as a non-detachable conversion feature that is in the money at the commitment date. Per accounting guidance, we are required to allocate a portion of the proceeds from the Preferred Units to the beneficial conversion feature based on the intrinsic value of the beneficial conversion feature. The intrinsic value is calculated at the commitment date based on the difference between the fair value of the common units at the issuance date (number of common units issuable at conversion multiplied by the per-share value of our common units at the issuance date) and the proceeds attributed to the Preferred Units. We record the accretion attributed to the beneficial conversion feature as a deemed distribution using the effective interest method over the five year period prior to the effective date of the holders conversion right. Accretion of the beneficial conversion feature was approximately $0.2 million and $0.5 million for the three and six months ended June 30, 2017. The holders of our Preferred Units are entitled to certain rights that are senior to the rights of holders of common units, such as rights to distributions and rights upon liquidation of the Partnership. We pay holders of the Preferred Units a cumulative, quarterly cash distribution on all Preferred Units then outstanding at an annual rate of 8.0%, or in the event that the Partnership’s existing secured indebtedness prevents the payment of a cash distribution to all holders of the Preferred Units, in kind (additional Preferred Units), at an annual rate of 10.0%. Such distributions will be paid for each such quarter within 45 days after such quarter end. As of June 30, 2017, all Preferred Unit distributions have been paid in cash. No payment or distribution on common units for any quarter is permitted prior to the payment in full of the Preferred Units distribution (including any outstanding arrearages). At June 30, 2017, the Partnership had accrued approximately $0.5 million for the second quarter 2017 dividends that are to be paid in August 2017. The following table summarizes cash distributions paid on our Preferred Units during the six months ended June 30, 2017: Date Paid Period Covered Distribution per Unit Total Distributions (in thousands) February 14, 2017 October 1, 2016 - December 31, 2016 $ 0.043 $ 500 May 15, 2017 January 1, 2017 - March 31, 2017 $ 0.043 $ 500 Prior to the five year anniversary of the closing date, each holder of the Preferred Units has the right, subject to certain conditions, to convert all or a portion of their Preferred Units into common units representing limited partner interests in the Partnership on a one-for-one basis, subject to adjustment for splits, subdivisions, combinations and reclassifications of the common units. Upon conversion of Preferred Units, the Partnership will pay any distributions (to the extent accrued and unpaid as of the then most recent Preferred Units distribution date) on the converted units in cash. Under the registration rights agreements entered into in connection with the Preferred Units issuance, we were required to use reasonable best efforts to file, within 90 days of the closing date, a registration statement registering resales of common units issued or to be issued upon conversion of the Preferred Units and have the registration statement declared effective within 180 days after the closing date. On June 14, 2017, the previously filed shelf registration statement on Form S-3 was declared effective by the SEC. Allocation of Net Income (Loss) Net income (loss), net of distributions on the Preferred Units and amortization of the Preferred Unit’s beneficial conversion feature (see Preferred Units section), is allocated between our general partner and the limited partner unitholders in proportion to their pro rata ownership (exclusive of the Preferred Units limited partnership interest) during the period. The allocation of net income (loss) is presented in our unaudited condensed consolidated statements of operations. In the event of net income, diluted net income per partner unit reflects the potential dilution of non-vested restricted stock awards and the conversion of Preferred Units.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
Related Party Transactions	Note 10. Related Party Transactions Agreements with Affiliates 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 our affiliate, 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. These expenses are included in G&A in our unaudited condensed consolidated statements of operations. Operating Agreements We, various third parties with an ownership interest in the same property and our affiliate, Mid-Con Energy Operating, are parties to standard oil and natural gas joint operating agreements, pursuant to which we and those third parties pay Mid-Con Energy Operating overhead associated with operating our properties. We and those third parties also pay Mid-Con Energy Operating for its direct and indirect expenses that are chargeable to the wells under their respective operating agreements. The majority of these expenses are included in lease operating expenses (“LOE”) in our unaudited condensed consolidated statements of operations. Oilfield Services We are party to operating agreements, pursuant to which our affiliate, Mid-Con Energy Operating, bills us for oilfield services performed by our affiliate, ME3 Oilfield Service. These amounts are either included in LOE in our unaudited condensed consolidated statements of operations or are capitalized as part of oil and natural gas properties in our unaudited condensed consolidated balance sheets. The following table summarizes the affiliates’ transactions for the periods indicated: Three Months Ended Six Months Ended June 30, June 30, 2017 2016 2017 2016 (in thousands) Amounts paid for: Services agreement $ 652 $ 706 $ 1,293 $ 1,526 Operating agreements 1,613 1,616 3,016 3,281 Oilfield services 857 825 1,667 1,496 $ 3,122 $ 3,147 $ 5,976 $ 6,303 At June 30, 2017, we had a payable to our affiliate, Mid-Con Energy Operating, of approximately $1.4 million, comprised of a joint interest billing payable of approximately $1.2 million and a payable for operating services of approximately $0.2 million. At December 31, 2016, we had a payable to our affiliate, Mid-Con Energy Operating, of approximately $3.4 million, comprised of a joint interest billing payable of approximately $2.8 million and a payable for operating services of approximately $0.6 million. These amounts were included in accounts payable-related parties in our unaudited condensed consolidated balance sheets.

New Accounting Standards

New Accounting Standards	6 Months Ended
	Jun. 30, 2017
Accounting Changes And Error Corrections [Abstract]
New Accounting Standards	Note 11. New Accounting Standards In May 2014, the Financial Accounting Standards Board (“FASB”) issued a comprehensive new revenue recognition standard that supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, Extractive Activities-Oil and Gas-Revenue Recognition In February 2016, the FASB issued ASU No. 2016-02, “ Leases In August, 2016, the FASB issued Accounting Standards Update No. 2016-15, Classification of Certain Cash Receipts and Cash Payments

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2017
Subsequent Events [Abstract]
Subsequent Events	Note 12. Subsequent Events Distributions The Board declared a Preferred Unit cash distribution for the second quarter of 2017, according to terms outlined in the Partnership Agreement. A cash distribution of $0.043 per Preferred Unit, or approximately $0.5 million in aggregate, will be paid on August 14, 2017, to holders of record as of the close of business on August 7, 2017. Equity Awards Issuance On July 26, 2017, the Board of Directors authorized the issuance of 32,500 equity-settled phantom units, with 27,000 subject to a two-year vesting period and 5,500 subject to a three-year vesting period.

Organization and Nature of Op19

Organization and Nature of Operations (Policies)	6 Months Ended
	Jun. 30, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Basis of Presentation	Basis of Presentation Our unaudited condensed consolidated financial statements are 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, 2016, 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 made are adequate to make the information not misleading. The unaudited condensed consolidated financial statements include 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. All intercompany transactions and account balances have been eliminated. Reclassifications Certain amounts in the financial statements for the prior years have been reclassified to conform to the 2017 presentation. These reclassifications have no impact on previously reported total assets, total liabilities, net income (loss) or total operating cash flows.

Organization and Nature of Op20

Organization and Nature of Operations (Tables)	6 Months Ended
	Jun. 30, 2017
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Schedule of Cash Flow Supplemental Disclosures	The following presents the non-cash investing, financing and supplemental cash flow information for the periods presented: Six Months Ended June 30, 2017 2016 (in thousands) Non-cash investing and financing information: Change in oil and natural gas properties - accrued capital expenditures $ (40 ) $ (379 ) Supplemental cash flow information: Cash paid for interest $ 2,305 $ 3,700

Acquisitions and Divestitures A

Acquisitions and Divestitures Acquisition and Divestiture (Tables)	6 Months Ended
	Jun. 30, 2017
Permian Bolt On [Member]
Acquisitions Of Oil Properties	The recognized fair values of the assets acquired and liabilities assumed are as follows (in thousands): Fair value of net assets acquired: Oil and natural gas properties $ 19,323 Total assets acquired 19,323 Fair value of net liabilities assumed: Asset retirement obligation 622 Net assets acquired $ 18,701
Wheatland [Member]
Acquisitions Of Oil Properties	The recognized fair values of the assets acquired and liabilities assumed are as follows (in thousands): Fair value of net assets acquired: Oil and natural gas properties $ 4,465 Other property and equipment 127 Total assets acquired 4,592 Fair value of net liabilities assumed: Asset retirement obligation 407 Net assets acquired $ 4,185

Equity Awards (Tables)

Equity Awards (Tables)	6 Months Ended
	Jun. 30, 2017
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Summary of awards 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, 2017: Number of Common Units Approved and authorized awards 3,514,000 Unrestricted units granted (1,212,706 ) Restricted units granted, net of forfeitures (400,424 ) Equity-settled phantom units granted, net of forfeitures (456,500 ) Awards available for future grant 1,444,370
Summary of restricted units awarded	A summary of our restricted unit awards for the six months ended June 30, 2017, is presented below: Number of Restricted Units Average Grant Date Fair Value per Unit Outstanding at December 31, 2016 76,922 $ 5.67 Units granted — — Units vested (66,030 ) 4.96 Units forfeited — — Outstanding at June 30, 2017 10,892 $ 9.99
Summary of equity-settled units	A summary of our equity-settled phantom unit awards for the six months ended June 30, 2017, is presented below: Number of Equity- Settled Phantom Units Average Grant Date Fair Value per Unit Outstanding at December 31, 2016 287,659 $ 1.64 Units granted 9,000 2.65 Units vested (7,166 ) 1.16 Units forfeited (10,000 ) 2.94 Outstanding at June 30, 2017 279,493 $ 1.64

Derivative Financial Instrume23

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2017
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Estimated Fair Value of Derivative Assets and Liabilities	The following tables summarize the gross fair value by the appropriate balance sheet classification, even when the derivative financial instruments are subject to netting arrangements and qualify for net presentation, in our unaudited condensed consolidated balance sheets at June 30, 2017, and December 31, 2016: Gross Amounts Recognized Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheets Net Amounts Presented in the Unaudited Condensed Consolidated Balance Sheets (in thousands) June 30, 2017: Assets Derivative financial instruments - current asset $ 2,516 $ (2,168 ) $ 348 Derivative financial instruments - long-term asset 948 (490 ) 458 Total 3,464 (2,658 ) 806 Liabilities Derivative financial instruments - current liability (271 ) (309 ) (580 ) Derivative deferred premium - current liability (2,477 ) 2,477 — Derivative financial instruments - long-term liability (89 ) 89 — Derivative deferred premium - long-term liability (401 ) 401 — Total (3,238 ) 2,658 (580 ) Net Asset $ 226 $ — $ 226 Gross Amounts Recognized Gross Amounts Offset in the Unaudited Condensed Consolidated Balance Sheets Net Amounts Presented in the Unaudited Condensed Consolidated Balance Sheets (in thousands) December 31, 2016: Assets Derivative financial instruments - current asset $ 1,570 $ (1,570 ) $ — Derivative financial instruments - long-term asset 406 (406 ) — Total 1,976 (1,976 ) — Liabilities Derivative financial instruments - current liability (1,836 ) (3,478 ) (5,314 ) Derivative deferred premium - current liability (5,048 ) 5,048 — Derivative financial instruments - long-term liability (2,500 ) 5 (2,495 ) Derivative deferred premium - long-term liability (401 ) 401 — Total (9,785 ) 1,976 (7,809 ) Net Liability $ (7,809 ) $ — $ (7,809 )
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: Three Months Ended Six Months Ended June 30, June 30, 2017 2016 2017 2016 (in thousands) Net settlements on matured derivatives (1) $ 357 $ 6,191 $ 201 $ 17,285 Net change in fair value of derivatives 2,176 (16,279 ) 5,464 (24,805 ) Total gain (loss) on derivatives, net $ 2,533 $ (10,088 ) $ 5,665 $ (7,520 ) (1) .
Commodity Contracts	At June 30, 2017, and December 31, 2016, our commodity derivative contracts had maturities at various dates through December 2019 and were comprised of commodity price put and collar contracts. At June 30, 2017, we had the following oil derivatives net positions: Period Covered Weighted Average Floor Price Weighted Average Ceiling Price Total Bbls Hedged/day NYMEX Index Collars - 2017 45.00 51.78 652 WTI Puts - 2017 50.00 — 1,875 WTI Collars - 2018 44.38 55.52 1,315 WTI Puts - 2018 45.00 — 164 WTI Collars - 2019 50.00 60.52 427 WTI At December 31, 2016, we had the following oil derivatives net positions: Period Covered Weighted Average Floor Price Weighted Average Ceiling Price Total Bbls Hedged/day NYMEX Index Collars - 2017 $ 43.75 $ 50.68 658 WTI Puts - 2017 $ 50.00 $ — 1,932 WTI Collars - 2018 $ 44.38 $ 55.52 1,315 WTI Puts - 2018 $ 45.00 $ — 164 WTI Collars - 2019 $ 50.00 $ 60.52 427 WTI

Fair Value Disclosures (Tables)

Fair Value Disclosures (Tables)	6 Months Ended
	Jun. 30, 2017
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 on a recurring basis as of June 30, 2017, and December 31, 2016: Level 1 Level 2 Level 3 Fair Value (in thousands) June 30, 2017 Assets and Liabilities Measured at Fair Value on a Recurring Basis Derivative financial instruments - asset $ — $ 3,464 $ — $ 3,464 Derivative financial instruments - liability $ — $ 360 $ — $ 360 Derivative deferred premiums - liability $ — $ — $ 2,878 $ 2,878 December 31, 2016 Assets and Liabilities Measured at Fair Value on a Recurring Basis Derivative financial instruments - asset $ — $ 1,976 $ — $ 1,976 Derivative financial instruments - liability $ — $ 4,336 $ — $ 4,336 Derivative deferred premiums - liability $ — $ — $ 5,449 $ 5,449
Schedule of changes in Level 3 fair value measurements	A summary of the changes in Level 3 fair value measurements for the periods presented are as follows: Six Months Ended Year Ended June 30, 2017 December 31, 2016 (in thousands) Balance of Level 3 at beginning of period $ (5,449 ) $ (9,973 ) Derivative deferred premiums - purchases — (516 ) Derivative deferred premiums - settlements 2,571 5,040 Balance of Level 3 at end of period $ (2,878 ) $ (5,449 )

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Changes in Asset Retirement Obligations	As of June 30, 2017, and December 31, 2016, our ARO were reported as “Asset retirement obligations” in our unaudited condensed consolidated balance sheets. Changes in our ARO for the periods indicated are presented in the following table: Six Months Ended Year Ended June 30, 2017 December 31, 2016 (in thousands) Asset retirement obligations - beginning of period $ 11,331 $ 12,679 Liabilities incurred for new wells and interest 636 747 Liabilities settled upon plugging and abandoning wells (17 ) — Liabilities removed upon sale of wells — (2,827 ) Revision of estimates (75 ) 155 Accretion expense 244 577 Asset retirement obligations - end of period $ 12,119 $ 11,331

Commitments and Contingencies -

Commitments and Contingencies - Non-Cancellable Operating Leases (Tables)	6 Months Ended
	Jun. 30, 2017
Commitments And Contingencies Disclosure [Abstract]
Operating leases	Future minimum lease payments under the non-cancellable operating leases are presented in the following table (in thousands): Remaining 2017 244 2018 490 2019 413 2020 418 2021 423 Total $ 1,988

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2017
Equity [Abstract]
Cash Distributions - Preferred Unitholders	The following table summarizes cash distributions paid on our Preferred Units during the six months ended June 30, 2017: Date Paid Period Covered Distribution per Unit Total Distributions (in thousands) February 14, 2017 October 1, 2016 - December 31, 2016 $ 0.043 $ 500 May 15, 2017 January 1, 2017 - March 31, 2017 $ 0.043 $ 500

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The following table summarizes the affiliates’ transactions for the periods indicated: Three Months Ended Six Months Ended June 30, June 30, 2017 2016 2017 2016 (in thousands) Amounts paid for: Services agreement $ 652 $ 706 $ 1,293 $ 1,526 Operating agreements 1,613 1,616 3,016 3,281 Oilfield services 857 825 1,667 1,496 $ 3,122 $ 3,147 $ 5,976 $ 6,303

Organization and Nature of Op29

Organization and Nature of Operations - Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Non-cash investing and financing information:
Change in oil and natural gas properties - accrued capital expenditures	$ (40)	$ (379)
Supplemental Cash Flow Information:
Cash paid for interest	$ 2,305	$ 3,700

Acquisitions and Divestitures -

Acquisitions and Divestitures - Acquisitions Additional Information (Details) - USD ($) $ in Millions	Aug. 11, 2016	Jun. 30, 2017
Business Acquisition [Line Items]
Proceeds from sale of convertible preferred units, gross	$ 25
Permian Bolt On [Member]
Business Acquisition [Line Items]
Aggregate purchase price, net	18.7
Proceeds from sale of convertible preferred units, gross	$ 25
Wheatland [Member]
Business Acquisition [Line Items]
Aggregate purchase price, net		$ 4.2

Acquisitions and Divestitures31

Acquisitions and Divestitures Acquisition and Divestiture (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Aug. 11, 2016
Permian Bolt On [Member]
Business Acquisition [Line Items]
Oil and natural gas properties		$ 19,323
Total assets acquired		19,323
Asset retirement obligation		622
Net assets acquired		$ 18,701
Wheatland [Member]
Business Acquisition [Line Items]
Oil and natural gas properties	$ 4,465
Other property and equipment	127
Total assets acquired	4,592
Asset retirement obligation	407
Net assets acquired	$ 4,185

Acquisitions and Divestitures32

Acquisitions and Divestitures - Divestitures Additional Information (Details) - USD ($) $ in Thousands	Jul. 28, 2016	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Divestiture details
Proceeds from sale of oil and natural gas properties					$ 7
Loss on sales of oil and natural gas properties		$ 0	$ 13	$ 0	13
Impairment of proved oil and natural gas properties sold		$ 0	3,578	$ 0	3,578
Hugoton [Member]
Divestiture details
Proceeds from sale of oil and natural gas properties	$ 17,600
Loss on sales of oil and natural gas properties	600
Impairment of proved oil and natural gas properties sold	$ 3,600
Divestiture oil and natural gas revenue			1,800		3,000
Divestiture oil and natural gas expense			$ 5,300		$ 7,100

Equity Awards - Awards availabl

Equity Awards - Awards available for future grant (Details) - Long-Term Incentive Plan	Jun. 30, 2017shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Approved and authorized awards	3,514,000
Unrestricted units granted	(1,212,706)
Restricted units granted, net of forfeitures	(400,424)
Equity-settled phantom units granted, net of forfeitures	(456,500)
Awards available for future grant	1,444,370

Equity Awards - Additional Info

Equity Awards - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Long-Term Incentive Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity-based compensation expense	$ 0.1	$ 0.3	$ 0.3	$ 0.7

Equity Awards - Unrestricted Un

Equity Awards - Unrestricted Units - Additional Information (Details) - Unrestricted Common Units [Member] - $ / shares	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Units granted	25,400	70,000
Average grant date fair value per unit, granted	$ 2.65	$ 1.16

Equity Awards - Restricted Unit

Equity Awards - Restricted Units - Additional Information (Details) - Restricted Common Units [Member] $ in Thousands	6 Months Ended
	Jun. 30, 2017USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation costs	$ 40
Weighted average period, unrecognized costs	5 months
Vesting period	3 years
Tranche One
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	2 years

Equity Awards - Restricted Un37

Equity Awards - Restricted Units (Details) - Restricted Common Units [Member]	6 Months Ended
	Jun. 30, 2017$ / sharesshares
Number of units
Outstanding, beginning of period | shares	76,922
Units granted | shares	0
Units vested | shares	(66,030)
Units forfeited | shares	0
Outstanding, end of period | shares	10,892
Weighted Average Grant Date Fair Value per Restricted Unit
Average fair value per unit, outstanding, beginning of period | $ / shares	$ 5.67
Average grant date fair value per unit, granted | $ / shares	0
Average grant date fair value per unit, vested | $ / shares	4.96
Average grant date fair value per unit, forfeited | $ / shares	0
Average fair value per unit, outstanding, end of period | $ / shares	$ 9.99

Equity Awards - Equity-Settled

Equity Awards - Equity-Settled Phantom Units - Additional Information (Details) - Equity-Settled Phantom Units [Member] - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation costs	$ 0.2
Weighted average period, unrecognized costs	1 year 3 months
Units granted	9,000	24,500
Tranche One
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		33.00%
Tranche Two
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage		66.00%
Minimum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	2 years
Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years

Equity Awards - Equity-Settle39

Equity Awards - Equity-Settled Phantom Units (Details) - Equity-Settled Phantom Units [Member] - $ / shares	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Number of units
Outstanding, beginning of period	287,659
Units granted	9,000	24,500
Units vested	(7,166)
Units forfeited	(10,000)
Outstanding, end of period	279,493
Weighted Average Grant Date Fair Value per Phantom Unit
Average fair value per unit, outstanding, beginning of period	$ 1.64
Average grant date fair value per unit, granted	2.65
Average grant date fair value per unit, vested	1.16
Average grant date fair value per unit, forfeited	2.94
Average fair value per unit, outstanding, end of period	$ 1.64

Derivative Financial Instrume40

Derivative Financial Instruments - Additional information (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Fair value	$ 226	$ (7,809)

Derivative Financial Instrume41

Derivative Financial Instruments - Summary of Gross Fair Value by Appropriate Balance Sheet Classification (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Assets
Derivative Asset, Fair Value, Gross Asset	$ 3,464	$ 1,976
Gross Amounts Offset	(2,658)	(1,976)
Net Amount presented - Balance Sheet	806	0
Liabilities
Gross Amounts of Recognized Liabilities	(3,238)	(9,785)
Gross Amounts Offset	2,658	1,976
Net Amount presented - Balance Sheet	(580)	(7,809)
Gross Amount of Recognized Assets and Liabilities	226	(7,809)
Gross Amounts Offset	0	0
Net Assets Presented - Balance Sheet	226	(7,809)
Current Asset [Member]
Assets
Derivative Asset, Fair Value, Gross Asset	2,516	1,570
Gross Amounts Offset	(2,168)	(1,570)
Net Amount presented - Balance Sheet	348	0
Long Term Asset [Member]
Assets
Derivative Asset, Fair Value, Gross Asset	948	406
Gross Amounts Offset	(490)	(406)
Net Amount presented - Balance Sheet	458	0
Current Liability [Member]
Liabilities
Gross Amounts of Recognized Liabilities	(271)	(1,836)
Gross Amount Deferred premium	(2,477)	(5,048)
Gross Amounts Offset	(309)	(3,478)
Deferred Premium Offset	2,477	5,048
Net Amount presented - Balance Sheet	(580)	(5,314)
Deferred Premium	0	0
Long Term Liability [Member]
Liabilities
Gross Amounts of Recognized Liabilities	(89)	(2,500)
Gross Amount Deferred premium	(401)	(401)
Gross Amounts Offset	89	5
Deferred Premium Offset	401	401
Net Amount presented - Balance Sheet	0	(2,495)
Deferred Premium	$ 0	$ 0

Derivative Financial Instrume42

Derivative Financial Instruments - Impact of Derivative Financial Instruments within Condensed Consolidated Statement of Operations (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Net settlements on matured derivatives	[1]	$ 357	$ 6,191	$ 201	$ 17,285
Net change in fair value of derivatives		2,176	(16,279)	5,464	(24,805)
Total gain (loss) on derivatives, net		$ 2,533	$ (10,088)	$ 5,665	$ (7,520)
[1]	The settlement amount does not include premiums paid attributable to contracts that matured during the respective period.

Derivative Financial Instrume43

Derivative Financial Instruments - Commodity Contracts (Details) - $ / bbl	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Put Option [Member] | Period Covered-2017 [Member]
Derivative [Line Items]
Weighted Average Floor Price	50	50
Total Bbls Hedged/day	1,875	1,932
Derivative, Underlying Basis	WTI	WTI
Put Option [Member] | Period Covered-2018 [Member]
Derivative [Line Items]
Weighted Average Floor Price	45	45
Total Bbls Hedged/day	164	164
Derivative, Underlying Basis	WTI	WTI
Collar [Member] | Period Covered-2017 [Member]
Derivative [Line Items]
Weighted Average Floor Price	45	43.75
Weighted Average Ceiling Price	51.78	50.68
Total Bbls Hedged/day	652	658
Derivative, Underlying Basis	WTI	WTI
Collar [Member] | Period Covered-2018 [Member]
Derivative [Line Items]
Weighted Average Floor Price	44.38	44.38
Weighted Average Ceiling Price	55.52	55.52
Total Bbls Hedged/day	1,315	1,315
Derivative, Underlying Basis	WTI	WTI
Collar [Member] | Period Covered-2019 [Member]
Derivative [Line Items]
Weighted Average Floor Price	50	50
Weighted Average Ceiling Price	60.52	60.52
Total Bbls Hedged/day	427	427
Derivative, Underlying Basis	WTI	WTI

Fair Value Disclosures - Assets

Fair Value Disclosures - Assets and Liabilities Measured at Fair Value on Recurring Basis and Nonrecurring Basis (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative financial instruments - asset	$ 806	$ 0
Derivative financial instruments - liability	580	7,809
Fair Value [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 financial instruments - asset	3,464	1,976
Derivative financial instruments - liability	360	4,336
Derivative deferred premiums - liability	2,878	5,449
Level 1 [Member] | Fair Value [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 financial instruments - asset	0	0
Derivative financial instruments - liability	0	0
Derivative deferred premiums - liability	0	0
Level 2 [Member] | Fair Value [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 financial instruments - asset	3,464	1,976
Derivative financial instruments - liability	360	4,336
Derivative deferred premiums - liability	0	0
Level 3 [Member] | Fair Value [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 financial instruments - asset	0	0
Derivative financial instruments - liability	0	0
Derivative deferred premiums - liability	$ 2,878	$ 5,449

Fair Value Disclosures - Summar

Fair Value Disclosures - Summary of Changes in assets (liabilities) - Level 3 (Details) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance of Level 3 at beginning of period	$ (5,449)	$ (9,973)
Derivative deferred premiums - purchases	0	(516)
Derivative deferred premiums - settlements	2,571	5,040
Balance of Level 3 at end of period	$ (2,878)	$ (5,449)

Fair Value Disclosures - Additi

Fair Value Disclosures - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Inputs, Discount Rate			10.00%
Impairment expense	$ 17,672	$ 895	$ 17,672	$ 895
Impairment of proved oil and natural gas properties sold	$ 0	$ 3,578	$ 0	$ 3,578

Asset Retirement Obligations -

Asset Retirement Obligations - Changes in Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Asset Retirement Obligation [Roll Forward]
Asset retirement obligations - beginning of period			$ 11,331	$ 12,679	$ 12,679
Liabilities incurred for new wells and interest			636		747
Liabilities settled upon plugging and abandoning wells			(17)		0
Liabilities removed upon sale of wells			0		(2,827)
Revision of estimates			(75)		155
Accretion expense	$ 136	$ 159	244	$ 316	577
Asset retirement obligations - end of period	$ 12,119		$ 12,119		$ 11,331

Debt - Additional Information (

Debt - Additional Information (Details) - Revolving Credit Facility [Member] - USD ($)	Aug. 11, 2016	Jun. 30, 2017	Jun. 30, 2017	Dec. 31, 2018	Dec. 31, 2017	May 24, 2017	Dec. 31, 2016	Oct. 28, 2016	May 31, 2016
Line of Credit Facility Line Items
Revolving credit facility (matures November 2018)		$ 121,000,000	$ 121,000,000				$ 122,000,000
Revolving credit facility maturity date			Nov. 30, 2018
Average effective rate		3.81%
Line of credit facility, maximum borrowing capacity	$ 140,000,000					$ 140,000,000		$ 140,000,000	$ 163,000,000
Line of credit over advance									53,000,000
Revolving Credit Facility, Conforming Tranche [Member]
Line of Credit Facility Line Items
Line of credit facility, maximum borrowing capacity									$ 110,000,000
August 2016 Amended Credit Agreement [Member]
Line of Credit Facility Line Items
Period to extend collateral coverage	30 days
August 2016 Amended Credit Agreement [Member] | Scenario, Forecast [Member] | Commodity Contract [Member]
Line of Credit Facility Line Items
Minimum coverage of projected production (percent)				50.00%	75.00%
Federal Funds Effective Swap Rate [Member]
Line of Credit Facility Line Items
Debt instrument, percentage points added to reference rate			0.50%
LIBOR [Member]
Line of Credit Facility Line Items
Debt instrument, percentage points added to reference rate			1.00%
Minimum
Line of Credit Facility Line Items
Debt instrument, percentage points added to reference rate			1.00%
Unused portion of borrowing base, percentage fee		0.375%
Minimum | LIBOR [Member]
Line of Credit Facility Line Items
Debt instrument, percentage points added to reference rate			2.00%
Maximum
Line of Credit Facility Line Items
Debt instrument, percentage points added to reference rate			2.75%
Unused portion of borrowing base, percentage fee		0.50%
Maximum | LIBOR [Member]
Line of Credit Facility Line Items
Debt instrument, percentage points added to reference rate			3.75%

Commitment and Contingencies -

Commitment and Contingencies - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Commitments Contingencies And Litigation [Line Items]
Lease expense	$ 0.1	$ 0.1	$ 0.1	$ 0.2
Minimum
Commitments Contingencies And Litigation [Line Items]
Employee Termination Expenses			0.4
Maximum
Commitments Contingencies And Litigation [Line Items]
Employee Termination Expenses			$ 0.7

Commitment and Contingencies 50

Commitment and Contingencies - Operating Leases (Details) $ in Thousands	Jun. 30, 2017USD ($)
Commitments And Contingencies Disclosure [Abstract]
Remaining 2,017	$ 244
2,018	490
2,019	413
2,020	418
2,021	423
Total	$ 1,988

Equity - Additional Information

Equity - Additional Information (Details) - USD ($)	May 05, 2015	Jun. 30, 2017	Dec. 31, 2016
Equity [Abstract]
Limited partners, units outstanding		29,944,796	29,912,230
Limited partnership interest		98.80%
Maximum proceeds under equity distribution agreement - suspended	$ 50,000,000

Equity - Preferred Units - Addi

Equity - Preferred Units - Additional Information (Details) $ / shares in Units, $ in Millions	Aug. 11, 2016USD ($)$ / sharesshares	Jun. 30, 2017USD ($)	Jun. 30, 2017USD ($)
Class of Stock [Line Items]
Preferred Units, Issued | shares	11,627,906
Proceeds from sale of convertible preferred units, net of offering costs	$ 25
Price per share for preferred units (in dollars per share) | $ / shares	$ 2.15
Proceeds from issuance of preferred stock (net of offering costs)	$ 24.6
Issuance costs	0.4
Net proceeds allocated, fair value basis, to Preferred Units	18.6
Allocation of value to beneficial conversion feature of Class A convertible preferred units	$ 6
Accretion period for beneficial conversion			5 years
Accretion of beneficial conversion		$ 0.2	$ 0.5
Days after quarter end distribution paid	45 days
Preferred units distribution accrued			$ 0.5
Conversion period	5 years
Number of days within closing date	90 days
Number of days after closing date	180 days
Cash Dividends [Member]
Class of Stock [Line Items]
Dividend rate (percentage)	8.00%
In Kind Dividends [Member]
Class of Stock [Line Items]
Dividend rate (percentage)	10.00%
Preferred Units
Class of Stock [Line Items]
Conversion ratio		1	1

Equity - Cash Distributions Pre

Equity - Cash Distributions Preferred Unitholders (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Equity [Abstract]
Date Paid	May 15, 2017	Feb. 14, 2017
Distribution per Unit	$ 0.043	$ 0.043
Total Distributions	$ 500	$ 500

Related Party Transactions Rela

Related Party Transactions Related Party Transactions- Affiliate Transactions (Details) - Mid-Con Energy Operating [Member] - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Related Party Transaction [Line Items]
Services agreement	$ 652	$ 706	$ 1,293	$ 1,526
Operating agreements	1,613	1,616	3,016	3,281
Oilfield services	857	825	1,667	1,496
Costs and expenses, Related Party	$ 3,122	$ 3,147	$ 5,976	$ 6,303

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Details) - Mid-Con Energy Operating [Member] - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Other transactions of related party	$ 1.4	$ 3.4
Joint interest billing payable	1.2	2.8
Operating services payable	$ 0.2	$ 0.6

Subsequent Events - Additional

Subsequent Events - Additional Information (Details) - USD ($) $ / shares in Units, $ in Millions	Aug. 07, 2017	Jul. 26, 2017	Mar. 31, 2017	Dec. 31, 2016	Jun. 30, 2017	Jun. 30, 2016
Subsequent Event [Line Items]
Distribution per Unit			$ 0.043	$ 0.043
Equity-Settled Phantom Units [Member]
Subsequent Event [Line Items]
Units granted					9,000	24,500
Subsequent Event [Member]
Subsequent Event [Line Items]
Distribution per Unit	$ 0.043
Preferred Units Distributions Declared	$ 0.5
Subsequent Event [Member] | Equity-Settled Phantom Units [Member]
Subsequent Event [Line Items]
Units granted		32,500
Subsequent Event [Member] | Equity-Settled Phantom Units [Member] | Tranche One
Subsequent Event [Line Items]
Units granted		27,000
Vesting period		2 years
Subsequent Event [Member] | Equity-Settled Phantom Units [Member] | Tranche Two
Subsequent Event [Line Items]
Units granted		5,500
Vesting period		3 years