Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2018	Apr. 27, 2018
Document and Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q1
Entity Registrant Name	Viper Energy Partners LP
Entity Central Index Key	0001602065
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Units, Units Outstanding		113,882,045
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes

Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 18,151	$ 24,197
Royalty income receivable	28,873	25,754
Royalty income receivable—related party	6,505	5,142
Other current assets	361	355
Total current assets	53,890	55,448
Property:
Oil and natural gas interests, full cost method of accounting ($630,916 and $514,724 excluded from depletion at March 31, 2018 and December 31, 2017, respectively)	1,258,327	1,103,897
Accumulated depletion and impairment	(200,992)	(189,466)
Oil and natural gas interests, net	1,057,335	914,431
Funds held in escrow	0	6,304
Other assets	18,824	36,854
Total assets	1,130,049	1,013,037
Current liabilities:
Accounts payable	576	2,960
Other accrued liabilities	1,918	2,669
Total current liabilities	2,494	5,629
Long-term debt	240,500	93,500
Total liabilities	242,994	99,129
Commitments and contingencies
Unitholders’ equity:
Common units (113,882,045 units issued and outstanding as of March 31, 2018 and as of December 31, 2017 )	887,055	913,908
Total unitholders’ equity	887,055	913,908
Total liabilities and unitholders’ equity	$ 1,130,049	$ 1,013,037

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Oil and natural gas interests, based on the full cost method of accounting, amount excluded from depletion	$ 630,916	$ 514,724
Common units issued	113,882,045	113,882,045
Common units outstanding	113,882,045	113,882,045

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Operating income:
Royalty income	$ 62,393	$ 32,050
Lease bonus income	0	1,602
Other operating income	50	0
Total operating income	62,443	33,652
Costs and expenses:
Production and ad valorem taxes	4,239	2,070
Gathering and transportation	265	143
Depletion	11,525	7,847
General and administrative expenses	2,711	2,142
Total costs and expenses	18,740	12,202
Income from operations	43,703	21,450
Other income (expense):
Interest expense, net	(2,098)	(612)
Gain on revaluation of investment	899	0
Other income (expense), net	392	(186)
Total other expense, net	(807)	(798)
Net income	$ 42,896	$ 20,652
Net income attributable to common limited partners per unit:
Basic (dollars per unit)	$ 0.38	$ 0.22
Diluted (dollars per unit)	$ 0.38	$ 0.22
Weighted average number of limited partner units outstanding:
Basic (in units)	113,901	94,969
Diluted (in units)	113,991	94,979

Statement of Consolidated Unitholders' Equity - USD ($) shares in Thousands, $ in Thousands	Total	Limited Partner [Member]	Diamondback Energy, Inc. Limited Partner [Member]
Common Stock, Shares, Outstanding at Dec. 31, 2016		87,800
Partners' capital at Dec. 31, 2016		$ 547,898
Increase (Decrease) in Partners' Capital [Roll Forward]
Units sold in public offering		9,575
Net proceeds from the issuance of common units		$ 147,523
Unit-based compensation		819
Distributions to public		(6,482)
Distributions to Diamondback			$ (18,692)
Net income	$ 20,652	$ 20,652
Common Stock, Shares, Outstanding at Mar. 31, 2017		97,375
Partners' capital at Mar. 31, 2017		$ 691,718
Common Stock, Shares, Outstanding at Dec. 31, 2017		113,882
Partners' capital at Dec. 31, 2017	913,908	$ 913,908
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation		1,288
Distributions to public		(18,737)
Distributions to Diamondback			$ (33,649)
Net income	42,896	$ 42,896
Common Stock, Shares, Outstanding at Mar. 31, 2018		113,882
Partners' capital at Mar. 31, 2018	$ 887,055	$ 887,055
Increase (Decrease) in Partners' Capital [Roll Forward]
Impact of adoption of ASU 2016-01		$ (18,651)

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Cash flows from operating activities:
Net income	$ 42,896	$ 20,652
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion	11,525	7,847
Gain on revaluation of investment	(899)	0
Amortization of debt issuance costs	155	133
Non-cash unit-based compensation	1,288	819
Changes in operating assets and liabilities:
Restricted cash	0	500
Royalty income receivable	(3,119)	826
Royalty income receivable—related party	(1,363)	(3,481)
Accounts payable and other accrued liabilities	(1,265)	(1,187)
Other current assets	(6)	(44)
Net cash provided by operating activities	49,212	26,065
Cash flows from investing activities:
Acquisition of mineral interests	(149,994)	(8,579)
Proceeds from the sale of investments	125	0
Net cash used in investing activities	(149,869)	(8,579)
Cash flows from financing activities:
Proceeds from borrowings under credit facility	147,000	0
Repayment on credit facility	0	(120,500)
Debt issuance costs	(3)	(1)
Proceeds from public offerings	0	147,725
Public offering costs	0	(186)
Distributions to partners	(52,386)	(25,174)
Net cash provided by financing activities	94,611	1,864
Net (decrease) increase in cash	(6,046)	19,350
Cash and cash equivalents at beginning of period	24,197	9,213
Cash and cash equivalents at end of period	18,151	28,563
Supplemental disclosure of cash flow information:
Interest paid	$ 2,072	$ 582

Organization and Basis of Presentation	3 Months Ended
Organization and Basis of Presentation	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	ORGANIZATION AND BASIS OF PRESENTATION Organization Viper Energy Partners LP (the “Partnership”) is a publicly traded Delaware limited partnership, the common units of which are listed on the NASDAQ Global Market under the symbol “VNOM”. The Partnership was formed by Diamondback Energy, Inc. (“Diamondback”) on February 27, 2014 to, among other things, own, acquire and exploit oil and natural gas properties in North America. The Partnership is currently focused on oil and natural gas properties in the Permian Basin and Eagle Ford Shale. Unless the context requires otherwise, references to “we,” “us,” “our” or “the Partnership” are intended to mean the business and operations of Viper Energy Partners LP and its consolidated subsidiary, Viper Energy Partners LLC. As of March 31, 2018, Viper Energy Partners GP LLC (the “General Partner”), held a 100% non-economic general partner interest in the Partnership and Diamondback had an approximate 64% limited partner interest in the Partnership. Diamondback owns and controls the General Partner. Basis of Presentation The accompanying consolidated financial statements and related notes thereto were prepared in conformity with GAAP. All material intercompany balances and transactions are eliminated in consolidation. These financial statements have been prepared by the Partnership without audit, pursuant to the rules and regulations of the SEC. They reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for interim periods, on a basis consistent with the annual audited financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations, although the Partnership believes the disclosures are adequate to make the information presented not misleading. This Quarterly Report on Form 10–Q should be read in conjunction with the Partnership’s most recent Annual Report on Form 10–K for the fiscal year ended December 31, 2017, which contains a summary of the Partnership’s significant accounting policies and other disclosures.

Summary of Significant Accounting Policies	3 Months Ended
Summary of Significant Accounting Policies	Mar. 31, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Use of Estimates Certain amounts included in or affecting the Partnership’s financial statements and related disclosures must be estimated by management, requiring certain assumptions to be made with respect to values or conditions that cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts the Partnership reports for assets and liabilities and the Partnership’s disclosure of contingent assets and liabilities at the date of the financial statements. The Partnership evaluates these estimates on an ongoing basis, using historical experience, consultation with experts and other methods the Partnership considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from the Partnership’s estimates. Any effects on the Partnership’s business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Significant items subject to such estimates and assumptions include estimates of proved oil and natural gas reserves and related present value estimates of future net cash flows therefrom, the carrying value of oil and natural gas interests and unit–based compensation. Investments The Partnership has an equity interest in a limited partnership that is so minor that the Partnership has no influence over the limited partnership’s operating and financial policies. This interest was acquired during the year ended December 31, 2014 and is accounted for under the cost method. Effective January 1, 2018, the Partnership adopted Accounting Standards Update 2016-01 which requires the Partnership to measure this investment at fair value which resulted in a downward adjustment of $18.7 million to record the impact of this adoption. For the three months ended March 31, 2018, the Partnership recorded a gain of $0.9 million which then increased the Partnership’s investment balance to $16.0 million, which is included in other assets in the accompanying consolidated balance sheets. New Accounting Pronouncements Recently Issued Pronouncements In January 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-01, “Financial Instruments–Overall”. This update applies to any entity that holds financial assets or owes financial liabilities. This update requires equity investments (except for those accounted for under the equity method or those that result in consolidation of the investee) to be measured at fair value with changes in fair value recognized in net income. The Partnership adopted this standard effective January 1, 2018 by means of a negative cumulative-effect adjustment totaling $18.7 million. In November 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-18, “Statement of Cash Flows - Restricted Cash”. This update affects entities that have restricted cash or restricted cash equivalents. The Partnership adopted this update effective January 1, 2018. The adoption of this update did not have an effect on the presentation on the Statement of Cash Flows. In January 2017, the Financial Accounting Standards Board issued Accounting Standards Update 2017-01, “Business Combinations - Clarifying the Definition of a Business”. This update apples to all entities that must determine whether they acquired or sold a business. This update provides a screen to determine when a set is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business. The Partnership adopted this update prospectively effective January 1, 2018. The adoption of this update did not have an impact on its financial position, results of operations or liquidity. Accounting Pronouncements Not Yet Adopted In February 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-02, “Leases”. This update applies to any entity that enters into a lease, with some specified scope exemptions. Under this update, a lessee should recognize in the statement of financial position a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. While there were no major changes to the lessor accounting, changes were made to align key aspects with the revenue recognition guidance. This update will be effective for public entities for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, with early adoption permitted. Entities will be required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. As of March 31, 2018, the Partnership was not the lessor or lessee of any leases other than mineral leases which were excluded from the scope of this Accounting Standards Update. Therefore, the Partnership believes the adoption of this update will not have an impact on its financial position, results of operations or liquidity. In January 2018, the Financial Accounting Standards Board issued Accounting Standards Update 2018-01, “Leases - Land Easement Practical Expedient for Transition to Topic 842”. This update applies to any entity that holds land easements. The update allows entities to adopt a practical expedient to not evaluate existing or expired land easements under Topic 842 that were not previously accounted for as leases under the current leases guidance. An entity that elects this practical expedient should evaluate new or modified land easements under Topic 842 beginning at the date that the entity adopts Topic 842. The Partnership believes the adoption of this update will not have an impact on its financial position, results of operations or liquidity. In June 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-13, “Financial Instruments - Credit Losses”. This update affects entities holding financial assets and net investment in leases that are not accounted for at fair value through net income. The amendments affect loans, debt securities, trade receivables, net investments in leases, off-balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. This update will be effective for financial statements issued for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. This update will be applied through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Partnership does not believe the adoption of this standard will have an impact on its financial statements since it does not have a history of credit losses.

Revenue from Contracts with Customers	3 Months Ended
Revenue from Contracts with Customers	Mar. 31, 2018
Revenue, Initial Application Period Cumulative Effect Transition [Line Items]
Revenue from Contract with Customer [Text Block]	Impact of ASC Topic 606 Adoption In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-09, “Revenue from Contracts with Customers”. This update supersedes most of the existing revenue recognition requirements. This standard included a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the Partnership expects to be entitled in exchange for those goods or services. Among other things, the standard also eliminated industry-specific revenue guidance, required enhanced disclosures about revenue, provided guidance for transactions that were not previously addressed comprehensively and improved guidance for multiple-element arrangements. The Partnership adopted this standard effective January 1, 2018 using the modified retrospective method. The Partnership utilized a bottom-up approach to analyze the impact of the new standard by reviewing its current accounting policies and practices to identify potential differences that would result from applying the requirements of the new standard to its revenue contracts and the impact of adopting this standard on its total revenues, operating income and the Partnership’s consolidated balance sheet. The adoption of this standard did not result in a cumulative-effect adjustment. Royalty income represents the right to receive revenues from oil, natural gas and natural gas liquids sales obtained by the operator of the wells in which the Partnership owns a royalty interest. Royalty income is recognized at the point control of the product is transferred to the purchaser. Virtually all of the Partnership’s contracts’ pricing provisions are tied to a market index. Royalty income from oil, natural gas and natural gas liquids sales The Partnership’s oil, natural gas and natural gas liquids sales contracts are generally structured whereby the producer of the properties in which the Partnership owns a royalty interest sells the Partnership’s proportionate share of oil, natural gas and natural gas liquids production to the purchaser and the Partnership collects its percentage royalty based on the revenue generated by the sale of the oil, natural gas and natural gas liquids. In this scenario, the Partnership recognizes revenue when control transfers to the purchaser at the wellhead or at the gas processing facility based on the Partnership’s percentage ownership share of the revenue. Transaction price allocated to remaining performance obligations The Partnership’s right to royalty income does not originate until production occurs and, therefore, is not considered to exist beyond each days’ production. Therefore, there are no remaining performance obligation under any of our royalty income contracts. Contract balances Under the Partnership’s royalty income contracts, it would have the right to receive royalty income from the producer once production has occurred, at which point payment is unconditional. Accordingly, the Partnership’s royalty income contracts do not give rise to contract assets or liabilities under Accounting Standards Codification 606. Prior-period performance obligations The Partnership records revenue in the month production is delivered to the purchaser. However, settlement statements for certain natural gas and natural gas liquids sales may not be received for 30 to 90 days after the date production is delivered, and as a result, the Partnership is required to estimate the amount of royalty income to be received based upon the Partnership’s interest. The Partnership records the differences between its estimates and the actual amounts received for royalties in the month that payment is received from the producer. The Partnership has existing internal controls for its revenue estimation process and related accruals, and any identified differences between its revenue estimates and actual revenue received historically have not been significant. For the three months ended March 31, 2018, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material. The Partnership believes that the pricing provisions of its oil, natural gas and natural gas liquids contracts are customary in the industry. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the royalties related to expected sales volumes and prices for those properties are estimated and recorded.

Acquisitions	3 Months Ended
Acquisitions	Mar. 31, 2018
Business Acquisition [Line Items]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	ACQUISITIONS During the three months ended March 31, 2018, the Partnership acquired mineral interests underlying 967 net royalty acres for an aggregate purchase price of approximately $158.1 million and, as of March 31, 2018, had mineral interests underlying 10,537 net royalty acres. The Partnership funded these acquisitions with borrowings under its revolving credit facility.

Oil and Natural Gas Interests

3 Months Ended

Mar. 31, 2018

Extractive Industries [Abstract]

Oil and Natural Gas Interests

OIL AND NATURAL GAS INTERESTS

Oil and natural gas interests include the following:



	March 31,			December 31,
	2018			2017

	(in thousands)
Oil and natural gas interests:
Subject to depletion	$	627,411		$	589,173
Not subject to depletion	630,916			514,724
Gross oil and natural gas interests	1,258,327			1,103,897
Accumulated depletion and impairment	(200,992		)	(189,466		)
Oil and natural gas interests, net	$	1,057,335		$	914,431

Balance of acquisition costs not subject to depletion
Incurred in 2018	$	120,802
Incurred in 2017	284,371
Incurred in 2016	158,157
Incurred in 2015	28,806
Incurred in 2014	38,780
Total not subject to depletion	$	630,916

Costs associated with unevaluated interests are excluded from the full cost pool until a determination as to the existence of proved reserves is able to be made. The inclusion of the Partnership’s unevaluated costs into the amortization base is expected to be completed within three to five years.

Under the full cost method of accounting, the Partnership is required to perform a ceiling test each quarter. The test determines a limit, or ceiling, on the book value of the proved oil and gas interests. Net capitalized costs are limited to the lower of unamortized cost or the cost center ceiling. The cost center ceiling is defined as the sum of (a) estimated future net revenues, discounted at 10% per annum, from proved reserves, based on the trailing 12-month unweighted average of the first-day-of-the-month price, adjusted for any contract provisions or financial derivatives, if any, that hedge the Partnership’s oil and natural gas revenue, (b) the cost of interests not being amortized, if any, and (c) the lower of cost or market value of unproved interests included in the cost being amortized. If the net book value exceeds the ceiling, an impairment or non-cash write down is required.

Debt

3 Months Ended

Mar. 31, 2018

Debt Disclosure [Abstract]

Debt

DEBT

Credit Agreement-Wells Fargo Bank

On July 8, 2014, the Partnership entered into a secured revolving credit agreement with Wells Fargo, as administrative agent, and Wells Fargo Securities, as sole book runner and lead arranger. The credit agreement, as amended, provides for a revolving credit facility in the maximum credit amount of $2.0 billion and a borrowing base based on its oil and natural gas reserves and other factors (the “borrowing base”) of $400.0 million, subject to scheduled semi-annual and other elective borrowing base redeterminations. The borrowing base is scheduled to be re-determined semi-annually with effective dates of May 1st and November 1st. In addition, the Partnership may request up to three additional redeterminations of the borrowing base during any 12-month period. As of March 31, 2018, the borrowing base was set at $400.0 million, and the Partnership had $240.5 million of outstanding borrowings and $159.5 million available for future borrowings under its revolving credit facility.

The outstanding borrowings under the credit agreement bear interest at a rate elected by the Partnership that is equal to an alternative base rate (which is equal to the greatest of the prime rate, the Federal Funds effective rate plus 0.50% and 3-month LIBOR plus 1.0%) or LIBOR, in each case plus the applicable margin. The applicable margin ranges from 0.75% to 1.75% per annum in the case of the alternative base rate and from 1.75% to 2.75% per annum in the case of LIBOR, in each case depending on the amount of loans and letters of credit outstanding in relation to the commitment, which is defined as the lesser of the maximum credit amount and the borrowing base. The Partnership is obligated to pay a quarterly commitment fee ranging from 0.375% to 0.500% per year on the unused portion of the commitment, which fee is also dependent on the amount of loans and letters of credit outstanding in relation to the commitment. Loan principal may be optionally repaid from time to time without premium or penalty (other than customary LIBOR breakage), and is required to be repaid (a) to the extent the loan amount exceeds the commitment or the borrowing base, whether due to a borrowing base redetermination or otherwise (in some cases subject to a cure period), (b) in an amount equal to the net cash proceeds from the sale of property when a borrowing base deficiency or event of default exists under the credit agreement and (c) at the maturity date of November 1, 2022. The loan is secured by substantially all of the assets of the Partnership and its subsidiary.

The credit agreement contains various affirmative, negative and financial maintenance covenants. These covenants, among other things, limit additional indebtedness, additional liens, sales of assets, mergers and consolidations, dividends and distributions, transactions with affiliates and entering into certain swap agreements and require the maintenance of the financial ratios described below.



Financial Covenant		Required Ratio
Ratio of total debt to EBITDAX		Not greater than 4.0 to 1.0
Ratio of current assets to liabilities, as defined in the credit agreement		Not less than 1.0 to 1.0

The covenant prohibiting additional indebtedness allows for the issuance of unsecured debt of up to $400.0 million in the form of senior unsecured notes and, in connection with any such issuance, the reduction of the borrowing base by 25% of the stated principal amount of each such issuance. A borrowing base reduction in connection with such issuance may require a portion of the outstanding principal of the loan to be repaid.

As of March 31, 2018, the Partnership was in compliance with the financial covenants under its credit agreement. The lenders may accelerate all of the indebtedness under the Partnership’s revolving credit facility upon the occurrence and during the continuance of any event of default. The credit agreement contains customary events of default, including non-payment, breach of covenants, materially incorrect representations, cross-default, bankruptcy and change of control. With certain specified exceptions, the terms and provisions of the Partnership’s credit agreement generally may be amended with the consent of the lenders holding a majority of the outstanding loans or commitments to lend.

Related Party Transactions	3 Months Ended
Related Party Transactions	Mar. 31, 2018
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS Partnership Agreement In connection with the closing of the IPO, the General Partner and Diamondback entered into the first amended and restated agreement of limited partnership, dated June 23, 2014 (the “Partnership Agreement”). The Partnership Agreement requires the Partnership to reimburse the General Partner for all direct and indirect expenses incurred or paid on the Partnership’s behalf and all other expenses allocable to the Partnership or otherwise incurred by the General Partner in connection with operating the Partnership’s business. The Partnership Agreement does not set a limit on the amount of expenses for which the General Partner and its affiliates may be reimbursed. These expenses include salary, bonus, incentive compensation and other amounts paid to persons who perform services for the Partnership or on the Partnership’s behalf and expenses allocated to the General Partner by its affiliates. The General Partner is entitled to determine the expenses that are allocable to the Partnership. For each of the three months ended March 31, 2018 and 2017, the General Partner allocated $0.6 million to the Partnership. Advisory Services Agreement In connection with the closing of the IPO, the Partnership and General Partner entered into an advisory services agreement with Wexford Capital LP (“Wexford”) dated as of June 23, 2014 (the “Advisory Services Agreement”), under which Wexford provides the Partnership and the General Partner with general financial and strategic advisory services related to the Partnership’s business in return for an annual fee of $0.5 million, plus reasonable out-of-pocket expenses. The Advisory Services Agreement has an initial term of two years commencing on June 23, 2014, and continues for additional one-year periods unless terminated in writing by either party at least ten days prior to the expiration of the then current term. It may be terminated at any time by either party upon 30 days prior written notice. For the three months ended March 31, 2018 and 2017, the Partnership did not pay any costs under the Advisory Services Agreement. Tax Sharing In connection with the closing of the IPO, the Partnership entered into a tax sharing agreement with Diamondback, dated June 23, 2014, pursuant to which the Partnership agreed to reimburse Diamondback for its share of state and local income and other taxes for which the Partnership’s results are included in a combined or consolidated tax return filed by Diamondback with respect to taxable periods including or beginning on June 23, 2014. The amount of any such reimbursement is limited to the tax the Partnership would have paid had it not been included in a combined group with Diamondback. Diamondback may use its tax attributes to cause its combined or consolidated group, of which the Partnership may be a member for this purpose, to owe less or no tax. In such a situation, the Partnership agreed to reimburse Diamondback for the tax the Partnership would have owed had the tax attributes not been available or used for the Partnership’s benefit, even though Diamondback had no cash tax expense for that period. Lease Bonus During the three months ended March 31, 2018, Diamondback did not pay the Partnership any lease bonus payments. During the three months ended March 31, 2017, Diamondback paid the Partnership $1,500 in lease bonus payments to extend the term of one lease, reflecting an average bonus of $400 per acre.

Unit-Based Compensation

3 Months Ended

Mar. 31, 2018

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Unit-Based Compensation

UNIT-BASED COMPENSATION

In connection with the IPO, the board of directors of the General Partner adopted the Viper Energy Partners LP Long Term Incentive Plan (“LTIP”), effective June 17, 2014, for employees, officers, consultants and directors of the General Partner and any of its affiliates, including Diamondback, who perform services for the Partnership. The LTIP provides for the grant of unit options, unit appreciation rights, restricted units, unit awards, phantom units, distribution equivalent rights, cash awards, performance awards, other unit-based awards and substitute awards. As of March 31, 2018, a total of 9,070,356 common units had been reserved for issuance pursuant to the LTIP. Common units that are cancelled, forfeited or withheld to satisfy exercise prices or tax withholding obligations will be available for delivery pursuant to other awards. The LTIP is administered by the board of directors of the General Partner or a committee thereof.

For the three months ended March 31, 2018, the Partnership incurred $1.3 million of unit–based compensation.

Phantom Units

Under the LTIP, the board of directors of the General Partner is authorized to issue phantom units to eligible employees and non-employee directors. The Partnership estimates the fair value of phantom units as the closing price of the Partnership’s common units on the grant date of the award, which is expensed over the applicable vesting period. Upon vesting the phantom units entitle the recipient to one common unit of the Partnership for each phantom unit.

The following table presents the phantom unit activity under the LTIP for the three months ended March 31, 2018:



	Phantom Units		Weighted Average Grant-Date Fair Value
Unvested at December 31, 2017	105,439		$	17.10
Granted	101,403		$	23.18
Vested	(39,147	)	$	22.30
Unvested at March 31, 2018	167,695		$	19.56

The aggregate fair value of phantom units that vested during the three months ended March 31, 2018 was $0.9 million. As of March 31, 2018, the unrecognized compensation cost related to unvested phantom units was $2.4 million. Such cost is expected to be recognized over a weighted-average period of 1.6 years.

Unitholders' Equity and Partnership Distributions

3 Months Ended

Mar. 31, 2018

Equity [Abstract]

Partners' Capital and Partnership Distributions

UNITHOLDERS’ EQUITY AND PARTNERSHIP DISTRIBUTIONS

The Partnership has general partner and common unit partnership interests. The general partner interest is a non-economic interest and is not entitled to any cash distributions.

At March 31, 2018, the Partnership had a total of 113,882,045 common units issued and outstanding, of which 73,150,000 common units were owned by Diamondback, representing approximately 64% of the total Partnership common units outstanding.

The following table summarizes changes in the number of the Partnership’s common units:



	Common Units
Balance at December 31, 2017	113,882,045
Common units vested and issued under the LTIP	—
Balance at March 31, 2018	113,882,045

The board of directors of the General Partner has adopted a policy for the Partnership to distribute all available cash generated on a quarterly basis, beginning with the quarter ended September 30, 2014.

The following table presents information regarding cash distributions approved by the board of directors of the General Partner for the periods presented:



	Amount per Common Unit		Declaration Date	Unitholder Record Date	Payment Date
Q4 2017	$	0.46	January 31, 2018	February 19, 2018	February 26, 2018

Cash distributions will be made to the common unitholders of record on the applicable record date, generally within 60 days after the end of each quarter. Available cash for each quarter will be determined by the board of directors of the General Partner following the end of such quarter. Available cash for each quarter will generally equal Adjusted EBITDA reduced for cash needed for debt service and other contractual obligations and fixed charges and reserves for future operating or capital needs that the board of directors of the General Partner deems necessary or appropriate, if any.

Earnings Per Unit

3 Months Ended

Mar. 31, 2018

Earnings Per Share [Abstract]

Earnings Per Unit

EARNINGS PER UNIT

The net income per common unit on the consolidated statements of operations is based on the net income of the Partnership for the three months ended March 31, 2018 and 2017, since this is the amount of net income that is attributable to the Partnership’s common units.

The Partnership’s net income is allocated wholly to the common units as the General Partner does not have an economic interest. Payments made to the Partnership’s unitholders are determined in relation to the cash distribution policy described in Note 9—Unitholders’ Equity and Partnership Distributions.

Basic net income per common unit is calculated by dividing net income by the weighted-average number of common units outstanding during the period. Diluted net income per common unit gives effect, when applicable, to unvested common units granted under the LTIP.



	Three Months Ended March 31,
	2018		2017
	(In thousands, except per unit amounts)
Net income attributable to the period	$	42,896	$	20,652
Weighted average common units outstanding
Basic weighted average common units outstanding	113,901		94,969
Effect of dilutive securities:
Potential common units issuable	90		10
Diluted weighted average common units outstanding	113,991		94,979
Net income per common unit, basic	$0.38		$0.22
Net income per common unit, diluted	$0.38		$0.22

For the three months ended March 31, 2018 and 2017, there were zero common units and 1,285,515 common units, respectively, that were not included in the computation of diluted earnings per common unit because their inclusion would have been anti-dilutive for the periods presented but could potentially dilute basic earnings per common unit in future periods.

Commitments and Contingencies	3 Months Ended
Commitments and Contingencies	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES The Partnership could be subject to various possible loss contingencies which arise primarily from interpretation of federal and state laws and regulations affecting the natural gas and crude oil industry. Such contingencies include differing interpretations as to the prices at which natural gas and crude oil sales may be made, the prices at which royalty owners may be paid for production from their leases, environmental issues and other matters. Management believes it has complied with the various laws and regulations, administrative rulings and interpretations.

Subsequent Events	3 Months Ended
Subsequent Events	Mar. 31, 2018
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS Cash Distribution On April 5, 2018, the board of directors of the General Partner approved a cash distribution for the first quarter of 2018 of $0.480 per common unit, payable on April 27, 2018, to unitholders of record at the close of business on April 20, 2018. Proposed Tax Status Election and Related Transactions On March 29, 2018, the Partnership announced that the Board of Directors of its General Partner had unanimously approved a change of the Partnership’s federal income tax status from that of a pass-through partnership to that of a taxable entity via a “check the box” election. In connection with making this election, the Partnership will (i) amend and restate its First Amended and Restated Partnership Agreement, (ii) amend and restate the First Amended and Restated Limited Liability Company Agreement of Viper Energy Partners LLC (the “Operating Company”), (iii) amend and restate its existing registration rights agreement with Diamondback and (iv) enter into an exchange agreement with Diamondback, the General Partner and the Operating Company. Simultaneously with the effectiveness of these agreements, Diamondback will deliver and assign to the Partnership the 73,150,000 Common Units it owns in exchange for (i) 73,150,000 newly-issued Class B Units of the Partnership and (ii) 73,150,000 newly-issued units of the Operating Company pursuant to the terms of a Recapitalization Agreement dated March 28, 2018. The Partnership currently expects that the tax status election will be effective on May 10, 2018. The Partnership’s Credit Facility In connection with the Partnership’s spring 2018 redetermination, the agent lender under the credit agreement has recommended that the Partnership’s borrowing base be increased to $475.0 million. This increase is subject to approval of the required other lenders.

Summary of Significant Accounting Policies (Policies)	3 Months Ended
Summary of Significant Accounting Policies (Policies)	Mar. 31, 2018
Accounting Policies [Abstract]
Basis of Accounting [Text Block]	Basis of Presentation The accompanying consolidated financial statements and related notes thereto were prepared in conformity with GAAP. All material intercompany balances and transactions are eliminated in consolidation. These financial statements have been prepared by the Partnership without audit, pursuant to the rules and regulations of the SEC. They reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for interim periods, on a basis consistent with the annual audited financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations, although the Partnership believes the disclosures are adequate to make the information presented not misleading. This Quarterly Report on Form 10–Q should be read in conjunction with the Partnership’s most recent Annual Report on Form 10–K for the fiscal year ended December 31, 2017, which contains a summary of the Partnership’s significant accounting policies and other disclosures.
Use of Estimates	Use of Estimates Certain amounts included in or affecting the Partnership’s financial statements and related disclosures must be estimated by management, requiring certain assumptions to be made with respect to values or conditions that cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts the Partnership reports for assets and liabilities and the Partnership’s disclosure of contingent assets and liabilities at the date of the financial statements. The Partnership evaluates these estimates on an ongoing basis, using historical experience, consultation with experts and other methods the Partnership considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from the Partnership’s estimates. Any effects on the Partnership’s business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Significant items subject to such estimates and assumptions include estimates of proved oil and natural gas reserves and related present value estimates of future net cash flows therefrom, the carrying value of oil and natural gas interests and unit–based compensation.
New Accounting Pronouncements	New Accounting Pronouncements Recently Issued Pronouncements In January 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-01, “Financial Instruments–Overall”. This update applies to any entity that holds financial assets or owes financial liabilities. This update requires equity investments (except for those accounted for under the equity method or those that result in consolidation of the investee) to be measured at fair value with changes in fair value recognized in net income. The Partnership adopted this standard effective January 1, 2018 by means of a negative cumulative-effect adjustment totaling $18.7 million. In November 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-18, “Statement of Cash Flows - Restricted Cash”. This update affects entities that have restricted cash or restricted cash equivalents. The Partnership adopted this update effective January 1, 2018. The adoption of this update did not have an effect on the presentation on the Statement of Cash Flows. In January 2017, the Financial Accounting Standards Board issued Accounting Standards Update 2017-01, “Business Combinations - Clarifying the Definition of a Business”. This update apples to all entities that must determine whether they acquired or sold a business. This update provides a screen to determine when a set is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business. The Partnership adopted this update prospectively effective January 1, 2018. The adoption of this update did not have an impact on its financial position, results of operations or liquidity. Accounting Pronouncements Not Yet Adopted In February 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-02, “Leases”. This update applies to any entity that enters into a lease, with some specified scope exemptions. Under this update, a lessee should recognize in the statement of financial position a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. While there were no major changes to the lessor accounting, changes were made to align key aspects with the revenue recognition guidance. This update will be effective for public entities for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, with early adoption permitted. Entities will be required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. As of March 31, 2018, the Partnership was not the lessor or lessee of any leases other than mineral leases which were excluded from the scope of this Accounting Standards Update. Therefore, the Partnership believes the adoption of this update will not have an impact on its financial position, results of operations or liquidity. In January 2018, the Financial Accounting Standards Board issued Accounting Standards Update 2018-01, “Leases - Land Easement Practical Expedient for Transition to Topic 842”. This update applies to any entity that holds land easements. The update allows entities to adopt a practical expedient to not evaluate existing or expired land easements under Topic 842 that were not previously accounted for as leases under the current leases guidance. An entity that elects this practical expedient should evaluate new or modified land easements under Topic 842 beginning at the date that the entity adopts Topic 842. The Partnership believes the adoption of this update will not have an impact on its financial position, results of operations or liquidity. In June 2016, the Financial Accounting Standards Board issued Accounting Standards Update 2016-13, “Financial Instruments - Credit Losses”. This update affects entities holding financial assets and net investment in leases that are not accounted for at fair value through net income. The amendments affect loans, debt securities, trade receivables, net investments in leases, off-balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. This update will be effective for financial statements issued for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. This update will be applied through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. The Partnership does not believe the adoption of this standard will have an impact on its financial statements since it does not have a history of credit losses.
Cost Method Investments, Policy [Policy Text Block]	Investments The Partnership has an equity interest in a limited partnership that is so minor that the Partnership has no influence over the limited partnership’s operating and financial policies. This interest was acquired during the year ended December 31, 2014 and is accounted for under the cost method. Effective January 1, 2018, the Partnership adopted Accounting Standards Update 2016-01 which requires the Partnership to measure this investment at fair value which resulted in a downward adjustment of $18.7 million to record the impact of this adoption. For the three months ended March 31, 2018, the Partnership recorded a gain of $0.9 million which then increased the Partnership’s investment balance to $16.0 million, which is included in other assets in the accompanying consolidated balance sheets.
Revenue Recognition, Policy [Policy Text Block]	Royalty income represents the right to receive revenues from oil, natural gas and natural gas liquids sales obtained by the operator of the wells in which the Partnership owns a royalty interest. Royalty income is recognized at the point control of the product is transferred to the purchaser. Virtually all of the Partnership’s contracts’ pricing provisions are tied to a market index. Royalty income from oil, natural gas and natural gas liquids sales The Partnership’s oil, natural gas and natural gas liquids sales contracts are generally structured whereby the producer of the properties in which the Partnership owns a royalty interest sells the Partnership’s proportionate share of oil, natural gas and natural gas liquids production to the purchaser and the Partnership collects its percentage royalty based on the revenue generated by the sale of the oil, natural gas and natural gas liquids. In this scenario, the Partnership recognizes revenue when control transfers to the purchaser at the wellhead or at the gas processing facility based on the Partnership’s percentage ownership share of the revenue. Transaction price allocated to remaining performance obligations The Partnership’s right to royalty income does not originate until production occurs and, therefore, is not considered to exist beyond each days’ production. Therefore, there are no remaining performance obligation under any of our royalty income contracts. Contract balances Under the Partnership’s royalty income contracts, it would have the right to receive royalty income from the producer once production has occurred, at which point payment is unconditional. Accordingly, the Partnership’s royalty income contracts do not give rise to contract assets or liabilities under Accounting Standards Codification 606. Prior-period performance obligations The Partnership records revenue in the month production is delivered to the purchaser. However, settlement statements for certain natural gas and natural gas liquids sales may not be received for 30 to 90 days after the date production is delivered, and as a result, the Partnership is required to estimate the amount of royalty income to be received based upon the Partnership’s interest. The Partnership records the differences between its estimates and the actual amounts received for royalties in the month that payment is received from the producer. The Partnership has existing internal controls for its revenue estimation process and related accruals, and any identified differences between its revenue estimates and actual revenue received historically have not been significant. For the three months ended March 31, 2018, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material. The Partnership believes that the pricing provisions of its oil, natural gas and natural gas liquids contracts are customary in the industry. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the royalties related to expected sales volumes and prices for those properties are estimated and recorded.

Oil and Natural Gas Interests (Tables)

3 Months Ended

Mar. 31, 2018

Extractive Industries [Abstract]

Aggregate capitalized costs related to oil and natural gas production activities

Oil and natural gas interests include the following:



	March 31,			December 31,
	2018			2017

	(in thousands)
Oil and natural gas interests:
Subject to depletion	$	627,411		$	589,173
Not subject to depletion	630,916			514,724
Gross oil and natural gas interests	1,258,327			1,103,897
Accumulated depletion and impairment	(200,992		)	(189,466		)
Oil and natural gas interests, net	$	1,057,335		$	914,431

Balance of acquisition costs not subject to depletion
Incurred in 2018	$	120,802
Incurred in 2017	284,371
Incurred in 2016	158,157
Incurred in 2015	28,806
Incurred in 2014	38,780
Total not subject to depletion	$	630,916

Unitholders' Equity and Partnership Distributions (Tables)

3 Months Ended

Mar. 31, 2018

Distribution Made to Limited Partner [Line Items]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

The following table presents information regarding cash distributions approved by the board of directors of the General Partner for the periods presented:



	Amount per Common Unit		Declaration Date	Unitholder Record Date	Payment Date
Q4 2017	$	0.46	January 31, 2018	February 19, 2018	February 26, 2018

Schedule of changes in common units

The following table summarizes changes in the number of the Partnership’s common units:



	Common Units
Balance at December 31, 2017	113,882,045
Common units vested and issued under the LTIP	—
Balance at March 31, 2018	113,882,045

Earnings Per Unit (Tables)

3 Months Ended

Mar. 31, 2018

Earnings Per Share [Abstract]

Schedule of basic and diluted net income per common unit



	Three Months Ended March 31,
	2018		2017
	(In thousands, except per unit amounts)
Net income attributable to the period	$	42,896	$	20,652
Weighted average common units outstanding
Basic weighted average common units outstanding	113,901		94,969
Effect of dilutive securities:
Potential common units issuable	90		10
Diluted weighted average common units outstanding	113,991		94,979
Net income per common unit, basic	$0.38		$0.22
Net income per common unit, diluted	$0.38		$0.22

Organization and Basis of Presentation (Details)	3 Months Ended
Organization and Basis of Presentation (Details)	Mar. 31, 2018
Parent Company [Member]
Limited Partners' Capital Account [Line Items]
Percent of limited partnership interest	64.00%
General Partner
Limited Partners' Capital Account [Line Items]
Percent of General Partner interest	100.00%

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Investment [Line Items]
Gain on revaluation of investment	$ 899	$ 0
Other Noncurrent Assets [Member]
Investment [Line Items]
Cost Method Investments	15,974
Limited Partner [Member]
Investment [Line Items]
Impact of adoption of ASU 2016-01	$ (18,651)

- Definition

This item represents the net total realized and unrealized gain (loss) included in earnings for the period as a result of selling or holding marketable securities categorized as trading, available-for-sale, or held-to-maturity, including the unrealized holding gain (loss) of held-to-maturity securities transferred to the trading security category and the cumulative unrealized gain (loss) which was included in other comprehensive income (a separate component of shareholders' equity) for available-for-sale securities transferred to trading securities during the period. Additionally, this item would include any gains (losses) realized during the period from the sale of investments accounted for under the cost method of accounting and losses recognized for other than temporary impairments (OTTI) of the subject investments.

+ References + Details

Acquisitions (Details) - Series of Individually Immaterial Business Acquisitions [Member] $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) a
Business Acquisition [Line Items]
Mineral Properties Acquired, Net Royalty Acres	967
Consideration transferred \| $	$ 158.1
Mineral Properties, Net Royalty Acres	10,537

Oil and Natural Gas Interests (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Oil and Natural gas interests subject to depletion	$ 627,411	$ 589,173
Oil and natural gas not subject to depletion	630,916	514,724
Gross oil and natural gas interests	1,258,327	1,103,897
Accumulated depletion and impairment	(200,992)	(189,466)
Oil and natural gas interests, net	1,057,335	914,431
Balance of acquisition costs not subject to depletion	$ 120,802	$ 284,371	$ 158,157	$ 28,806	$ 38,780
Minimum [Member]
Property, Plant and Equipment [Line Items]
Anticipated number of years of inclusion of costs in amortization calculation	3
Maximum [Member]
Property, Plant and Equipment [Line Items]
Anticipated number of years of inclusion of costs in amortization calculation	5

Debt - Credit Facility (Details) $ in Millions	3 Months Ended
Debt - Credit Facility (Details) $ in Millions	Mar. 31, 2018 USD ($) redetermindation
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 2,000.0
Current borrowing capacity	$ 400.0
Number of additional redeterminations that may be requested \| redetermindation	3
Period of redeterminations	12 months
Amount outstanding under credit facility	$ 240.5
Remaining borrowing capacity	$ 159.5
Federal Funds Effective Swap Rate [Member]
Line of Credit Facility [Line Items]
Basis spread on variable rate	0.50%
LIBOR [Member]
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.00%
Minimum [Member]
Line of Credit Facility [Line Items]
Commitment fee on the unused portion of the borrowing base	0.375%
Minimum [Member] \| LIBOR [Member]
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.75%
Minimum [Member] \| Base Rate [Member]
Line of Credit Facility [Line Items]
Basis spread on variable rate	0.75%
Maximum [Member]
Line of Credit Facility [Line Items]
Commitment fee on the unused portion of the borrowing base	0.50%
Maximum [Member] \| LIBOR [Member]
Line of Credit Facility [Line Items]
Basis spread on variable rate	2.75%
Maximum [Member] \| Base Rate [Member]
Line of Credit Facility [Line Items]
Basis spread on variable rate	1.75%

Debt - Financial Covenants (Details) $ in Millions	Mar. 31, 2018 USD ($)
Line of Credit Facility [Line Items]
Maximum issuance of unsecured debt	$ 400.0
Reduction of borrowing base	25.00%
Maximum [Member]
Line of Credit Facility [Line Items]
Ratio of total debt to EBITDAX, not greater than 4.0	4.0
Minimum [Member]
Line of Credit Facility [Line Items]
Ratio of current assets to liabilities, not less than 1.0	1.0

Related Party Transactions (Details)	3 Months Ended
Related Party Transactions (Details)	Mar. 31, 2018 USD ($)	Mar. 31, 2017 USD ($)
General Partner \| Partnership Agreement [Member]
Related Party Transaction [Line Items]
Incurred costs for transactions with related party	$ 615,000	$ 615,000
Affiliated Entity, Wexford [Member] \| Advisory Services Agreement [Member]
Related Party Transaction [Line Items]
Incurred costs for transactions with related party	0	0
Advisory services agreement, annual fee	$ 500,000
Term of advisory services agreement	2 years
Renewal term of advisory services agreement	1 year
Minimum period for cancellation of additional one-year periods	10 days
Agreement termination, written notice period	30 days
Diamondback Energy, Inc.
Related Party Transaction [Line Items]
Revenue from Related Parties	$ 0	$ 1,500
Number of leases extended		1
Average price per acre		$ 400

Unit-Based Compensation (Details) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($) $ / shares shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common units reserved for issuance	9,070,356
Unit-based compensation \| $	$ 1.3
Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Unvested at December 31, 2017	105,439
Granted	101,403
Vested	(39,147)
Unvested at March 31, 2018	167,695
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Unvested at December 31, 2017 \| $ / shares	$ 17.10
Granted \| $ / shares	23.18
Vested \| $ / shares	22.30
Unvested at March 31, 2018 \| $ / shares	$ 19.56
Equity Instruments Other than Options, Vested in Period, Fair Value \| $	$ 0.9
Nonvested Awards, Compensation Cost Not yet Recognized \| $	$ 2.4
Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	1 year 7 months 17 days

Unitholders' Equity and Partnership Distributions (Details) - shares	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Limited Partners' Capital Account [Line Items]
Total common units issued	113,882,045	113,882,045
Common units outstanding	113,882,045	113,882,045
Common units vested and issued under the LTIP	0
Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Units of Partnership Interest, Amount	73,150,000
Percent of limited partnership interest	64.00%

Unitholders' Equity and Partnership Distributions Partnership Distributions (Details) - Cash Distribution [Member]	3 Months Ended
	Mar. 31, 2018 $ / shares
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.46
Distribution Made to Limited Partner, Declaration Date	Jan. 31, 2018
Distribution Made to Limited Partner, Date of Record	Feb. 19, 2018
Distribution Made to Limited Partner, Distribution Date	Feb. 26, 2018
Distribution Made to Limited Partner, Distribution Date, Period after Quarter End	60 days

Earnings Per Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Earnings Per Share [Abstract]
Net income attributable to the period	$ 42,896	$ 20,652
Basic weighted average common units outstanding	113,901,000	94,969,000
Effect of dilutive securities: contingently issuable units	90,000	10,000
Diluted weighted average common units outstanding	113,991,000	94,979,000
Net income per common unit, basic	$ 0.38	$ 0.22
Net income per common unit, diluted	$ 0.38	$ 0.22
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	1,285,515

Subsequent Events Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	May 10, 2018	Apr. 27, 2018
Subsequent Event [Line Items]
Current borrowing capacity		$ 400.0
Cash Distribution [Member]
Subsequent Event [Line Items]
Distribution Made to Limited Partner, Declaration Date		Jan. 31, 2018
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0.46
Distribution Made to Limited Partner, Distribution Date		Feb. 26, 2018
Distribution Made to Limited Partner, Date of Record		Feb. 19, 2018
Subsequent Event [Member]
Subsequent Event [Line Items]
Current borrowing capacity				$ 475.0
Subsequent Event [Member] \| Cash Distribution [Member]
Subsequent Event [Line Items]
Distribution Made to Limited Partner, Declaration Date	Apr. 05, 2018
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.480
Distribution Made to Limited Partner, Distribution Date	Apr. 27, 2018
Distribution Made to Limited Partner, Date of Record	Apr. 20, 2018
Parent Company [Member]
Subsequent Event [Line Items]
Units of Partnership Interest, Amount		73,150,000
Parent Company [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Units of Partnership Interest, Amount			73,150,000
Class of Warrant or Right, Outstanding			73,150,000