Form 10-Q - Quarterly report [Sections 13 or 15(d)]

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


☒			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended June 30, 2023


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF SECURITIES EXCHANGE ACT OF 1934

Commission File Number 001-36505

Viper Energy Partners LP

(Exact Name of Registrant As Specified in Its Charter)

46-5001985

(State or Other Jurisdiction of Incorporation or Organization)

(I.R.S. Employer Identification Number)

500 West Texas Ave.

Suite 100

Midland, TX

79701

(Address of principal executive offices)

(Zip code)

(432) 221-7400

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

Common Units

VNOM

The Nasdaq Stock Market LLC

(NASDAQ Global Select Market)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check One):

Large Accelerated Filer

☒

Accelerated Filer

☐

Non-Accelerated Filer

☐

Smaller Reporting Company

☐

Emerging Growth Company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

As of July 28, 2023, the registrant had outstanding 70,904,057 common units representing limited partner interests and 90,709,946 Class B units representing limited partner interests.

VIPER ENERGY PARTNERS LP

FORM 10-Q

FOR THE QUARTER ENDED JUNE 30, 2023

TABLE OF CONTENTS


			Page
Glossary of Oil and Natural Gas Terms			ii
Glossary of Certain Other Terms			iii
Cautionary Statement Regarding Forward-Looking Statements			iv

PART I. FINANCIAL INFORMATION
Item 1. Condensed Consolidated Financial Statements (Unaudited)			1
Condensed Consolidated Balance Sheets			1
Condensed Consolidated Statements of Operations			2
Condensed Consolidated Statements of Changes to Unitholders’ Equity			3
Condensed Consolidated Statements of Cash Flows			5
Condensed Notes to Consolidated Financial Statements			6

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			17

Item 3. Quantitative and Qualitative Disclosures about Market Risk			27

Item 4. Controls and Procedures			28

PART II. OTHER INFORMATION
Item 1. Legal Proceedings			29

Item 1A. Risk Factors			29

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			29

Item 5. Other Information			29

Item 6. Exhibits			30

Signatures			31

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GLOSSARY OF OIL AND NATURAL GAS TERMS

The following is a glossary of certain oil and natural gas terms that are used in this Quarterly Report on Form 10-Q (this “report”):



Argus WTI Midland			Grade of oil that serves as a benchmark price for oil at Midland, Texas.
Basin			A large depression on the earth’s surface in which sediments accumulate.
Bbl or barrel			One stock tank barrel, or 42 U.S. gallons liquid volume, used in this report in reference to crude oil or other liquid hydrocarbons.

BO			One barrel of oil.
BO/d			BO per day.
BOE			One barrel of oil equivalent, with six thousand cubic feet of natural gas being equivalent to one barrel of oil.
BOE/d			BOE per day.
British Thermal Unit or Btu			The quantity of heat required to raise the temperature of one pound of water by one degree Fahrenheit.

Condensate			Liquid hydrocarbons associated with the production of a primarily natural gas reserve.

















Henry Hub			Natural gas gathering point that serves as a benchmark price for natural gas futures on the NYMEX.
Horizontal wells			Wells drilled directionally horizontal to allow for development of structures not reachable through traditional vertical drilling mechanisms.

MBbls			Thousand barrels of crude oil or other liquid hydrocarbons.
MBOE			One thousand barrels of crude oil equivalent, determined using a ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or natural gas liquids.
Mcf			One thousand cubic feet of natural gas.

Mineral interests			The interests in ownership of the resource and mineral rights, giving an owner the right to profit from the extracted resources.
MMBtu			One million British Thermal Units.
MMcf			Million cubic feet of natural gas.




Net royalty acres			Net mineral acres multiplied by the average lease royalty interest and other burdens.
Oil and natural gas properties			Tracts of land consisting of properties to be developed for oil and natural gas resource extraction.
Operator			The individual or company responsible for the exploration and/or production of an oil or natural gas well or lease.







Proved reserves			The estimated quantities of oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be commercially recoverable in future years from known reservoirs under existing economic and operating conditions.


Reserves			The estimated remaining quantities of oil and natural gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and natural gas or related substances to the market and all permits and financing required to implement the project. Reserves are not assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).
Reservoir			A porous and permeable underground formation containing a natural accumulation of producible natural gas and/or crude oil that is confined by impermeable rock or water barriers and is separate from other reservoirs.

Royalty interest			An interest that gives an owner the right to receive a portion of the resources or revenues without having to carry any costs of development, which may be subject to expiration.
Spud			Commencement of actual drilling operations.
Waha Hub			Natural gas gathering point that serves as a benchmark price for natural gas at western Texas and New Mexico.






WTI			West Texas Intermediate, a light sweet blend of oil produced from fields in western Texas and is a grade of oil that serves as a benchmark for oil on the NYMEX.
WTI Cushing			Grade of oil that serves as a benchmark price for oil at Cushing, Oklahoma.

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GLOSSARY OF CERTAIN OTHER TERMS

The following is a glossary of certain other terms that are used in this report:





ASU			Accounting Standards Update.

Exchange Act			The Securities Exchange Act of 1934, as amended.
GAAP			Accounting principles generally accepted in the United States.



LTIP			Viper Energy Partners LP Long Term Incentive Plan.
Nasdaq			The Nasdaq Global Select Market.
NYMEX			New York Mercantile Exchange.
OPEC			Organization of the Petroleum Exporting Countries.
Operating Company			Viper Energy Partners LLC, a Delaware limited liability company and a consolidated subsidiary of Viper Energy Partners LP.



SEC			United States Securities and Exchange Commission.

SOFR			The secured overnight financing rate
Notes			The 5.375% Senior Notes due 2027 issued on October 16, 2019.

iii

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

Various statements contained in this report are “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act, which involve risks, uncertainties, and assumptions. All statements, other than statements of historical fact, including statements regarding our: future performance; business strategy; future operations; estimates and projections of operating income, losses, costs and expenses, returns, cash flow, and financial position; production levels on properties in which we have mineral and royalty interests, developmental activity by other operators; reserve estimates and our ability to replace or increase reserves; our intent to convert into a corporate structure and expectations regarding the timing of such conversion, potential inclusion into certain indices and benchmarks, trading liquidity, tax treatment for our public unitholders post-conversion and related statements; anticipated benefits other of strategic transactions (including acquisitions and divestitures); and plans and objectives of management (including Diamondback’s plans for developing our acreage and our cash distribution policy and repurchases of our common units and/or senior notes) are forward-looking statements. When used in this report, the words “aim,” “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “future,” “guidance,” “intend,” “may,” “model,” “outlook,” “plan,” “positioned,” “potential,” “predict,” “project,” “seek,” “should,” “target,” “will,” “would,” and similar expressions (including the negative of such terms) as they relate to us are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. In particular, the factors discussed in this report and detailed under Part II. Item 1A. Risk Factors, and our Annual Report on Form 10-K for the year ended December 31, 2022, could affect our actual results and cause our actual results to differ materially from expectations, estimates or assumptions expressed, forecasted or implied in such forward-looking statements. Unless the context requires otherwise, references to “we,” “us,” “our” or “the Partnership” are intended to mean the business and operations of the Partnership and the Operating Company.

Factors that could cause the outcomes to differ materially include (but are not limited to) the following:

•changes in supply and demand levels for oil, natural gas, and natural gas liquids, and the resulting impact on the price for those commodities;

•the impact of public health crises, including epidemic or pandemic diseases and any related company or government policies or actions;

•actions taken by the members of OPEC and Russia affecting the production and pricing of oil, as well as other domestic and global political, economic, or diplomatic developments;

•changes in general economic, business or industry conditions, including changes in foreign currency exchange rates, interest rates, inflation rates, instability in the financial sector and concerns over a potential economic downturn or recession;

•regional supply and demand factors, including delays, curtailment delays or interruptions of production on our mineral and royalty acreage, or governmental orders, rules or regulations that impose production limits on such acreage;

•federal and state legislative and regulatory initiatives relating to hydraulic fracturing, including the effect of existing and future laws and governmental regulations;

•physical and transition risks relating to climate change;

•restrictions on the use of water, including limits on the use of produced water by our operators and a moratorium on new produced water well permits recently imposed by the Texas Railroad Commission in an effort to control induced seismicity in the Permian Basin;

•significant declines in prices for oil, natural gas, or natural gas liquids, which could require recognition of significant impairment charges;

•changes in U.S. energy, environmental, monetary and trade policies;

•conditions in the capital, financial and credit markets, including the availability and pricing of capital for drilling and development by our operators and environmental and social responsibility projects undertaken by Diamondback and our other operators;

•changes in availability or cost of rigs, equipment, raw materials, supplies and oilfield services impacting our operators;

•changes in safety, health, environmental, tax, and other regulations or requirements impacting us or our operators (including those addressing air emissions, water management, or the impact of global climate change);

•security threats, including cybersecurity threats and disruptions to our business from breaches of our information technology systems, or from breaches of information technology systems of our operators or third parties with whom we transact business;

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•lack of, or disruption in, access to adequate and reliable transportation, processing, storage, and other facilities impacting our operators;

•severe weather conditions;

•acts of war or terrorist acts and the governmental or military response thereto;

•changes in the financial strength of counterparties to the credit agreement and hedging contracts of our operating subsidiary;

•changes in our credit rating; and

•other risks and factors disclosed in this report.

In light of these factors, the events anticipated by our forward-looking statements may not occur at the time anticipated or at all. Moreover, new risks emerge from time to time. We cannot predict all risks, nor can we assess the impact of all factors on our business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those anticipated by any forward-looking statements we may make. Accordingly, you should not place undue reliance on any forward-looking statements made in this report. All forward-looking statements speak only as of the date of this report or, if earlier, as of the date they were made. We do not intend to, and disclaim any obligation to, update or revise any forward-looking statements unless required by applicable law.

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PART I. FINANCIAL INFORMATION

ITEM 1. CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Viper Energy Partners LP

Condensed Consolidated Balance Sheets

(Unaudited)


	June 30,		December 31,
	2023		2022
	(In thousands, except unit amounts)
Assets
Current assets:
Cash and cash equivalents	$	13,079	$	18,179

Royalty income receivable (net of allowance for credit losses)	80,765		81,657
Royalty income receivable—related party	4,384		6,260
Derivative instruments	—		9,328
Other current assets	7,566		3,196
Total current assets	105,794		118,620
Property:
Oil and natural gas interests, full cost method of accounting ($1,195,923 and $1,297,221 excluded from depletion at June 30, 2023 and December 31, 2022, respectively)	3,590,476		3,464,819
Land	5,688		5,688
Accumulated depletion and impairment	(785,286)		(720,234)
Property, net	2,810,878		2,750,273

Derivative instruments	—		442
Deferred income taxes (net of allowances)	49,124		49,656
Other assets	1,242		1,382
Total assets	$	2,967,038	$	2,920,373
Liabilities and Unitholders’ Equity
Current liabilities:
Accounts payable	$	19	$	1,129
Accounts payable—related party	—		306
Accrued liabilities	18,127		19,600
Derivative instruments	8,349		—
Income taxes payable	1,584		911
Total current liabilities	28,079		21,946
Long-term debt, net	649,416		576,895

Derivative instruments	3,373		7
Total liabilities	680,868		598,848
Commitments and contingencies (Note 12)

Unitholders’ equity:
General Partner	609		649
Common units (71,206,622 units issued and outstanding as of June 30, 2023 and 73,229,645 units issued and outstanding as of December 31, 2022)	665,511		689,178
Class B units (90,709,946 units issued and outstanding as of June 30, 2023 and December 31, 2022)	782		832
Total Viper Energy Partners LP unitholders’ equity	666,902		690,659
Non-controlling interest	1,619,268		1,630,866
Total equity	2,286,170		2,321,525
Total liabilities and unitholders’ equity	$	2,967,038	$	2,920,373

See accompanying notes to condensed consolidated financial statements.

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Viper Energy Partners LP

Condensed Consolidated Statements of Operations

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Operating income:
Royalty income	$	158,197	$	238,830	$	319,282	$	431,919
Lease bonus income—related party	1,277		—		8,348		6,280
Lease bonus income	1,134		329		1,534		2,731

Other operating income	179		163		581		295
Total operating income	160,787		239,322		329,745		441,225
Costs and expenses:
Production and ad valorem taxes	12,621		16,039		25,508		29,909

Depletion	34,064		31,962		65,051		59,373

General and administrative expenses	2,008		1,880		4,772		3,833

Total costs and expenses	48,693		49,881		95,331		93,115
Income (loss) from operations	112,094		189,441		234,414		348,110
Other income (expense):
Interest expense, net	(11,291)		(9,782)		(20,977)		(19,427)


Gain (loss) on derivative instruments, net	(12,594)		(1,889)		(27,697)		(20,248)

Other income, net	172		32		313		38
Total other expense, net	(23,713)		(11,639)		(48,361)		(39,637)
Income (loss) before income taxes	88,381		177,802		186,053		308,473
Provision for (benefit from) income taxes	8,450		6,182		17,856		8,812
Net income (loss)	79,931		171,620		168,197		299,661
Net income (loss) attributable to non-controlling interest	49,381		137,598		103,680		249,034
Net income (loss) attributable to Viper Energy Partners LP	$	30,550	$	34,022	$	64,517	$	50,627

Net income (loss) attributable to common limited partner units:
Basic	$	0.42	$	0.44	$	0.89	$	0.66
Diluted	$	0.42	$	0.44	$	0.89	$	0.66
Weighted average number of common limited partner units outstanding:
Basic	71,771		76,620		72,249		76,861
Diluted	71,771		76,729		72,249		76,978

See accompanying notes to condensed consolidated financial statements.

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Viper Energy Partners LP

Condensed Consolidated Statements of Changes to Unitholders' Equity

(Unaudited)


	Limited Partners						General Partner		Non-Controlling Interest
	Common			Class B			Amount		Amount
	Units	Amount		Units	Amount						Total
	(In thousands)
Balance at December 31, 2022	73,230	$	689,178	90,710	$	832	$	649	$	1,630,866	$	2,321,525

Unit-based compensation	—	370		—	—		—		—		370
Vesting of restricted stock units	4	—		—	—		—		—		—
Distribution equivalent rights payments	—	(72)		—	—		—		—		(72)
Distributions to public	—	(35,253)		—	—		—		—		(35,253)
Distributions to Diamondback	—	(358)		—	(25)		—		(48,983)		(49,366)
Distributions to General Partner	—	—		—	—		(20)		—		(20)
Change in ownership of consolidated subsidiaries, net	—	11,449		—	—		—		(11,449)		—

Repurchased units as part of unit buyback	(1,115)	(33,022)		—	—		—		—		(33,022)
Net income (loss)	—	33,967		—	—		—		54,299		88,266
Balance at March 31, 2023	72,119	666,259		90,710	807		629		1,624,733		2,292,428

Unit-based compensation	—	259		—	—		—		—		259

Distribution equivalent rights payments	—	(43)		—	—		—		—		(43)
Distributions to public	—	(23,513)		—	—		—		—		(23,513)
Distributions to Diamondback	—	(241)		—	(25)		—		(38,097)		(38,363)
Distributions to General Partner	—	—		—	—		(20)		—		(20)
Change in ownership of consolidated subsidiaries, net	—	16,749		—	—		—		(16,749)		—

Repurchased units as part of unit buyback	(912)	(24,509)		—	—		—		—		(24,509)
Net income (loss)	—	30,550		—	—		—		49,381		79,931
Balance at June 30, 2023	71,207	$	665,511	90,710	$	782	$	609	$	1,619,268	$	2,286,170

See accompanying notes to condensed consolidated financial statements.

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Viper Energy Partners LP

Condensed Consolidated Statements of Changes to Unitholders' Equity - (Continued)

(Unaudited)


	Limited Partners						General Partner		Non-Controlling Interest
	Common			Class B			Amount		Amount
	Units	Amount		Units	Amount						Total
	(In thousands)
Balance at December 31, 2021	78,546	$	813,161	90,710	$	931	$	729	$	1,418,007	$	2,232,828

Unit-based compensation	—	284		—	—		—		—		284

Distribution equivalent rights payments	—	(64)		—	—		—		—		(64)
Distributions to public	—	(35,830)		—	—		—		—		(35,830)
Distributions to Diamondback	—	(344)		—	(25)		—		(42,634)		(43,003)
Distributions to General Partner	—	—		—	—		(20)		—		(20)
Change in ownership of consolidated subsidiaries, net	—	14,195		—	—		—		(14,195)		—

Repurchased units as part of unit buyback	(1,580)	(39,260)		—	—		—		—		(39,260)
Net income (loss)	—	16,605		—	—		—		111,436		128,041
Balance at March 31, 2022	76,966	768,747		90,710	906		709		1,472,614		2,242,976

Unit-based compensation	—	335		—	—		—		—		335
Distribution equivalent rights payments	—	(113)		—	—		—		—		(113)
Distributions to public	—	(51,077)		—	—		—		—		(51,077)
Distributions to Diamondback	—	(490)		—	(25)		—		(63,497)		(64,012)
Distributions to General Partner	—	—		—	—		(20)		—		(20)
Change in ownership of consolidated subsidiaries, net	—	11,523		—	—		—		(11,523)		—
Repurchased units as part of unit buyback	(1,020)	(28,949)			—		—		—		(28,949)
Net income (loss)	—	34,022		—	—		—		137,598		171,620
Balance at June 30, 2022	75,946	$	733,998	90,710	$	881	$	689	$	1,535,192	$	2,270,760

See accompanying notes to condensed consolidated financial statements.

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Viper Energy Partners LP

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,
	2023		2022
	(In thousands)
Cash flows from operating activities:
Net income (loss)	$	168,197	$	299,661
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Provision for (benefit from) deferred income taxes	532		—
Depletion	65,051		59,373

(Gain) loss on derivative instruments, net	27,697		20,248
Net cash receipts (payments) on derivatives	(6,212)		(17,029)






Other	1,222		2,893
Changes in operating assets and liabilities:

Royalty income receivable	892		(53,876)
Royalty income receivable—related party	1,876		(8,445)


Accounts payable and accrued liabilities	(2,583)		(5,580)

Accounts payable—related party	(306)		—
Income tax payable	673		2,288

Other	(4,370)		(513)
Net cash provided by (used in) operating activities	252,669		299,020
Cash flows from investing activities:

Acquisitions of oil and natural gas interests—related party	(75,073)		—
Acquisitions of oil and natural gas interests	(48,609)		1,862



Proceeds from sale of oil and natural gas interests	(1,975)		29,336

Other	1,200		—
Net cash provided by (used in) investing activities	(124,457)		31,198
Cash flows from financing activities:
Proceeds from borrowings under credit facility	191,000		144,000
Repayment on credit facility	(119,000)		(198,000)

Repayment of senior notes	—		(48,963)








Repurchased units as part of unit buyback	(57,531)		(68,209)
Distributions to public	(58,881)		(87,084)
Distributions to Diamondback	(87,729)		(107,015)
Other	(1,171)		(83)
Net cash provided by (used in) financing activities	(133,312)		(365,354)
Net increase (decrease) in cash and cash equivalents	(5,100)		(35,136)
Cash, cash equivalents and restricted cash at beginning of period	18,179		39,448
Cash, cash equivalents and restricted cash at end of period	$	13,079	$	4,312

See accompanying notes to condensed consolidated financial statements.

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Viper Energy Partners LP

Condensed Notes to Consolidated Financial Statements

(Unaudited)

1. ORGANIZATION AND BASIS OF PRESENTATION

Organization

Viper Energy Partners LP (the “Partnership”) is a publicly traded Delaware limited partnership focused on owning and acquiring mineral interests and royalty interests in oil and natural gas properties primarily in the Permian Basin.

As of June 30, 2023, Viper Energy Partners GP LLC (the “General Partner”) held a 100% general partner interest in the Partnership and Diamondback Energy, Inc. (“Diamondback”) beneficially owned approximately 57% of the Partnership’s total limited partner units outstanding. Diamondback owns and controls the General Partner.

Basis of Presentation

The accompanying condensed consolidated financial statements and related notes thereto were prepared in accordance with GAAP. All material intercompany balances and transactions have been eliminated upon consolidation. We report our operations in one reportable segment.

These condensed consolidated 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 SEC rules and regulations, although the Partnership believes the disclosures are adequate to make the information presented not misleading. This report should be read in conjunction with the Partnership’s most recent Annual Report on Form 10–K for the fiscal year ended December 31, 2022, which contains a summary of the Partnership’s significant accounting policies and other disclosures.

Reclassifications

Certain prior period amounts have been reclassified to conform to the current period financial statement presentation. These reclassifications had no effect on the previously reported total assets, total liabilities, unitholders’ equity, results of operations or cash flows.

2. 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 as of the date of the financial statements.

Making accurate estimates and assumptions is particularly difficult in the oil and natural gas industry given the challenges resulting from volatility in oil and natural gas prices. For instance, the war in Ukraine, rising interest rates, global supply chain disruptions, concerns about a potential economic downturn or recession, and measures to combat persistent inflation and instability in the financial sector have contributed to recent pricing and economic volatility. The financial results of companies in the oil and natural gas industry have been and may continue to be impacted materially as a result of changing market conditions. Such circumstances generally increase uncertainty in the Partnership’s accounting estimates, particularly those involving financial forecasts.

The Partnership evaluates these estimates on an ongoing basis, using historical experience, consultation with experts and other methods the Partnership considers reasonable in each particular circumstance. 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

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Viper Energy Partners LP

Condensed Notes to Consolidated Financial Statements - (Continued)

(Unaudited)

interests, estimates of third party operated royalty income related to expected sales volumes and prices, the recoverability of costs of unevaluated properties, the fair value determination of assets and liabilities, including those acquired by the Partnership, fair value estimates of commodity derivatives and estimates of income taxes, including deferred tax valuation allowances.

Related Party Transactions

Royalty Income Receivable

As of June 30, 2023 and December 31, 2022, Diamondback, either directly or through its consolidated subsidiaries, owed the Partnership $4.4 million and $6.3 million, respectively for royalty income received from third parties for the Partnership’s production, which had not yet been remitted to the Partnership.

Lease Bonus Income

During the three and six months ended June 30, 2023 and the six months ended June 30, 2022, Diamondback, either directly or through its consolidated subsidiaries, paid the Partnership $1.3 million, $8.3 million and $6.3 million, respectively, of lease bonus income primarily related to new leases in the Midland Basin. There was no lease bonus income for the three months ended June 30, 2022.

See Note 4—Acquisitions and Divestitures for significant related party acquisitions of oil and natural gas interests. All other significant related party transactions with Diamondback or its affiliates have been stated on the face of the condensed consolidated financial statements as of June 30, 2023 and for the three and six months ended June 30, 2023 and 2022.

Accrued Liabilities

Accrued liabilities consist of the following:


	June 30,		December 31,
	2023		2022
	(In thousands)
Interest payable	$	4,449	$	3,972
Ad valorem taxes payable	9,963		12,492
Derivatives instruments payable	1,756		1,684
Other	1,959		1,452
Total accrued liabilities	$	18,127	$	19,600

Recent Accounting Pronouncements

Recently Adopted Pronouncements

There are no recently adopted pronouncements.

Accounting Pronouncements Not Yet Adopted

The Partnership considers the applicability and impact of all ASUs. There are no recent accounting pronouncements not yet adopted that are expected to have a material effect on the Partnership upon adoption, as applicable.

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3. REVENUE FROM CONTRACTS WITH CUSTOMERS

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 at the wellhead or at the gas processing facility based on the Partnership’s percentage ownership share of the revenue, net of any deductions for gathering and transportation. Virtually all of the pricing provisions in the Partnership’s contracts are tied to a market index.

The following table disaggregates the Partnership’s total royalty income by product type:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Oil income	$	139,300	$	191,195	$	275,919	$	346,246
Natural gas income	5,090		23,793		14,081		38,983
Natural gas liquids income	13,807		23,842		29,282		46,690
Total royalty income	$	158,197	$	238,830	$	319,282	$	431,919

4. ACQUISITIONS AND DIVESTITURES

2023 Activity

Drop Down Transaction

On March 8, 2023, the Partnership completed the acquisition of certain mineral and royalty interests from subsidiaries of Diamondback for approximately $74.5 million in cash, including customary post-closing adjustments for net title benefits (the ‘‘Drop Down’’). The mineral and royalty interests acquired in the Drop Down represent approximately 660 net royalty acres in Ward County in the Southern Delaware Basin, 100% of which are operated by Diamondback, and have an average net royalty interest of approximately 7.2% and current production of approximately 300 BO/d, approximately 72% of which is from oil. The Partnership funded the Drop Down through a combination of cash on hand and borrowings under the Operating Company’s revolving credit facility. The Drop Down was accounted for as a transaction between entities under common control with the properties acquired recorded at Diamondback’s historical carrying value in the Partnership’s condensed consolidated balance sheet. The historical carrying value of the properties approximated the Drop Down purchase price.

Other Acquisitions

Additionally in the first half of 2023, the Partnership acquired, in individually insignificant transactions from unrelated third-party sellers, mineral and royalty interests representing 203 net royalty acres in the Permian Basin for an aggregate purchase price of approximately $48.1 million, subject to customary post-closing adjustments. The Partnership funded these acquisitions with cash on hand and borrowings under the Operating Company’s revolving credit facility.

2022 Activity

Acquisitions

During the year ended December 31, 2022, in individually insignificant transactions, the Partnership acquired, from unrelated third-party sellers, mineral and royalty interests representing 375 net royalty acres in the Permian Basin for an aggregate net purchase price of approximately $65.8 million, including certain customary post-closing adjustments. The Partnership funded these acquisitions with cash on hand and borrowings under the Operating Company’s revolving credit facility.

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Divestitures

In the first quarter of 2022, the Partnership divested 325 net royalty acres of third party operated acreage located entirely in Upton and Reagan counties in the Midland Basin for an aggregate net sales price of $29.3 million, including customary closing adjustments.

In the third quarter of 2022, the Partnership divested 93 net royalty acres of third party operated acreage located entirely in Loving county in the Delaware Basin for an aggregate net sales price of $29.9 million, including customary closing adjustments.

In the fourth quarter of 2022, the Partnership divested its entire position in the Eagle Ford Shale consisting of 681 net royalty acres of third party operated acreage for an aggregate net sales price of $53.7 million, including customary closing adjustments.

5. OIL AND NATURAL GAS INTERESTS

Oil and natural gas interests include the following:


	June 30,		December 31,
	2023		2022
	(In thousands)
Oil and natural gas interests:
Subject to depletion	$	2,394,553	$	2,167,598
Not subject to depletion	1,195,923		1,297,221
Gross oil and natural gas interests	3,590,476		3,464,819
Accumulated depletion and impairment	(785,286)		(720,234)
Oil and natural gas interests, net	2,805,190		2,744,585
Land	5,688		5,688
Property, net of accumulated depletion and impairment	$	2,810,878	$	2,750,273

As of June 30, 2023 and December 31, 2022, the Partnership had mineral and royalty interests representing 27,178 and 26,315 net royalty acres, respectively.

No impairment expense was recorded on the Partnership’s oil and natural gas interests for the three and six months ended June 30, 2023 and 2022 based on the results of the respective quarterly ceiling tests. In addition to commodity prices, the Partnership’s production rates, levels of proved reserves, transfers of unevaluated properties and other factors will determine its actual ceiling test limitations and impairment analysis in future periods. If the trailing 12-month commodity prices decline as compared to the commodity prices used in prior quarters, the Partnership may have material write-downs in subsequent quarters.

6. DEBT

Long-term debt consisted of the following as of the dates indicated:


	June 30,		December 31,
	2023		2022
	(In thousands)
5.375% senior unsecured notes due 2027	$	430,350	$	430,350
Revolving credit facility	224,000		152,000
Unamortized debt issuance costs	(1,171)		(1,306)
Unamortized discount	(3,763)		(4,149)
Total long-term debt	$	649,416	$	576,895

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The Operating Company’s Revolving Credit Facility

On May 31, 2023, the Operating Company entered into a tenth amendment to the existing credit agreement, which among other things, (i) maintained the maximum credit amount of $2.0 billion, (ii) increased the borrowing base from $580.0 million to $1.0 billion and (iii) increased the elected commitment amount from $500.0 million to $750.0 million. The borrowing base is scheduled to be redetermined semi-annually in May and November. As of June 30, 2023, the Operating Company had $224.0 million of outstanding borrowings and $526.0 million available for future borrowings. During the three and six months ended June 30, 2023 and 2022, the weighted average interest rates on the Operating Company’s revolving credit facility were 7.53%, 7.24%, 3.20% and 2.88%, respectively. The revolving credit facility will mature on June 2, 2025.

As of June 30, 2023, the Operating Company was in compliance with the financial maintenance covenants under its credit agreement.

7. UNITHOLDERS’ EQUITY AND DISTRIBUTIONS

The Partnership has General Partner and limited partner units. At June 30, 2023, the Partnership had a total of 71,206,622 common units issued and outstanding and 90,709,946 Class B units issued and outstanding, of which 731,500 common units and 90,709,946 Class B units were beneficially owned by Diamondback, representing approximately 57% of the Partnership’s total units outstanding. At June 30, 2023, Diamondback also beneficially owns 90,709,946 Operating Company units, representing a 56% non-controlling ownership interest in the Operating Company. The Operating Company units and the Partnership’s Class B units beneficially owned by Diamondback are exchangeable from time to time for the Partnership’s common units (that is, one Operating Company unit and one Partnership Class B unit, together, will be exchangeable for one Partnership common unit).

Common Unit Repurchase Program

The board of directors of the Partnership’s General Partner has approved a common unit repurchase program to acquire up to $750.0 million of the Partnership’s outstanding common units, excluding excise tax, over an indefinite period of time. The Partnership intends to purchase common units under the repurchase program opportunistically with funds from cash on hand, free cash flow from operations and potential liquidity events such as the sale of assets. This repurchase program may be suspended from time to time, modified, extended or discontinued by the board of directors of the Partnership’s General Partner at any time. During the three and six months ended June 30, 2023 and 2022, the Partnership repurchased, excluding excise tax, approximately $24.3 million, $57.0 million, $28.9 million and $68.2 million of common units under the repurchase program, respectively. Repurchases for the six months ended June 30, 2022 include approximately $37.3 million for the repurchase of 1.5 million common units from a significant unitholder in a privately negotiated transaction in the first quarter of 2022. As of June 30, 2023, $472.4 million remains available under the repurchase program, excluding excise tax.

Cash Distributions

Effective with the Partnership’s distribution payable for the third quarter of 2022, the board of directors of the General Partner approved a distribution policy consisting of a base and variable distribution, that takes into account capital returned to unitholders via our common unit repurchase program. For a detailed description of the Partnership’s and the Operating Company’s distribution policy, see Note 7—Unitholders’ Equity and Distributions—Cash Distributions in the Partnership's Annual Report on Form 10-K for the year ended December 31, 2022.

The percentage of cash available for distribution pursuant to the distribution policy may change quarterly to enable the Operating Company to retain cash flow to help strengthen the Partnership’s balance sheet while also expanding the return of capital program through the Partnership’s common unit repurchase program. The Partnership is not required to pay distributions to its common unitholders on a quarterly or other basis.

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The following table presents information regarding cash distributions approved by the board of directors of the General Partner for the periods presented (in thousands, except for per unit amounts):




Period	Amount per Operating Company Unit		Operating Company Distributions to Diamondback		Amount per Common Unit		Distributions to Common Unitholders(1)		Declaration Date	Unitholder Record Date	Payment Date
Q4 2022	$	0.54	$	48,983	$	0.49	$	35,683	February 15, 2023	March 3, 2023	March 10, 2023
Q1 2023	$	0.42	$	38,097	$	0.33	$	23,797	April 26, 2023	May 11, 2023	May 18, 2023

(1)Includes amounts paid to Diamondback for the 731,500 common units beneficially owned by Diamondback and distribution equivalent rights payments.

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.

Change in Ownership of Consolidated Subsidiaries

Non-controlling interest in the accompanying condensed consolidated financial statements represents Diamondback’s ownership in the net assets of the Operating Company. Diamondback’s relative ownership interest in the Operating Company can change due to the Partnership’s public offerings, issuance of units for acquisitions, issuance of unit-based compensation, repurchases of common units and distribution equivalent rights paid on the Partnership’s units. These changes in ownership percentage result in adjustments to non-controlling interest and common unitholder equity, tax effected, but do not impact earnings. The following table summarizes the changes in common unitholder equity due to changes in ownership interest during the period:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Net income (loss) attributable to the Partnership	$	30,550	$	34,022	$	64,517	$	50,627

Change in ownership of consolidated subsidiaries	16,749		11,523		28,198		25,718




Change from net income (loss) attributable to the Partnership's unitholders and transfers to non-controlling interest	$	47,299	$	45,545	$	92,715	$	76,345

8. EARNINGS PER COMMON UNIT

The net income (loss) per common unit on the condensed consolidated statements of operations is based on the net income (loss) attributable to the Partnership’s common units for the three and six months ended June 30, 2023 and 2022. The Partnership’s net income (loss) is allocated wholly to the common units, as the General Partner does not have an economic interest.

Basic and diluted earnings per common unit is calculated using the two-class method. The two class method is an earnings allocation proportional to the respective ownership among holders of common units and participating securities. Basic net income (loss) per common unit is calculated by dividing net income (loss) by the weighted-average number of common units outstanding during the period. Diluted net income (loss) per common unit gives effect, when applicable, to unvested common units granted under the LTIP.

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A reconciliation of the components of basic and diluted earnings per common unit is presented in the table below:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Net income (loss) attributable to the period	$	30,550	$	34,022	$	64,517	$	50,627
Less: distributed and undistributed earnings allocated to participating securities(1)	56		113		123		177
Net income (loss) attributable to common unitholders	$	30,494	$	33,909	$	64,394	$	50,450
Weighted average common units outstanding:
Basic weighted average common units outstanding	71,771		76,620		72,249		76,861
Effect of dilutive securities:
Potential common units issuable(2)	—		109		—		117
Diluted weighted average common units outstanding	71,771		76,729		72,249		76,978
Net income (loss) per common unit, basic	$	0.42	$	0.44	$	0.89	$	0.66
Net income (loss) per common unit, diluted	$	0.42	$	0.44	$	0.89	$	0.66

(1) Unvested restricted stock units that contain non-forfeitable distribution equivalent rights granted are considered participating securities and therefore are included in the earnings per unit calculation pursuant to the two-class method.

(2) For the three and six months ended June 30, 2023 and 2022, there were no potential common units excluded from the computation of diluted earnings per common unit because their inclusion would have been anti-dilutive.

9. INCOME TAXES

The following table provides the Partnership’s provision for (benefit from) income taxes and the effective income tax rate for the dates indicated:


	Three Months Ended June 30,						Six Months Ended June 30,
	2023			2022			2023			2022
	(In thousands, except for tax rate)
Provision for (benefit from) income taxes	$	8,450		$	6,182		$	17,856		$	8,812
Effective tax rate	9.6		%	3.5		%	9.6		%	2.9		%

The Partnership’s effective income tax rate for the three and six months ended June 30, 2023 differed from the amount computed by applying the United States federal statutory tax rate to pre-tax income for the period primarily due to net income attributable to the non-controlling interest. The Partnership’s effective income tax rate for the three and six months ended June 30, 2022 differed from the amount computed by applying the United States federal statutory tax rate to pre-tax income for the period primarily due to net income attributable to the non-controlling interest and the impact of maintaining a valuation allowance on the Partnership’s deferred tax assets.

As of June 30, 2023, the Partnership maintained a partial valuation allowance against its deferred tax assets considered not more likely than not to be realized, based on its assessment of all available evidence, both positive and negative, as required by applicable accounting standards.

As of June 30, 2022, the Partnership had a full valuation allowance against its deferred tax assets, based on its assessment of all available evidence, both positive and negative, supporting realizability of the Partnership’s deferred tax assets.

The Inflation Reduction Act of 2022 (“IRA”) was enacted on August 16, 2022, and imposed an excise tax of 1% on the fair market value of certain public company stock/unit repurchases for tax years beginning after December 31, 2022, and included several other provisions applicable to U.S. income taxes for corporations. The Partnership’s excise tax during the three and six months ended June 30, 2023 was immaterial and is recognized as part of the cost basis of the units repurchased.

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10. DERIVATIVES

All derivative financial instruments are recorded at fair value. The Partnership has not designated its derivative instruments as hedges for accounting purposes and, as a result, marks its derivative instruments to fair value and recognizes the cash and non-cash changes in fair value in the condensed consolidated statements of operations under the caption “Gain (loss) on derivative instruments, net.”

Commodity Contracts

The Partnership historically has used fixed price swap contracts, fixed price basis swap contracts and costless collars with corresponding put and call options to reduce price volatility associated with certain of its royalty income. At June 30, 2023, the Partnership has put options and fixed price basis swaps outstanding.

The Partnership’s derivative contracts are based upon reported settlement prices on commodity exchanges, with put contracts for oil based on WTI Cushing and fixed price basis swaps for oil based on the spread between the WTI Cushing crude oil price and the Argus WTI Midland crude oil price. The Partnership’s fixed price basis swaps for natural gas are for the spread between the Waha Hub natural gas price and the Henry Hub natural gas price. The weighted average differential represents the amount of reduction to the WTI Cushing oil price and the Waha Hub natural gas price for the notional volumes covered by the basis swap contracts.

By using derivative instruments to economically hedge exposure to changes in commodity prices, the Partnership exposes itself to credit risk and market risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Partnership, which creates credit risk. The Partnership’s counterparties are all participants in the amended and restated credit agreement, which is secured by substantially all of the assets of the Operating Company; therefore, the Partnership is not required to post any collateral. The Partnership’s counterparties have been determined to have an acceptable credit risk; therefore, the Partnership does not require collateral from its counterparties.

As of June 30, 2023, the Partnership had the following outstanding derivative contracts. When aggregating multiple contracts, the weighted average contract price is disclosed.


					Swaps	Puts
Settlement Month	Settlement Year	Type of Contract	Bbls/Mcf Per Day	Index	Weighted Average Differential		Strike Price	Deferred Premium
OIL
Jul. - Sep.	2023	Puts	12,000	WTI Cushing	$—		$55.00	$1.80
Oct. - Dec.	2023	Puts	12,000	WTI Cushing	$—		$55.00	$1.85

Jul. - Dec.	2023	Basis Swaps	4,000	Argus WTI Midland	$1.05		$—	$—
NATURAL GAS
Jul. - Dec.	2023	Basis Swaps	30,000	Waha Hub	$(1.33)		$—	$—
Jan. - Dec.	2024	Basis Swaps	30,000	Waha Hub	$(1.20)		$—	$—

Balance Sheet Offsetting of Derivative Assets and Liabilities

The fair value of derivative instruments is generally determined using established index prices and other sources which are based upon, among other things, futures prices and time to maturity. These fair values are recorded by netting asset and liability positions, including any deferred premiums, that are with the same counterparty and are subject to contractual terms which provide for net settlement. See Note 11—Fair Value Measurements for further details.

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Gains and Losses on Derivative Instruments

The following table summarizes the gains and losses on derivative instruments included in the condensed consolidated statements of operations and the net cash receipts (payments) on derivatives for the periods presented:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Gain (loss) on derivative instruments	$	(12,594)	$	(1,889)	$	(27,697)	$	(20,248)
Net cash receipts (payments) on derivatives(1)	$	(3,997)	$	(6,765)	$	(6,212)	$	(17,029)

(1)The six months ended June 30, 2022 includes cash paid on commodity contracts terminated prior to their contractual maturity of $4.2 million.

11. FAIR VALUE MEASUREMENTS

Assets and Liabilities Measured at Fair Value on a Recurring Basis

As discussed in Note 11—Fair Value Measurements in the Partnership's Annual Report on Form 10-K for the year ended December 31, 2022, certain assets and liabilities are reported at fair value on a recurring basis on the Partnership’s condensed consolidated balance sheets, including the Partnership’s derivative instruments. The fair values of the Partnership’s derivative contracts are measured internally using established commodity futures price strips for the underlying commodity provided by a reputable third party, the contracted notional volumes, and time to maturity. These valuations are Level 2 inputs in the fair value hierarchy. The net amounts are classified as current or noncurrent based on their anticipated settlement dates.

The following table provides (i) fair value measurement information for financial assets and liabilities measured at fair value on a recurring basis, (ii) the gross amounts of recognized derivative assets and liabilities, (iii) the amounts offset under master netting arrangements with counterparties and (iv) the resulting net amounts presented in the Partnership’s condensed consolidated balance sheets as of June 30, 2023 and December 31, 2022:


	As of June 30, 2023
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	1,541	$	—	$	1,541	$	(1,541)	$	—



Liabilities:
Current:
Derivative instruments	$	—	$	9,890	$	—	$	9,890	$	(1,541)	$	8,349
Non-current:
Derivative instruments	$	—	$	3,373	$	—	$	3,373	$	—	$	3,373

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	As of December 31, 2022
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	13,296	$	—	$	13,296	$	(3,968)	$	9,328
Non-current:

Derivative instruments	$	—	$	1,911	$	—	$	1,911	$	(1,469)	$	442
Liabilities:
Current:
Derivative instruments	$	—	$	3,968	$	—	$	3,968	$	(3,968)	$	—
Non-current:
Derivative instruments	$	—	$	1,476	$	—	$	1,476	$	(1,469)	$	7

Assets and Liabilities Not Recorded at Fair Value

The following table provides the fair value of financial instruments that are not recorded at fair value in the condensed consolidated balance sheets:


	June 30, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
Debt:
Revolving credit facility	$	224,000	$	224,000	$	152,000	$	152,000
5.375% senior notes due 2027(1)	$	425,416	$	413,097	$	424,895	$	411,634

(1) The carrying value includes associated deferred loan costs and any discount.

The fair value of the Operating Company’s revolving credit facility approximates the carrying value based on borrowing rates available to the Partnership for bank loans with similar terms and maturities and is classified as Level 2 in the fair value hierarchy. The fair value of the Notes was determined using the June 30, 2023 quoted market price, a Level 1 classification in the fair value hierarchy.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are measured at fair value on a nonrecurring basis in certain circumstances. These assets and liabilities can include mineral and royalty interests acquired in asset acquisitions and subsequent write-downs of our proved oil and natural gas interests to fair value when they are impaired or held for sale.

Fair Value of Financial Assets

The Partnership has other financial instruments consisting of cash and cash equivalents, royalty income receivable, other current assets, accounts payable, accrued liabilities and income taxes payable. The carrying value of these instruments approximate their fair value because of the short-term nature of the instruments.

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12. COMMITMENTS AND CONTINGENCIES

The Partnership is a party to various routine legal proceedings, disputes and claims from time to time arising in the ordinary course of its business. While the ultimate outcome of the pending proceedings, disputes or claims, and any resulting impact on the Partnership, cannot be predicted with certainty, the Partnership’s management believes that none of these matters, if ultimately decided adversely, will have a material adverse effect on the Partnership’s financial condition, results of operations or cash flows. The Partnership’s assessment is based on information known about the pending matters and its experience in contesting, litigating and settling similar matters. Actual outcomes could differ materially from the Partnership’s assessment. The Partnership records reserves for contingencies related to outstanding legal proceedings, disputes or claims when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

13. SUBSEQUENT EVENTS

Cash Distribution

On July 25, 2023, the board of directors of the General Partner approved an increase to the Partnership’s annual base dividend to $1.08 per common unit beginning with the distribution payable for the second quarter of 2023, and a cash distribution for the second quarter of 2023 of $0.36 per common unit and $0.44 per Class B unit, payable on August 17, 2023, to eligible unitholders of record at the close of business on August 10, 2023. For the second quarter of 2023, the distribution to common unitholders consists of a base quarterly distribution of $0.27 per common unit and a variable quarterly distribution of $0.09 per common unit.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements and notes thereto presented in this report as well as our audited financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2022. The following discussion contains “forward-looking statements” that reflect our future plans, estimates, beliefs and expected performance. Actual results and the timing of events may differ materially from those contained in these forward-looking statements due to a number of factors. See Part II. Item 1A. Risk Factors and Cautionary Statement Regarding Forward-Looking Statements.

Overview

We are a publicly traded Delaware limited partnership formed by Diamondback to own and acquire mineral and royalty interests in oil and natural gas properties primarily in the Permian Basin. We operate in one reportable segment. Since May 10, 2018, we have been treated as a corporation for U.S. federal income tax purposes.

Recent Developments

Commodity Prices

Prices for oil, natural gas and natural gas liquids are determined primarily by prevailing market conditions. Regional and worldwide economic activity, including any economic downturn or recession that has occurred or may occur in the future, extreme weather conditions and other substantially variable factors influence market conditions for these products. These factors are beyond our control and are difficult to predict. During the first half of 2023 and 2022, the NYMEX WTI price averaged $74.77 and $101.77 per Bbl, respectively, and NYMEX Henry Hub price averaged $2.54 and $6.04 per MMBtu, respectively. The war in Ukraine, rising interest rates, global supply chain disruptions, concerns about a potential economic downturn or recession, measures to combat persistent inflation and instability in the financial sector have contributed to recent economic and pricing volatility and may continue to impact pricing throughout 2023. Additionally, OPEC and its non-OPEC allies, known collectively as OPEC+, continues to meet regularly to evaluate the state of global oil supply, demand and inventory levels.

Cash Distribution Update

On July 25, 2023, the board of directors of the General Partner approved an increase to the Partnership’s annual base dividend to $1.08 per common unit beginning with our distribution payable for the second quarter of 2023.

Intent to Convert into Corporate Structure

On July 31, 2023, we announced our intent to convert our legal status from a Delaware limited partnership into a Delaware corporation. The conversion is expected to be completed by or before December 31, 2023. After the conversion, it is expected that our current limited partners would own the same percentage of the corporation’s outstanding shares as they currently own of the Partnership’s outstanding equity interests.

In connection with the conversion, we intend to adopt a corporate governance structure designed to meet the eligibility requirements for certain indices and benchmarks, which we believe would further broaden our investor base and improve our trading liquidity, although no assurances can be provided regarding inclusion in any such index or benchmark. Because we are already treated as a corporation for U.S. federal income tax purposes, we expect that the conversion of our entity form into a Delaware corporation will not impact the current tax treatment for the Partnership’s current public common unitholders.

Upon conversion, it is intended that our common stockholders will have the ability to vote on all matters on which stockholders of a corporation are generally entitled to vote under the Delaware General Corporation Law, including the election of our board of directors. Immediately following the proposed conversion, we would be a “controlled company” under the Nasdaq rules because Diamondback would own more than 50% of the voting power of our common stock. In addition, Diamondback intends to continue to provide general and administrative services to us post-conversion in substantially the same manner as Diamondback currently provides. At or around the actual conversion, we intend to provide additional information regarding the post-conversion structural arrangements, including the terms of our post-conversion governing documents and the arrangements providing for Diamondback’s provision of services to us post-conversion. It is expected that post-conversion, our publicly traded common stock will be traded on Nasdaq under the existing ticker symbol “VNOM.”

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Production and Operational Update

Our footprint of mineral and royalty interests totaled 27,178 net royalty acres, approximately 58% of which are operated by Diamondback, as of June 30, 2023. Continuing the trend of increasing production, average oil production per day during the second quarter of 2023 was the highest in the Partnership’s history. There are currently 47 rigs operating on our mineral and royalty acreage, eight of which are operated by Diamondback. As a result of the continued outperformance of our production goals, we have increased our third quarter 2023 oil production guidance by approximately four percent at midpoint compared to average daily oil production in the second quarter of 2023. Due to Diamondback’s consistent focus on developing our high concentration royalty acreage, primarily in the Northern Midland Basin, we expect our Diamondback-operated full year 2023 oil production to increase by over 15% compared to 2022, with a further increase of approximately 10% expected for the full year 2024.

The following table summarizes our gross well information for the second quarter ended June 30, 2023:


	Diamondback Operated		Third Party Operated		Total
Horizontal wells turned to production(1):
Gross wells	81		204		285
Net 100% royalty interest wells	3.9		2.0		5.9
Average percent net royalty interest	4.8	%	1.0	%	2.1	%

Horizontal producing well count:
Gross wells	1,653		4,189		5,842
Net 100% royalty interest wells	120.8		68.1		188.9
Average percent net royalty interest	7.3	%	1.6	%	3.2	%

Horizontal active development well count(2):
Gross wells	110		353		463
Net 100% royalty interest wells	6.5		2.9		9.4
Average percent net royalty interest	5.9	%	0.8	%	2.0	%

Line of sight wells(3):
Gross wells	206		371		577
Net 100% royalty interest wells	12.3		5.6		17.9
Average percent net royalty interest	6.0	%	1.5	%	3.1	%

(1) Average lateral length of 11,403.

(2) The total 463 gross wells currently in the process of active development are those wells that have been spud and are expected to be turned to production within approximately the next six to eight months.

(3) The total 577 gross line-of-sight wells are those that are not currently in the process of active development, but for which we have reason to believe that they will be turned to production within approximately the next 15 to 18 months. The expected timing of these line-of-sight wells is based primarily on permitting by third party operators or Diamondback’s current expected completion schedule. Existing permits or active development of our royalty acreage does not ensure that those wells will be turned to production given the volatility in oil prices.

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Comparison of the Three Months Ended June 30, 2023 and March 31, 2023

Results of Operations

The following table summarizes our income and expenses for the periods indicated:


	Three Months Ended
	June 30, 2023		March 31, 2023
	(In thousands)

Operating income:
Oil income	$	139,300	$	136,619
Natural gas income	5,090		8,991
Natural gas liquids income	13,807		15,475
Royalty income	158,197		161,085
Lease bonus income—related party	1,277		7,071
Lease bonus income	1,134		400

Other operating income	179		402
Total operating income	160,787		168,958
Costs and expenses:
Production and ad valorem taxes	12,621		12,887

Depletion	34,064		30,987


General and administrative expenses	2,008		2,764

Total costs and expenses	48,693		46,638
Income (loss) from operations	112,094		122,320
Other income (expense):
Interest expense, net	(11,291)		(9,686)


Gain (loss) on derivative instruments, net	(12,594)		(15,103)

Other income, net	172		141
Total other expense, net	(23,713)		(24,648)
Income (loss) before income taxes	88,381		97,672
Provision for (benefit from) income taxes	8,450		9,406
Net income (loss)	79,931		88,266
Net income (loss) attributable to non-controlling interest	49,381		54,299
Net income (loss) attributable to Viper Energy Partners LP	$	30,550	$	33,967

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The following table summarizes our production data, average sales prices and average costs for the periods indicated:


	Three Months Ended
	June 30, 2023		March 31, 2023
Production data:
Oil (MBbls)	1,924		1,810
Natural gas (MMcf)	4,685		4,224
Natural gas liquids (MBbls)	724		633
Combined volumes (MBOE)(1)	3,429		3,147

Average daily oil volumes (BO/d)	21,143		20,111
Average daily combined volumes (BOE/d)	37,681		34,967


Average sales prices:
Oil ($/Bbl)	$	72.40	$	75.48
Natural gas ($/Mcf)	$	1.09	$	2.13
Natural gas liquids ($/Bbl)	$	19.07	$	24.45
Combined ($/BOE)(2)	$	46.14	$	51.19

Oil, hedged ($/Bbl)(3)	$	71.39	$	74.30
Natural gas, hedged ($/Mcf)(3)	$	0.65	$	2.11
Natural gas liquids ($/Bbl)(3)	$	19.07	$	24.45
Combined price, hedged ($/BOE)(3)	$	44.97	$	50.48

Average costs ($/BOE):
Production and ad valorem taxes	$	3.68	$	4.10
General and administrative - cash component(4)	0.51		0.76
Total operating expense - cash	$	4.19	$	4.86

General and administrative - non-cash unit compensation expense	$	0.08	$	0.12
Interest expense, net	$	3.29	$	3.08
Depletion	$	9.93	$	9.85

(1)Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.

(2)Realized price net of all deducts for gathering, transportation and processing.

(3)Hedged prices reflect the impact of cash settlements of our matured commodity derivative transactions on our average sales prices.

(4)Excludes non-cash unit-based compensation expense for the respective periods presented.

Royalty Income

Our royalty income is a function of oil, natural gas and natural gas liquids production volumes sold and average prices received for those volumes.

Royalty income decreased $2.9 million during the second quarter of 2023 compared to the first quarter of 2023. Changes in average pricing contributed to approximately $14.7 million of the total decrease due to lower average prices for oil, natural gas and natural gas liquids received for our production in the second quarter of 2023. The impact of lower pricing was partially offset by an increase of $11.8 million in royalty income due to 9% growth in production in the second quarter of 2023 compared to the first quarter of 2023, which resulted primarily from new well development in areas where Viper has a higher royalty interest.

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Lease Bonus Income-Related Party

Lease bonus income from Diamondback decreased $5.8 million due primarily to receiving payment for two leases and two lease extensions covering approximately 165 net mineral acres in the second quarter of 2023 compared to receiving payment for one lease covering approximately 257 net mineral acres in Martin County, TX from Diamondback in the first quarter of 2023.

Production and Ad Valorem Taxes

The following table presents production and ad valorem taxes for the three months ended June 30, 2023 and March 31, 2023:


	Three Months Ended
	June 30, 2023						March 31, 2023
	Amount (In thousands)		Per BOE		Percentage of Royalty Income		Amount (In thousands)		Per BOE		Percentage of Royalty Income
Production taxes	$	7,807	$	2.28	5.0	%	$	8,177	$	2.60	5.1	%
Ad valorem taxes	4,814		1.40		3.0		4,710		1.50		2.9
Total production and ad valorem taxes	$	12,621	$	3.68	8.0	%	$	12,887	$	4.10	8.0	%

In general, production taxes are directly related to production revenues and are based upon current year commodity prices. Production taxes as a percentage of royalty income for the second quarter of 2023 were consistent with the first quarter of 2023. Ad valorem taxes are based, among other factors, on property values driven by prior year commodity prices, and were also consistent for the second quarter of 2023 compared to the first quarter of 2023.

Depletion

The $3.1 million increase in depletion expense for the second quarter of 2023 compared to the first quarter of 2023 was due primarily to production growth between the periods. The average depletion rate also increased slightly to $9.93 per BOE for the second quarter of 2023 compared to $9.85 per BOE for the first quarter of 2023.

Derivative Instruments

The following table shows the net gain (loss) on derivative instruments and the net cash receipts (payments) on derivatives for the periods presented:


	Three Months Ended
	June 30, 2023		March 31, 2023
	(In thousands)
Gain (loss) on derivative instruments	$	(12,594)	$	(15,103)
Net cash receipts (payments) on derivatives	$	(3,997)	$	(2,215)

We recorded losses on our derivative instruments for the three months ended June 30, 2023 and March 31, 2023 primarily due to a decrease in the differential spread compared to contract terms on our natural gas basis swaps. We are required to recognize all derivative instruments on our balance sheet as either assets or liabilities measured at fair value. See Note 10—Derivatives of the notes to the condensed consolidated financial statements for additional discussion of our open contracts at June 30, 2023.

Provision for (Benefit from) Income Taxes

The $1.0 million decrease in income tax expense for the second quarter of 2023 compared to the first quarter of 2023 is primarily due to the decrease in pre-tax income attributable to the Partnership. See Note 9—Income Taxes of the notes to the condensed consolidated financial statements for further details.

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Comparison of the Six Months Ended June 30, 2023 and 2022

Results of Operations

The following table summarizes our income and expenses for the periods indicated:


	Six Months Ended June 30,
	2023		2022


Operating income:
Oil income	$	275,919	$	346,246
Natural gas income	14,081		38,983
Natural gas liquids income	29,282		46,690
Royalty income	319,282		431,919
Lease bonus income—related party	8,348		6,280
Lease bonus income	1,534		2,731

Other operating income	581		295
Total operating income	329,745		441,225
Costs and expenses:
Production and ad valorem taxes	25,508		29,909

Depletion	65,051		59,373


General and administrative expenses	4,772		3,833

Total costs and expenses	95,331		93,115
Income (loss) from operations	234,414		348,110
Other income (expense):
Interest expense, net	(20,977)		(19,427)


Gain (loss) on derivative instruments, net	(27,697)		(20,248)

Other income, net	313		38
Total other expense, net	(48,361)		(39,637)
Income (loss) before income taxes	186,053		308,473
Provision for (benefit from) income taxes	17,856		8,812
Net income (loss)	168,197		299,661
Net income (loss) attributable to non-controlling interest	103,680		249,034
Net income (loss) attributable to Viper Energy Partners LP	$	64,517	$	50,627

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The following table summarizes our production data, average sales prices and average costs for the periods indicated:


	Six Months Ended June 30,
	2023		2022
Production data:
Oil (MBbls)	3,734		3,431
Natural gas (MMcf)	8,909		7,627
Natural gas liquids (MBbls)	1,357		1,193
Combined volumes (MBOE)(1)	6,576		5,895

Average daily oil volumes (BO/d)	20,630		18,956
Average daily combined volumes (BOE/d)	36,331		32,569


Average sales prices:
Oil ($/Bbl)	$	73.89	$	100.92
Natural gas ($/Mcf)	$	1.58	$	5.11
Natural gas liquids ($/Bbl)	$	21.58	$	39.14
Combined ($/BOE)(2)	$	48.55	$	73.27

Oil, hedged ($/Bbl)(3)	$	72.80	$	99.14
Natural gas, hedged ($/Mcf)(3)	$	1.34	$	4.22
Natural gas liquids ($/Bbl)(3)	$	21.58	$	39.14
Combined price, hedged ($/BOE)(3)	$	47.61	$	71.09

Average costs ($/BOE):
Production and ad valorem taxes	$	3.88	$	5.07
General and administrative - cash component(4)	0.63		0.55
Total operating expense - cash	$	4.51	$	5.62

General and administrative - non-cash unit compensation expense	$	0.10	$	0.11
Interest expense, net	$	3.19	$	3.30
Depletion	$	9.89	$	10.07

(1)Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.

(2)Realized price net of all deducts for gathering, transportation and processing.

(3)Hedged prices reflect the impact of cash settlements of our matured commodity derivative transactions on our average sales prices.

(4)Excludes non-cash unit-based compensation expense for the respective periods presented.

Royalty Income

Our royalty income is a function of oil, natural gas and natural gas liquids production volumes sold and average prices received for those volumes.

Royalty income decreased $112.6 million during the six months ended June 30, 2023 compared to the same period in 2022. Changes in average pricing during 2023 contributed to approximately $156.2 million of the total decrease due primarily to lower average oil prices, natural gas and natural gas liquids prices received for our production in 2023. The decrease due to lower pricing was partially offset by $43.5 million in additional royalty income due to a 12% increase in production volumes during the six months ended June 30, 2023 compared to the same period in 2022. This production growth stems from new well development in areas where Viper has a higher royalty interest between periods.

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Production and Ad Valorem Taxes

The following table presents production and ad valorem taxes for the six months ended June 30, 2023 and 2022:


	Six Months Ended June 30,
	2023						2022
	Amount (In thousands)		Per BOE		Percentage of Royalty Income		Amount (In thousands)		Per BOE		Percentage of Royalty Income
Production taxes	$	15,984	$	2.43	5.0	%	$	21,894	$	3.71	5.1	%
Ad valorem taxes	9,524		1.45		3.0		8,015		1.36		1.9
Total production and ad valorem taxes	$	25,508	$	3.88	8.0	%	$	29,909	$	5.07	7.0	%

In general, production taxes are directly related to production revenues and are based upon current year commodity prices. Production taxes as a percentage of royalty income for the six months ended June 30, 2023 remained consistent with the same period in 2022. Ad valorem taxes are based, among other factors, on property values driven by prior year commodity prices. The increase in ad valorem taxes is primarily due to higher valuations assigned to our oil and natural gas interests period over period driven by higher average commodity prices in 2022.

Depletion

The $5.7 million increase in depletion expense for the six months ended June 30, 2023 compared to the same period in 2022 was due primarily to production growth between the periods resulting largely from new well development. The average depletion rate decreased slightly to $9.89 for the six months ended June 30, 2023 compared to the rate of $10.07 for the same period in 2022 due primarily to lower value leasehold being transferred into the amortization base during 2023.

Derivative Instruments

The following table shows the net gain (loss) on derivative instruments and the net cash receipts (payments) on derivatives for the periods presented:


	Six Months Ended June 30,
	2023		2022
	(In thousands)
Gain (loss) on derivative instruments	$	(27,697)	$	(20,248)
Net cash receipts (payments) on derivatives(1)	$	(6,212)	$	(17,029)

(1)The six months ended June 30, 2022 includes cash paid on commodity contracts terminated prior to their contractual maturity of $4.2 million.

We recorded losses on our derivative instruments for the six months ended June 30, 2023 and 2022 primarily due to market prices being higher than the strike prices on our open derivative contracts. We are required to recognize all derivative instruments on our balance sheet as either assets or liabilities measured at fair value. See Note 10—Derivatives of the notes to the condensed consolidated financial statements for additional discussion of our open contracts at June 30, 2023.

Provision for (Benefit from) Income Taxes

The $9.0 million increase in income tax expense for the six months ended June 30, 2023 compared to the same period in 2022 resulted primarily from the increase in pre-tax income attributable to the Partnership as a result of the expiration of the special income allocation at December 31, 2022 and the impact of maintaining a valuation allowance against the Partnership’s deferred tax assets as of June 30, 2022. See Note 9—Income Taxes of the notes to the condensed consolidated financial statements for further details.

Net Income (Loss) Attributable to Non-controlling Interest

The $145.4 million decrease in net income (loss) attributable to non-controlling interest for the six months ended June 30, 2023 compared to the same period in 2022 is primarily due to the expiration of the special income allocation at December 31, 2022.

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Liquidity and Capital Resources

Overview of Sources and Uses of Cash

As we pursue our business and financial strategy, we regularly consider which capital resources, including cash flow and equity and debt financings, are available to meet our future financial obligations and liquidity requirements. Our future ability to grow proved reserves will be highly dependent on the capital resources available to us. Our primary sources of liquidity have been cash flows from operations, proceeds from sales of non-core assets, equity and debt offerings and borrowings under the Operating Company’s credit agreement. Our primary uses of cash have been distributions to our unitholders, repayments of debt, capital expenditures for the acquisition of our mineral and royalty interests in oil and natural gas properties and repurchases of our common units. At June 30, 2023, we had approximately $539.1 million of liquidity consisting of $13.1 million in cash and cash equivalents and $526.0 million available under the Operating Company’s credit agreement.

Our working capital requirements are supported by our cash and cash equivalents and the Operating Company’s credit agreement. We may draw on the Operating Company’s credit agreement to meet short-term cash requirements, or issue debt or equity securities as part of our longer-term liquidity and capital management program. Because of the alternatives available to us as discussed above, we believe that our short-term and long-term liquidity are adequate to fund not only our current operations, but also our near-term and long-term funding requirements including our acquisitions of mineral and royalty interests, distributions, debt service obligations and repayment of debt maturities, common unit and senior note repurchases and any amounts that may ultimately be paid in connection with contingencies.

In order to mitigate volatility in oil and natural gas prices, we have entered into commodity derivative contracts as discussed further in Item 3. Quantitative and Qualitative Disclosures About Market Risk—Commodity Price Risk.

Continued prolonged volatility in the capital, financial and/or credit markets due to the war in Ukraine, the depressed commodity markets and, or adverse macroeconomic conditions, including persistent inflation, rising interests rates, global supply chain disruptions and increasing concerns over a potential economic downturn or recession, may limit our access to, or increase our cost of, capital or make capital unavailable on terms acceptable to us or at all. Although we expect that our sources of funding will be adequate to fund our short-term and long-term liquidity requirements, we cannot assure you that the needed capital will be available on acceptable terms or at all.

Cash Flows

The following table presents our cash flows for the periods indicated:


	Six Months Ended June 30,
	2023		2022
	(In thousands)
Cash Flow Data:
Net cash provided by (used in) operating activities	$	252,669	$	299,020
Net cash provided by (used in) investing activities	(124,457)		31,198
Net cash provided by (used in) financing activities	(133,312)		(365,354)
Net increase (decrease) in cash and cash equivalents	$	(5,100)	$	(35,136)

Operating Activities

Our operating cash flow is sensitive to many variables, the most significant of which are the volatility of prices for oil and natural gas and the volumes of oil and natural gas sold by our producers. The decrease in net cash provided by operating activities during the six months ended June 30, 2023 compared to the same period in 2022 was primarily driven by lower royalty income. This was partially offset by an increase in cash flows from (i) changes in our working capital accounts, due primarily to a reduction in our royalty income receivables at June 30, 2023 compared to June 30, 2022 resulting from lower commodity prices and royalty income in 2023, (ii) a decrease in cash paid for derivative settlements, and (iii) a reduction in production and ad valorem taxes due to the corresponding decrease in royalty income. See “—Results of Operations” for discussion of significant changes in our revenues and expenses.

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Investing Activities

Net cash used in investing activities during the six months ended June 30, 2023 primarily related to the acquisition of oil and natural gas interests in the Drop Down and from other third-party acquisitions.

Net cash provided by in investing activities during the six months ended June 30, 2022 primarily related to proceeds from the divestiture of oil and natural gas interests.

Financing Activities

Net cash used in financing activities during the six months ended June 30, 2023 primarily resulted from distributions of $146.6 million and $57.5 million of common unit repurchases as we continue to return capital to our unitholders. These cash outflows were partially offset by net borrowings of $72.0 million under the Operating Company’s revolving credit facility.

Net cash used in financing activities during the six months ended June 30, 2022, was primarily related to distributions of $194.1 million to our unitholders and $68.2 million of common unit repurchases which included approximately $37.3 million for the repurchase of 1.5 million common units from a significant unitholder in a privately negotiated transaction. Additionally, we paid $49.0 million for the repurchase of principal outstanding on the Notes and made net repayments of $54.0 million under the Operating Company’s revolving credit facility.

Capital Resources

The Operating Company’s Revolving Credit Facility

During the second quarter of 2023, the Operating Company entered into a tenth amendment to our existing credit agreement, which strengthened our short and long-term liquidity positions by among other things, increasing our borrowing base from $580.0 million to $1.0 billion, and increasing our elected commitment amount from $500.0 million to $750.0 million. The Operating Company’s credit agreement, which matures on June 2, 2025, had $224.0 million in outstanding borrowings and $526.0 million of availability at June 30, 2023.

See Note 6—Debt of the notes to the condensed consolidated financial statements for additional discussion of our outstanding debt at June 30, 2023.

Capital Requirements

Repurchases of Securities

Under our current common unit repurchase program, the board of directors of our General Partner has authorized us to acquire up to $750.0 million of our common units, excluding excise tax. As of June 30, 2023, $472.4 million remains available for use to repurchase units under this repurchase program, excluding excise tax.

We may also from time to time opportunistically repurchase some of the outstanding Notes in open market purchases or in privately negotiated transactions.

Cash Distributions

The distribution for the second quarter of 2023 is $0.36 per common unit and $0.44 per Class B unit payable on August 17, 2023 to eligible unitholders of record at the close of business on August 10, 2023. The dividend to common unitholders consists of a base quarterly dividend of $0.27 per common unit and a variable quarterly dividend of $0.09 per common unit.

Future base and variable dividends are at the discretion of the board of directors of our General Partner.

See Note 7—Unitholders' Equity and Distributions of the notes to the condensed consolidated financial statements for further discussion of the repurchase program and distributions.

Critical Accounting Estimates

There have been no changes to our critical accounting estimates from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2022.

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Recent Accounting Pronouncements

See Note 2—Summary of Significant Accounting Policies included in the condensed notes to the consolidated financial statements for recent accounting pronouncements not yet adopted, if any.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are exposed to market risk, including the effects of adverse changes in commodity prices and interest rates as described below. The primary objective of the following information is to provide quantitative and qualitative information about our potential exposure to market risks. The term “market risk” refers to the risk of loss arising from adverse changes in oil and natural gas prices and interest rates. The disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses.

Commodity Price Risk

Our major market risk exposure is in the pricing applicable to the oil and natural gas production of our operators. Realized prices are driven primarily by the prevailing worldwide price for crude oil and prices for natural gas in the United States. Both crude oil and natural gas realized prices are also impacted by the quality of the product, supply and demand balances in local physical markets and the availability of transportation to demand centers. Pricing for oil and natural gas production has been historically volatile and unpredictable and the prices that our operators receive for production depend on many factors outside of our or their control, such as the war in Ukraine, rising interest rates, global supply chain disruptions, a potential economic downturn or recession and actions taken by OPEC members and other exporting nations. We cannot predict events that may lead to future price volatility and the near term energy outlook remains subject to heightened levels of uncertainty.

We historically have used fixed price swap contracts, fixed price basis swap contracts and costless collars with corresponding put and call options to reduce price volatility associated with certain of our royalty income as discussed in Note 10—Derivatives of the notes to the condensed consolidated financial statements.

At June 30, 2023, we had a net liability derivative position related to our commodity price derivatives of $11.7 million. Utilizing actual derivative contractual volumes under our contracts as of June 30, 2023, a 10% increase in forward curves associated with the underlying commodity would have decreased the net liability position by $0.4 million to approximately $11.4 million, while a 10% decrease in forward curves associated with the underlying commodity would have increased the net liability derivative position by $0.3 million to approximately $12.0 million. However, any cash derivative gain or loss would be substantially offset by a decrease or increase, respectively, in the actual sales value of production covered by the derivative instrument.

Credit Risk

We are subject to risk resulting from the concentration of royalty income in producing oil and natural gas interests and receivables with a limited number of significant purchasers and producers. We do not require collateral and the failure or inability of our significant purchasers to meet their obligations to us due to their liquidity issues, bankruptcy, insolvency or liquidation may adversely affect our financial results. Volatility in commodity pricing environment and macroeconomic conditions may enhance our purchaser credit risk.

Interest Rate Risk

We are subject to market risk exposure related to changes in interest rates on our indebtedness under the Operating Company’s credit agreement. The terms of the credit agreement provide for interest on borrowings at a floating rate equal to (i) term SOFR plus 0.10% (“Adjusted Term SOFR”) or (ii) an alternate base rate (which is equal to the greatest of the prime rate, the Federal Funds effective rate plus 0.50%, and 1-month Adjusted Term SOFR plus 1.00%), in each case plus the applicable margin. The applicable margin ranges from 1.00% to 2.00% per annum in the case of the alternative base rate and from 2.00% to 3.00% per annum in the case of Adjusted Term SOFR, in each case depending on the amount of the loans outstanding in relation to the commitment, which is calculated using the least of the maximum credit amount, the aggregate elected commitment amount and the borrowing base. We are obligated to pay a quarterly commitment fee ranging from 0.375% to 0.500% per year on the unused portion of the commitment. As of June 30, 2023, we had $224.0 million in outstanding borrowings. During the three and six months ended June 30, 2023, the weighted average interest rate on the Operating Company’s revolving credit facility was 7.53% and 7.24%.

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ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Control and Procedures. Under the direction of the Chief Executive Officer and Chief Financial Officer of our General Partner, we have established disclosure controls and procedures, as defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act, that are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. The disclosure controls and procedures are also intended to ensure that such information is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer of our General Partner, as appropriate to allow timely decisions regarding required disclosures. In designing and evaluating the disclosure controls and procedures, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures must reflect the fact that there are resource constraints and that management is required to apply judgment in evaluating the benefits of possible controls and procedures relative to their costs.

As of June 30, 2023, an evaluation was performed under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer of our General Partner, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(b) under the Exchange Act. Based upon the evaluation, the Chief Executive Officer and Chief Financial Officer of our General Partner have concluded that as of June 30, 2023, our disclosure controls and procedures are effective.

Changes in Internal Control over Financial Reporting. There have not been any changes in our internal control over financial reporting that occurred during the quarter ended June 30, 2023 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Due to the nature of our business, we are, from time to time, involved in routine litigation or subject to disputes or claims related to our business activities. In the opinion of our management, none of the pending litigation, disputes or claims against us, if decided adversely, will have a material adverse effect on our financial condition, cash flows or results of operations. See Note 12—Commitments and Contingencies of the notes to the condensed consolidated financial statements.

ITEM 1A. RISK FACTORS

Our business faces many risks. Any of the risks discussed in this report and our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also materially impair our business operations, financial condition or future results.

As of the date of this filing, we continue to be subject to the risk factors previously disclosed in Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2022, filed with the SEC on February 23, 2023 and in subsequent filings we make with the SEC. There have been no material changes in our risk factors from those described in our Annual Report on Form 10-K for the year ended December 31, 2022.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Unregistered Sales of Equity Securities

None.

Issuer Repurchases of Equity Securities

Our common unit repurchase activity for the three months ended June 30, 2023 was as follows:


Period	Total Number of Units Purchased	Average Price Paid Per Unit(1)(3)		Total Number of Units Purchased as Part of Publicly Announced Plan	Approximate Dollar Value of Units that May Yet Be Purchased Under the Plan(2)(3)
	(In thousands, except unit amounts)
April 1, 2023 - April 30, 2023	102,000	$	29.27	102,000	$	493,700
May 1, 2023 - May 31, 2023	379,500	$	26.91	379,500	$	483,487
June 1, 2023 - June 30, 2023	430,500	$	25.71	430,500	$	472,420
Total	912,000	$	26.61	912,000

(1)The average price paid per common unit includes any commissions paid to repurchase a common unit.

(2)On July 26, 2022, the board of directors of our General Partner increased the authorization under our then-in-effect common unit repurchase program from $250.0 million to $750.0 million, excluding excise tax. This repurchase program has no expiration date and remains subject to market conditions, applicable legal requirements, contractual obligations and other factors and may be suspended from time to time, modified, extended or discontinued by the board of directors of our General Partner at any time.

(3)The Inflation Reduction Act of 2022, which was enacted into law on August 16, 2022, imposed a nondeductible 1% excise tax on the net value of certain stock repurchases made after December 31, 2022. All dollar amounts presented exclude such excise taxes, as applicable.

ITEM 5. OTHER INFORMATION

None of the directors or officers of our General Partner adopted or terminated a Rule 10b5-1 trading arrangement or a non-Rule 10b5-1 trading arrangement during our fiscal quarter ended June 30, 2023.

Table of Contents

ITEM 6. EXHIBITS


Exhibit Number						Description
2.1						Purchase and Sale Agreement dated August 6, 2021 by and among Swallowtail Royalties LLC, Swallowtail Royalties II LLC (collectively, as seller), Viper Energy Partners LLC (as buyer) and Viper Energy Partners LP (as parent, and collectively with Viper Energy Partners LLC, as buyer parties) (incorporated by reference to Exhibit 2.1 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on August 12, 2021).
3.1						Certificate of Limited Partnership of Viper Energy Partners LP (incorporated by reference to Exhibit 3.1 of the Partnership’s Registration Statement on Form S-1 (File 333-195769) filed on May 7, 2014).
3.2						Second Amended and Restated Agreement of Limited Partnership of Viper Energy Partners LP, dated as of May 9, 2018 (incorporated by reference to Exhibit 3.1 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on May 15, 2018).
3.3						First Amendment to Second Amended and Restated Agreement of Limited Partnership of Viper Energy Partners LP, dated as of May 10, 2018. (incorporated by reference to Exhibit 3.2 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on May 15, 2018).
3.4						Second Amended and Restated Limited Liability Company Agreement of Viper Energy Partners LLC, dated as of May 9, 2018. (incorporated by reference to Exhibit 3.3 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on May 15, 2018).
3.5						First Amendment to Second Amended and Restated Limited Liability Company Agreement of Viper Energy Partners LLC, dated as of March 30, 2020 (incorporated by reference to Exhibit 3.1 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on March 31, 2020).

3.6						Second Amendment to the Second Amended and Restated Limited Liability Company Agreement of Viper Energy Partners LLC, dated as of December 27, 2021 (incorporated by reference to Exhibit 3.1 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on December 28, 2021).
4.1						Amended and Restated Registration Rights Agreement, dated as of May 9, 2018, by and between Viper Energy Partners LP and Diamondback Energy, Inc. (incorporated by reference to Exhibit 4.1 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on May 15, 2018).







4.2						Registration Rights Agreement, dated as of October 1, 2021, by and among Viper Energy Partners LP, Swallowtail Royalties LLC and Swallowtail Royalties II LLC (incorporated by reference to Exhibit 4.1 of the Partnership’s Current Report on Form 8-K (File 001-36505) filed on October 7, 2021).
10.1						Tenth Amendment to Amended and Restated Senior Secured Revolving Credit Agreement and Second Amendment to Guaranty and Collateral Agreement, dated as of May 31, 2023, by and among Viper Energy Partners LLC, as borrower, Viper Energy Partners LP, as parent guarantor, Wells Fargo Bank, National Association, as administrative agent, and the lenders party thereto (incorporated by reference to Exhibit 10.1 of the Partnership's Current Report on Form 8-K (File No. 001-36505) filed on June 6, 2023).
31.1*						Certification of Chief Executive Officer pursuant to Rule 13a-14(a) promulgated under the Securities Exchange Act of 1934, as amended.
31.2*						Certification of Chief Financial Officer pursuant to Rule 13a-14(a) promulgated under the Securities Exchange Act of 1934, as amended.
32.1**						Certification of Chief Executive Officer and Chief Financial Officer pursuant to Rule 13a-14(b) promulgated under the Securities Exchange Act of 1934, as amended, and Section 1350 of Chapter 63 of Title 18 of the United States Code.
101						The following financial information from the Registrant’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2023, formatted in Inline XBRL: (i) Condensed Consolidated Balance Sheets, (ii) Condensed Consolidated Statements of Operations, (iii) Condensed Consolidated Statement of Changes in Unitholders’ Equity, (iv) Condensed Consolidated Statements of Cash Flows and (v) Condensed Notes to Consolidated Financial Statements.






104						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).


*			Filed herewith.
**			The certifications attached as Exhibit 32.1 accompany this Quarterly Report on Form 10-Q pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, and shall not be deemed “filed” by the Registrant for purposes of Section 18 of the Securities Exchange Act of 1934, as amended.

Table of Contents

SIGNATURES

Pursuant to the requirements of the Securities and Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.


		VIPER ENERGY PARTNERS LP

		By:	VIPER ENERGY PARTNERS GP LLC
			its General Partner

Date:	August 3, 2023	By:	/s/ Travis D. Stice
			Travis D. Stice
			Chief Executive Officer

Date:	August 3, 2023	By:	/s/ Teresa L. Dick
			Teresa L. Dick
			Chief Financial Officer

EXHIBIT 31.1

CERTIFICATION

I, Travis D. Stice, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Viper Energy Partners LP (the “registrant”).

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.



Date:	August 3, 2023	/s/ Travis D. Stice
		Travis D. Stice
		Chief Executive Officer
		Viper Energy Partners GP LLC
		(as general partner of Viper Energy Partners LP)

EXHIBIT 31.2

CERTIFICATION

I, Teresa L. Dick, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Viper Energy Partners LP (the “registrant”).

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.



Date:	August 3, 2023	/s/ Teresa L. Dick
		Teresa L. Dick
		Chief Financial Officer
		Viper Energy Partners GP LLC
		(as general partner of Viper Energy Partners LP)

EXHIBIT 32.1

CERTIFICATION OF PERIOD REPORT

In connection with the Quarterly Report on Form 10-Q of Viper Energy Partners LP (the “Partnership”), as filed with the Securities and Exchange Commission on the date hereof (the “Report”), the undersigned, Travis D. Stice, Chief Executive Officer of Viper Energy Partners GP LLC, the general partner of Viper Energy Partners LP, and Teresa L. Dick, Chief Financial Officer of Viper Energy Partners GP LLC, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to their knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)); and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.



Date:	August 3, 2023	/s/ Travis D. Stice
		Travis D. Stice
		Chief Executive Officer
		Viper Energy Partners GP LLC
		(as general partner of Viper Energy Partners LP)

Date:	August 3, 2023	/s/ Teresa L. Dick
		Teresa L. Dick
		Chief Financial Officer
		Viper Energy Partners GP LLC
		(as general partner of Viper Energy Partners LP)

Cover - shares	6 Months Ended
Cover - shares	Jun. 30, 2023	Jul. 28, 2023
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
Document Transition Report	false
Entity File Number	001-36505
Entity Registrant Name	Viper Energy Partners LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-5001985
Entity Address, Address Line One	500 West Texas Ave.
Entity Address, Address Line Two	Suite 100
Entity Address, City or Town	Midland,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	79701
City Area Code	432
Local Phone Number	221-7400
Title of 12(b) Security	Common Units
Trading Symbol	VNOM
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Entity Central Index Key	0001602065
Current Fiscal Year End Date	--12-31
Common Units
Document Information [Line Items]
Entity Common Units, Units Outstanding		70,904,057
Class B Units
Document Information [Line Items]
Entity Common Units, Units Outstanding		90,709,946

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Current assets:
Cash and cash equivalents	$ 13,079	$ 18,179
Derivative instruments	0	9,328
Other current assets	7,566	3,196
Total current assets	105,794	118,620
Property:
Oil and natural gas interests, full cost method of accounting ($1,195,923 and $1,297,221 excluded from depletion at June 30, 2023 and December 31, 2022, respectively)	3,590,476	3,464,819
Land	5,688	5,688
Accumulated depletion and impairment	(785,286)	(720,234)
Property, net	2,810,878	2,750,273
Derivative instruments	0	442
Deferred income taxes (net of allowances)	49,124	49,656
Other assets	1,242	1,382
Total assets	2,967,038	2,920,373
Current liabilities:
Accrued liabilities	18,127	19,600
Derivative instruments	8,349	0
Income taxes payable	1,584	911
Total current liabilities	28,079	21,946
Long-term debt, net	649,416	576,895
Derivative instruments	3,373	7
Total liabilities	680,868	598,848
Commitments and contingencies
Unitholders’ equity:
General Partner	609	649
Common units (71,206,622 units issued and outstanding as of June 30, 2023 and 73,229,645 units issued and outstanding as of December 31, 2022)	665,511	689,178
Class B units (90,709,946 units issued and outstanding as of June 30, 2023 and December 31, 2022)	782	832
Total Viper Energy Partners LP unitholders’ equity	666,902	690,659
Non-controlling interest	1,619,268	1,630,866
Total equity	2,286,170	2,321,525
Total liabilities and unitholders’ equity	2,967,038	2,920,373
Nonrelated Party
Current assets:
Royalty income receivable (net of allowance for credit losses)	80,765	81,657
Current liabilities:
Accounts payable	19	1,129
Related Party
Current assets:
Royalty income receivable (net of allowance for credit losses)	4,384	6,260
Current liabilities:
Accounts payable	$ 0	$ 306

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Oil and natural gas interests, based on the full cost method of accounting, amount excluded from depletion	$ 1,195,923	$ 1,297,221
Common Units
Limited partners' capital account, units issued (in shares)	71,206,622	73,229,645
Limited partners' capital account, units outstanding (in shares)	71,206,622	73,229,645
Class B Units
Limited partners' capital account, units issued (in shares)	90,709,946	90,709,946
Limited partners' capital account, units outstanding (in shares)	90,709,946	90,709,946

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Operating income:
Royalty income	$ 158,197	$ 238,830	$ 319,282	$ 431,919
Other operating income	179	163	581	295
Total operating income	160,787	239,322	329,745	441,225
Costs and expenses:
Production and ad valorem taxes	12,621	16,039	25,508	29,909
Depletion	34,064	31,962	65,051	59,373
General and administrative expenses	2,008	1,880	4,772	3,833
Total costs and expenses	48,693	49,881	95,331	93,115
Income (loss) from operations	112,094	189,441	234,414	348,110
Other income (expense):
Interest expense, net	(11,291)	(9,782)	(20,977)	(19,427)
Gain (loss) on derivative instruments, net	(12,594)	(1,889)	(27,697)	(20,248)
Other income, net	172	32	313	38
Total other expense, net	(23,713)	(11,639)	(48,361)	(39,637)
Income (loss) before income taxes	88,381	177,802	186,053	308,473
Provision for (benefit from) income taxes	8,450	6,182	17,856	8,812
Net income (loss)	79,931	171,620	168,197	299,661
Net income (loss) attributable to non-controlling interest	49,381	137,598	103,680	249,034
Net income (loss) attributable to Viper Energy Partners LP	$ 30,550	$ 34,022	$ 64,517	$ 50,627
Net income (loss) attributable to common limited partner units:
Basic (dollars per unit)	$ 0.42	$ 0.44	$ 0.89	$ 0.66
Diluted (dollars per unit)	$ 0.42	$ 0.44	$ 0.89	$ 0.66
Weighted average number of common limited partner units outstanding:
Basic (in units)	71,771	76,620	72,249	76,861
Diluted (in units)	71,771	76,729	72,249	76,978
Revenue, Product and Service [Extensible Enumeration]	Royalty [Member]	Royalty [Member]	Royalty [Member]	Royalty [Member]
Related Party
Operating income:
Lease bonus	$ 1,277	$ 0	$ 8,348	$ 6,280
Nonrelated Party
Operating income:
Lease bonus	$ 1,134	$ 329	$ 1,534	$ 2,731

Condensed Consolidated Statements of Changes to Unitholders' Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Limited Partners	General Partner	Non-Controlling Interest	Common Units Limited Partners	Class B Units Limited Partners
Beginning balance (in shares) at Dec. 31, 2021					78,546	90,710
Beginning balance at Dec. 31, 2021	$ 2,232,828		$ 729	$ 1,418,007	$ 813,161	$ 931
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation	284				284
Distribution equivalent rights payments	(64)				(64)
Distributions to public	(35,830)				(35,830)
Distributions to Diamondback	(43,003)			(42,634)	(344)	$ (25)
Distributions to General Partner	(20)		(20)
Change in ownership of consolidated subsidiaries, net	0			(14,195)	$ 14,195
Repurchased units as part of unit buyback (in shares)					(1,580)
Repurchased units as part of unit buyback	(39,260)				$ (39,260)
Net income (loss)	128,041			111,436	$ 16,605
Ending balance (in shares) at Mar. 31, 2022					76,966	90,710
Ending balance at Mar. 31, 2022	2,242,976		709	1,472,614	$ 768,747	$ 906
Beginning balance (in shares) at Dec. 31, 2021					78,546	90,710
Beginning balance at Dec. 31, 2021	2,232,828		729	1,418,007	$ 813,161	$ 931
Increase (Decrease) in Partners' Capital [Roll Forward]
Change in ownership of consolidated subsidiaries, net		$ 25,718
Net income (loss)	299,661
Ending balance (in shares) at Jun. 30, 2022					75,946	90,710
Ending balance at Jun. 30, 2022	2,270,760		689	1,535,192	$ 733,998	$ 881
Beginning balance (in shares) at Mar. 31, 2022					76,966	90,710
Beginning balance at Mar. 31, 2022	2,242,976		709	1,472,614	$ 768,747	$ 906
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation	335				335
Distribution equivalent rights payments	(113)				(113)
Distributions to public	(51,077)				(51,077)
Distributions to Diamondback	(64,012)			(63,497)	(490)	$ (25)
Distributions to General Partner	(20)		(20)
Change in ownership of consolidated subsidiaries, net	0	11,523		(11,523)	$ 11,523
Repurchased units as part of unit buyback (in shares)					(1,020)
Repurchased units as part of unit buyback	(28,949)				$ (28,949)
Net income (loss)	171,620			137,598	$ 34,022
Ending balance (in shares) at Jun. 30, 2022					75,946	90,710
Ending balance at Jun. 30, 2022	2,270,760		689	1,535,192	$ 733,998	$ 881
Beginning balance (in shares) at Dec. 31, 2022					73,230	90,710
Beginning balance at Dec. 31, 2022	2,321,525		649	1,630,866	$ 689,178	$ 832
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation	370				$ 370
Vesting of restricted stock units (shares)					4
Distribution equivalent rights payments	(72)				$ (72)
Distributions to public	(35,253)				(35,253)
Distributions to Diamondback	(49,366)			(48,983)	(358)	$ (25)
Distributions to General Partner	(20)		(20)
Change in ownership of consolidated subsidiaries, net	0			(11,449)	$ 11,449
Repurchased units as part of unit buyback (in shares)					(1,115)
Repurchased units as part of unit buyback	(33,022)				$ (33,022)
Net income (loss)	88,266			54,299	$ 33,967
Ending balance (in shares) at Mar. 31, 2023					72,119	90,710
Ending balance at Mar. 31, 2023	2,292,428		629	1,624,733	$ 666,259	$ 807
Beginning balance (in shares) at Dec. 31, 2022					73,230	90,710
Beginning balance at Dec. 31, 2022	2,321,525		649	1,630,866	$ 689,178	$ 832
Increase (Decrease) in Partners' Capital [Roll Forward]
Change in ownership of consolidated subsidiaries, net		28,198
Net income (loss)	168,197
Ending balance (in shares) at Jun. 30, 2023					71,207	90,710
Ending balance at Jun. 30, 2023	2,286,170		609	1,619,268	$ 665,511	$ 782
Beginning balance (in shares) at Mar. 31, 2023					72,119	90,710
Beginning balance at Mar. 31, 2023	2,292,428		629	1,624,733	$ 666,259	$ 807
Increase (Decrease) in Partners' Capital [Roll Forward]
Unit-based compensation	259				259
Distribution equivalent rights payments	(43)				(43)
Distributions to public	(23,513)				(23,513)
Distributions to Diamondback	(38,363)			(38,097)	(241)	$ (25)
Distributions to General Partner	(20)		(20)
Change in ownership of consolidated subsidiaries, net	0	$ 16,749		(16,749)	$ 16,749
Repurchased units as part of unit buyback (in shares)					(912)
Repurchased units as part of unit buyback	(24,509)				$ (24,509)
Net income (loss)	79,931			49,381	$ 30,550
Ending balance (in shares) at Jun. 30, 2023					71,207	90,710
Ending balance at Jun. 30, 2023	$ 2,286,170		$ 609	$ 1,619,268	$ 665,511	$ 782

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Cash flows from operating activities:
Net income (loss)	$ 168,197	$ 299,661
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Provision for (benefit from) deferred income taxes	532	0
Depletion	65,051	59,373
(Gain) loss on derivative instruments, net	27,697	20,248
Net cash receipts (payments) on derivatives	(6,212)	(17,029)
Other	1,222	2,893
Changes in operating assets and liabilities:
Royalty income receivable	892	(53,876)
Royalty income receivable—related party	1,876	(8,445)
Accounts payable and accrued liabilities	(2,583)	(5,580)
Accounts payable—related party	(306)	0
Income tax payable	673	2,288
Other	(4,370)	(513)
Net cash provided by (used in) operating activities	252,669	299,020
Cash flows from investing activities:
Acquisitions of oil and natural gas interests—related party	(75,073)	0
Acquisitions of oil and natural gas interests	(48,609)	1,862
Proceeds from sale of oil and natural gas interests	(1,975)	29,336
Other	1,200	0
Net cash provided by (used in) investing activities	(124,457)	31,198
Cash flows from financing activities:
Proceeds from borrowings under credit facility	191,000	144,000
Repayment on credit facility	(119,000)	(198,000)
Repayment of senior notes	0	(48,963)
Repurchased units as part of unit buyback	(57,531)	(68,209)
Distributions to public	(58,881)	(87,084)
Distributions to Diamondback	(87,729)	(107,015)
Other	(1,171)	(83)
Net cash provided by (used in) financing activities	(133,312)	(365,354)
Net increase (decrease) in cash and cash equivalents	(5,100)	(35,136)
Cash, cash equivalents and restricted cash at beginning of period	18,179	39,448
Cash, cash equivalents and restricted cash at end of period	$ 13,079	$ 4,312

ORGANIZATION AND BASIS OF PRESENTATION	6 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION	Jun. 30, 2023
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 focused on owning and acquiring mineral interests and royalty interests in oil and natural gas properties primarily in the Permian Basin. As of June 30, 2023, Viper Energy Partners GP LLC (the “General Partner”) held a 100% general partner interest in the Partnership and Diamondback Energy, Inc. (“Diamondback”) beneficially owned approximately 57% of the Partnership’s total limited partner units outstanding. Diamondback owns and controls the General Partner. Basis of Presentation The accompanying condensed consolidated financial statements and related notes thereto were prepared in accordance with GAAP. All material intercompany balances and transactions have been eliminated upon consolidation. We report our operations in one reportable segment. These condensed consolidated 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 SEC rules and regulations, although the Partnership believes the disclosures are adequate to make the information presented not misleading. This report should be read in conjunction with the Partnership’s most recent Annual Report on Form 10–K for the fiscal year ended December 31, 2022, which contains a summary of the Partnership’s significant accounting policies and other disclosures. Reclassifications Certain prior period amounts have been reclassified to conform to the current period financial statement presentation. These reclassifications had no effect on the previously reported total assets, total liabilities, unitholders’ equity, results of operations or cash flows.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2023

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates

Related Party Transactions

Royalty Income Receivable

Lease Bonus Income

Accrued Liabilities

Accrued liabilities consist of the following:


	June 30,		December 31,
	2023		2022
	(In thousands)
Interest payable	$	4,449	$	3,972
Ad valorem taxes payable	9,963		12,492
Derivatives instruments payable	1,756		1,684
Other	1,959		1,452
Total accrued liabilities	$	18,127	$	19,600

Recent Accounting Pronouncements

Recently Adopted Pronouncements

There are no recently adopted pronouncements.

Accounting Pronouncements Not Yet Adopted

REVENUE FROM CONTRACTS WITH CUSTOMERS

6 Months Ended

Jun. 30, 2023

Revenue from Contract with Customer [Abstract]

REVENUE FROM CONTRACTS WITH CUSTOMERS

The following table disaggregates the Partnership’s total royalty income by product type:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Oil income	$	139,300	$	191,195	$	275,919	$	346,246
Natural gas income	5,090		23,793		14,081		38,983
Natural gas liquids income	13,807		23,842		29,282		46,690
Total royalty income	$	158,197	$	238,830	$	319,282	$	431,919

ACQUISITIONS AND DIVESTITURES	6 Months Ended
ACQUISITIONS AND DIVESTITURES	Jun. 30, 2023
Business Combinations And Divestitures [Abstract]
ACQUISITIONS AND DIVESTITURES	ACQUISITIONS AND DIVESTITURES 2023 Activity Drop Down Transaction On March 8, 2023, the Partnership completed the acquisition of certain mineral and royalty interests from subsidiaries of Diamondback for approximately $74.5 million in cash, including customary post-closing adjustments for net title benefits (the ‘‘Drop Down’’). The mineral and royalty interests acquired in the Drop Down represent approximately 660 net royalty acres in Ward County in the Southern Delaware Basin, 100% of which are operated by Diamondback, and have an average net royalty interest of approximately 7.2% and current production of approximately 300 BO/d, approximately 72% of which is from oil. The Partnership funded the Drop Down through a combination of cash on hand and borrowings under the Operating Company’s revolving credit facility. The Drop Down was accounted for as a transaction between entities under common control with the properties acquired recorded at Diamondback’s historical carrying value in the Partnership’s condensed consolidated balance sheet. The historical carrying value of the properties approximated the Drop Down purchase price. Other Acquisitions Additionally in the first half of 2023, the Partnership acquired, in individually insignificant transactions from unrelated third-party sellers, mineral and royalty interests representing 203 net royalty acres in the Permian Basin for an aggregate purchase price of approximately $48.1 million, subject to customary post-closing adjustments. The Partnership funded these acquisitions with cash on hand and borrowings under the Operating Company’s revolving credit facility. 2022 Activity Acquisitions During the year ended December 31, 2022, in individually insignificant transactions, the Partnership acquired, from unrelated third-party sellers, mineral and royalty interests representing 375 net royalty acres in the Permian Basin for an aggregate net purchase price of approximately $65.8 million, including certain customary post-closing adjustments. The Partnership funded these acquisitions with cash on hand and borrowings under the Operating Company’s revolving credit facility. Divestitures In the first quarter of 2022, the Partnership divested 325 net royalty acres of third party operated acreage located entirely in Upton and Reagan counties in the Midland Basin for an aggregate net sales price of $29.3 million, including customary closing adjustments. In the third quarter of 2022, the Partnership divested 93 net royalty acres of third party operated acreage located entirely in Loving county in the Delaware Basin for an aggregate net sales price of $29.9 million, including customary closing adjustments. In the fourth quarter of 2022, the Partnership divested its entire position in the Eagle Ford Shale consisting of 681 net royalty acres of third party operated acreage for an aggregate net sales price of $53.7 million, including customary closing adjustments.

OIL AND NATURAL GAS INTERESTS

6 Months Ended

Jun. 30, 2023

Extractive Industries [Abstract]

OIL AND NATURAL GAS INTERESTS

Oil and natural gas interests include the following:


	June 30,		December 31,
	2023		2022
	(In thousands)
Oil and natural gas interests:
Subject to depletion	$	2,394,553	$	2,167,598
Not subject to depletion	1,195,923		1,297,221
Gross oil and natural gas interests	3,590,476		3,464,819
Accumulated depletion and impairment	(785,286)		(720,234)
Oil and natural gas interests, net	2,805,190		2,744,585
Land	5,688		5,688
Property, net of accumulated depletion and impairment	$	2,810,878	$	2,750,273

As of June 30, 2023 and December 31, 2022, the Partnership had mineral and royalty interests representing 27,178 and 26,315 net royalty acres, respectively.

DEBT

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

DEBT

Long-term debt consisted of the following as of the dates indicated:


	June 30,		December 31,
	2023		2022
	(In thousands)
5.375% senior unsecured notes due 2027	$	430,350	$	430,350
Revolving credit facility	224,000		152,000
Unamortized debt issuance costs	(1,171)		(1,306)
Unamortized discount	(3,763)		(4,149)
Total long-term debt	$	649,416	$	576,895

The Operating Company’s Revolving Credit Facility

As of June 30, 2023, the Operating Company was in compliance with the financial maintenance covenants under its credit agreement.

UNITHOLDERS’ EQUITY AND DISTRIBUTIONS

6 Months Ended

Jun. 30, 2023

Equity [Abstract]

UNITHOLDERS’ EQUITY AND DISTRIBUTIONS

Common Unit Repurchase Program

Cash Distributions

The following table presents information regarding cash distributions approved by the board of directors of the General Partner for the periods presented (in thousands, except for per unit amounts):




Period	Amount per Operating Company Unit		Operating Company Distributions to Diamondback		Amount per Common Unit		Distributions to Common Unitholders(1)		Declaration Date	Unitholder Record Date	Payment Date
Q4 2022	$	0.54	$	48,983	$	0.49	$	35,683	February 15, 2023	March 3, 2023	March 10, 2023
Q1 2023	$	0.42	$	38,097	$	0.33	$	23,797	April 26, 2023	May 11, 2023	May 18, 2023

(1)Includes amounts paid to Diamondback for the 731,500 common units beneficially owned by Diamondback and distribution equivalent rights payments.

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.

Change in Ownership of Consolidated Subsidiaries


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Net income (loss) attributable to the Partnership	$	30,550	$	34,022	$	64,517	$	50,627

Change in ownership of consolidated subsidiaries	16,749		11,523		28,198		25,718




Change from net income (loss) attributable to the Partnership's unitholders and transfers to non-controlling interest	$	47,299	$	45,545	$	92,715	$	76,345

EARNINGS PER COMMON UNIT

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

EARNINGS PER COMMON UNIT

A reconciliation of the components of basic and diluted earnings per common unit is presented in the table below:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Net income (loss) attributable to the period	$	30,550	$	34,022	$	64,517	$	50,627
Less: distributed and undistributed earnings allocated to participating securities(1)	56		113		123		177
Net income (loss) attributable to common unitholders	$	30,494	$	33,909	$	64,394	$	50,450
Weighted average common units outstanding:
Basic weighted average common units outstanding	71,771		76,620		72,249		76,861
Effect of dilutive securities:
Potential common units issuable(2)	—		109		—		117
Diluted weighted average common units outstanding	71,771		76,729		72,249		76,978
Net income (loss) per common unit, basic	$	0.42	$	0.44	$	0.89	$	0.66
Net income (loss) per common unit, diluted	$	0.42	$	0.44	$	0.89	$	0.66

INCOME TAXES

6 Months Ended

Jun. 30, 2023

Income Tax Disclosure [Abstract]

INCOME TAXES

The following table provides the Partnership’s provision for (benefit from) income taxes and the effective income tax rate for the dates indicated:


	Three Months Ended June 30,						Six Months Ended June 30,
	2023			2022			2023			2022
	(In thousands, except for tax rate)
Provision for (benefit from) income taxes	$	8,450		$	6,182		$	17,856		$	8,812
Effective tax rate	9.6		%	3.5		%	9.6		%	2.9		%

DERIVATIVES

6 Months Ended

Jun. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVES

Commodity Contracts

As of June 30, 2023, the Partnership had the following outstanding derivative contracts. When aggregating multiple contracts, the weighted average contract price is disclosed.


					Swaps	Puts
Settlement Month	Settlement Year	Type of Contract	Bbls/Mcf Per Day	Index	Weighted Average Differential		Strike Price	Deferred Premium
OIL
Jul. - Sep.	2023	Puts	12,000	WTI Cushing	$—		$55.00	$1.80
Oct. - Dec.	2023	Puts	12,000	WTI Cushing	$—		$55.00	$1.85

Jul. - Dec.	2023	Basis Swaps	4,000	Argus WTI Midland	$1.05		$—	$—
NATURAL GAS
Jul. - Dec.	2023	Basis Swaps	30,000	Waha Hub	$(1.33)		$—	$—
Jan. - Dec.	2024	Basis Swaps	30,000	Waha Hub	$(1.20)		$—	$—

Balance Sheet Offsetting of Derivative Assets and Liabilities

Gains and Losses on Derivative Instruments


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Gain (loss) on derivative instruments	$	(12,594)	$	(1,889)	$	(27,697)	$	(20,248)
Net cash receipts (payments) on derivatives(1)	$	(3,997)	$	(6,765)	$	(6,212)	$	(17,029)

(1)The six months ended June 30, 2022 includes cash paid on commodity contracts terminated prior to their contractual maturity of $4.2 million.

FAIR VALUE MEASUREMENTS

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

Assets and Liabilities Measured at Fair Value on a Recurring Basis


	As of June 30, 2023
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	1,541	$	—	$	1,541	$	(1,541)	$	—



Liabilities:
Current:
Derivative instruments	$	—	$	9,890	$	—	$	9,890	$	(1,541)	$	8,349
Non-current:
Derivative instruments	$	—	$	3,373	$	—	$	3,373	$	—	$	3,373


	As of December 31, 2022
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	13,296	$	—	$	13,296	$	(3,968)	$	9,328
Non-current:

Derivative instruments	$	—	$	1,911	$	—	$	1,911	$	(1,469)	$	442
Liabilities:
Current:
Derivative instruments	$	—	$	3,968	$	—	$	3,968	$	(3,968)	$	—
Non-current:
Derivative instruments	$	—	$	1,476	$	—	$	1,476	$	(1,469)	$	7

Assets and Liabilities Not Recorded at Fair Value

The following table provides the fair value of financial instruments that are not recorded at fair value in the condensed consolidated balance sheets:


	June 30, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
Debt:
Revolving credit facility	$	224,000	$	224,000	$	152,000	$	152,000
5.375% senior notes due 2027(1)	$	425,416	$	413,097	$	424,895	$	411,634

(1) The carrying value includes associated deferred loan costs and any discount.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Fair Value of Financial Assets

COMMITMENTS AND CONTINGENCIES	6 Months Ended
COMMITMENTS AND CONTINGENCIES	Jun. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIESThe Partnership is a party to various routine legal proceedings, disputes and claims from time to time arising in the ordinary course of its business. While the ultimate outcome of the pending proceedings, disputes or claims, and any resulting impact on the Partnership, cannot be predicted with certainty, the Partnership’s management believes that none of these matters, if ultimately decided adversely, will have a material adverse effect on the Partnership’s financial condition, results of operations or cash flows. The Partnership’s assessment is based on information known about the pending matters and its experience in contesting, litigating and settling similar matters. Actual outcomes could differ materially from the Partnership’s assessment. The Partnership records reserves for contingencies related to outstanding legal proceedings, disputes or claims when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

SUBSEQUENT EVENTS	6 Months Ended
SUBSEQUENT EVENTS	Jun. 30, 2023
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Cash Distribution On July 25, 2023, the board of directors of the General Partner approved an increase to the Partnership’s annual base dividend to $1.08 per common unit beginning with the distribution payable for the second quarter of 2023, and a cash distribution for the second quarter of 2023 of $0.36 per common unit and $0.44 per Class B unit, payable on August 17, 2023, to eligible unitholders of record at the close of business on August 10, 2023. For the second quarter of 2023, the distribution to common unitholders consists of a base quarterly distribution of $0.27 per common unit and a variable quarterly distribution of $0.09 per common unit.

Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Thousands	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pay vs Performance Disclosure
Net income (loss) attributable to the period	$ 30,550	$ 34,022	$ 64,517	$ 50,627

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Jun. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	6 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	Jun. 30, 2023
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying condensed consolidated financial statements and related notes thereto were prepared in accordance with GAAP. All material intercompany balances and transactions have been eliminated upon consolidation. We report our operations in one reportable segment. These condensed consolidated 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 SEC rules and regulations, although the Partnership believes the disclosures are adequate to make the information presented not misleading. This report should be read in conjunction with the Partnership’s most recent Annual Report on Form 10–K for the fiscal year ended December 31, 2022, which contains a summary of the Partnership’s significant accounting policies and other disclosures.
Reclassifications	Reclassifications Certain prior period amounts have been reclassified to conform to the current period financial statement presentation. These reclassifications had no effect on the previously reported total assets, total liabilities, unitholders’ equity, results of operations or cash flows.
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 as of the date of the financial statements. Making accurate estimates and assumptions is particularly difficult in the oil and natural gas industry given the challenges resulting from volatility in oil and natural gas prices. For instance, the war in Ukraine, rising interest rates, global supply chain disruptions, concerns about a potential economic downturn or recession, and measures to combat persistent inflation and instability in the financial sector have contributed to recent pricing and economic volatility. The financial results of companies in the oil and natural gas industry have been and may continue to be impacted materially as a result of changing market conditions. Such circumstances generally increase uncertainty in the Partnership’s accounting estimates, particularly those involving financial forecasts. The Partnership evaluates these estimates on an ongoing basis, using historical experience, consultation with experts and other methods the Partnership considers reasonable in each particular circumstance. 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, estimates of third party operated royalty income related to expected sales volumes and prices, the recoverability of costs of unevaluated properties, the fair value determination of assets and liabilities, including those acquired by the Partnership, fair value estimates of commodity derivatives and estimates of income taxes, including deferred tax valuation allowances.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Recently Adopted Pronouncements There are no recently adopted pronouncements. Accounting Pronouncements Not Yet Adopted The Partnership considers the applicability and impact of all ASUs. There are no recent accounting pronouncements not yet adopted that are expected to have a material effect on the Partnership upon adoption, as applicable.
Revenue from Contracts with Customers	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 at the wellhead or at the gas processing facility based on the Partnership’s percentage ownership share of the revenue, net of any deductions for gathering and transportation. Virtually all of the pricing provisions in the Partnership’s contracts are tied to a market index.
Fair Value Measurement	Assets and Liabilities Measured at Fair Value on a Recurring Basis As discussed in Note 11—Fair Value Measurements in the Partnership's Annual Report on Form 10-K for the year ended December 31, 2022, certain assets and liabilities are reported at fair value on a recurring basis on the Partnership’s condensed consolidated balance sheets, including the Partnership’s derivative instruments. The fair values of the Partnership’s derivative contracts are measured internally using established commodity futures price strips for the underlying commodity provided by a reputable third party, the contracted notional volumes, and time to maturity. These valuations are Level 2 inputs in the fair value hierarchy. The net amounts are classified as current or noncurrent based on their anticipated settlement dates.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

6 Months Ended

Jun. 30, 2023

Accounting Policies [Abstract]

Schedule of Accrued Liabilities

Accrued liabilities consist of the following:


	June 30,		December 31,
	2023		2022
	(In thousands)
Interest payable	$	4,449	$	3,972
Ad valorem taxes payable	9,963		12,492
Derivatives instruments payable	1,756		1,684
Other	1,959		1,452
Total accrued liabilities	$	18,127	$	19,600

REVENUE FROM CONTRACTS WITH CUSTOMERS (Tables)

6 Months Ended

Jun. 30, 2023

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following table disaggregates the Partnership’s total royalty income by product type:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Oil income	$	139,300	$	191,195	$	275,919	$	346,246
Natural gas income	5,090		23,793		14,081		38,983
Natural gas liquids income	13,807		23,842		29,282		46,690
Total royalty income	$	158,197	$	238,830	$	319,282	$	431,919

OIL AND NATURAL GAS INTERESTS (Tables)

6 Months Ended

Jun. 30, 2023

Extractive Industries [Abstract]

Aggregate Capitalized Costs Related to Oil and Natural Gas Production Activities

Oil and natural gas interests include the following:


	June 30,		December 31,
	2023		2022
	(In thousands)
Oil and natural gas interests:
Subject to depletion	$	2,394,553	$	2,167,598
Not subject to depletion	1,195,923		1,297,221
Gross oil and natural gas interests	3,590,476		3,464,819
Accumulated depletion and impairment	(785,286)		(720,234)
Oil and natural gas interests, net	2,805,190		2,744,585
Land	5,688		5,688
Property, net of accumulated depletion and impairment	$	2,810,878	$	2,750,273

DEBT (Tables)

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Schedule of Maturities of Long-Term Debt

Long-term debt consisted of the following as of the dates indicated:


	June 30,		December 31,
	2023		2022
	(In thousands)
5.375% senior unsecured notes due 2027	$	430,350	$	430,350
Revolving credit facility	224,000		152,000
Unamortized debt issuance costs	(1,171)		(1,306)
Unamortized discount	(3,763)		(4,149)
Total long-term debt	$	649,416	$	576,895

UNITHOLDERS’ EQUITY AND DISTRIBUTIONS (Tables)

6 Months Ended

Jun. 30, 2023

Equity [Abstract]

Schedule of Cash Distributions

The following table presents information regarding cash distributions approved by the board of directors of the General Partner for the periods presented (in thousands, except for per unit amounts):




Period	Amount per Operating Company Unit		Operating Company Distributions to Diamondback		Amount per Common Unit		Distributions to Common Unitholders(1)		Declaration Date	Unitholder Record Date	Payment Date
Q4 2022	$	0.54	$	48,983	$	0.49	$	35,683	February 15, 2023	March 3, 2023	March 10, 2023
Q1 2023	$	0.42	$	38,097	$	0.33	$	23,797	April 26, 2023	May 11, 2023	May 18, 2023

(1)Includes amounts paid to Diamondback for the 731,500 common units beneficially owned by Diamondback and distribution equivalent rights payments.

Schedule of Change in Ownership Interest

The following table summarizes the changes in common unitholder equity due to changes in ownership interest during the period:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Net income (loss) attributable to the Partnership	$	30,550	$	34,022	$	64,517	$	50,627

Change in ownership of consolidated subsidiaries	16,749		11,523		28,198		25,718




Change from net income (loss) attributable to the Partnership's unitholders and transfers to non-controlling interest	$	47,299	$	45,545	$	92,715	$	76,345

EARNINGS PER COMMON UNIT (Tables)

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Schedule of Basic and Diluted Net Income (Loss) Per Common Unit

A reconciliation of the components of basic and diluted earnings per common unit is presented in the table below:


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Net income (loss) attributable to the period	$	30,550	$	34,022	$	64,517	$	50,627
Less: distributed and undistributed earnings allocated to participating securities(1)	56		113		123		177
Net income (loss) attributable to common unitholders	$	30,494	$	33,909	$	64,394	$	50,450
Weighted average common units outstanding:
Basic weighted average common units outstanding	71,771		76,620		72,249		76,861
Effect of dilutive securities:
Potential common units issuable(2)	—		109		—		117
Diluted weighted average common units outstanding	71,771		76,729		72,249		76,978
Net income (loss) per common unit, basic	$	0.42	$	0.44	$	0.89	$	0.66
Net income (loss) per common unit, diluted	$	0.42	$	0.44	$	0.89	$	0.66

INCOME TAXES (Tables)

6 Months Ended

Jun. 30, 2023

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation

The following table provides the Partnership’s provision for (benefit from) income taxes and the effective income tax rate for the dates indicated:


	Three Months Ended June 30,						Six Months Ended June 30,
	2023			2022			2023			2022
	(In thousands, except for tax rate)
Provision for (benefit from) income taxes	$	8,450		$	6,182		$	17,856		$	8,812
Effective tax rate	9.6		%	3.5		%	9.6		%	2.9		%

DERIVATIVES (Tables)

6 Months Ended

Jun. 30, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments

As of June 30, 2023, the Partnership had the following outstanding derivative contracts. When aggregating multiple contracts, the weighted average contract price is disclosed.


					Swaps	Puts
Settlement Month	Settlement Year	Type of Contract	Bbls/Mcf Per Day	Index	Weighted Average Differential		Strike Price	Deferred Premium
OIL
Jul. - Sep.	2023	Puts	12,000	WTI Cushing	$—		$55.00	$1.80
Oct. - Dec.	2023	Puts	12,000	WTI Cushing	$—		$55.00	$1.85

Jul. - Dec.	2023	Basis Swaps	4,000	Argus WTI Midland	$1.05		$—	$—
NATURAL GAS
Jul. - Dec.	2023	Basis Swaps	30,000	Waha Hub	$(1.33)		$—	$—
Jan. - Dec.	2024	Basis Swaps	30,000	Waha Hub	$(1.20)		$—	$—

Summary of Derivative Contract Gains and Losses Included in the Consolidated Statements of Operations


	Three Months Ended June 30,				Six Months Ended June 30,
	2023		2022		2023		2022
	(In thousands)
Gain (loss) on derivative instruments	$	(12,594)	$	(1,889)	$	(27,697)	$	(20,248)
Net cash receipts (payments) on derivatives(1)	$	(3,997)	$	(6,765)	$	(6,212)	$	(17,029)

(1)The six months ended June 30, 2022 includes cash paid on commodity contracts terminated prior to their contractual maturity of $4.2 million.

FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value Consolidated Balance Sheets


	As of June 30, 2023
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	1,541	$	—	$	1,541	$	(1,541)	$	—



Liabilities:
Current:
Derivative instruments	$	—	$	9,890	$	—	$	9,890	$	(1,541)	$	8,349
Non-current:
Derivative instruments	$	—	$	3,373	$	—	$	3,373	$	—	$	3,373


	As of December 31, 2022
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	13,296	$	—	$	13,296	$	(3,968)	$	9,328
Non-current:

Derivative instruments	$	—	$	1,911	$	—	$	1,911	$	(1,469)	$	442
Liabilities:
Current:
Derivative instruments	$	—	$	3,968	$	—	$	3,968	$	(3,968)	$	—
Non-current:
Derivative instruments	$	—	$	1,476	$	—	$	1,476	$	(1,469)	$	7

Offsetting Assets


	As of June 30, 2023
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	1,541	$	—	$	1,541	$	(1,541)	$	—



Liabilities:
Current:
Derivative instruments	$	—	$	9,890	$	—	$	9,890	$	(1,541)	$	8,349
Non-current:
Derivative instruments	$	—	$	3,373	$	—	$	3,373	$	—	$	3,373


	As of December 31, 2022
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	13,296	$	—	$	13,296	$	(3,968)	$	9,328
Non-current:

Derivative instruments	$	—	$	1,911	$	—	$	1,911	$	(1,469)	$	442
Liabilities:
Current:
Derivative instruments	$	—	$	3,968	$	—	$	3,968	$	(3,968)	$	—
Non-current:
Derivative instruments	$	—	$	1,476	$	—	$	1,476	$	(1,469)	$	7

Offsetting Liabilities


	As of June 30, 2023
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	1,541	$	—	$	1,541	$	(1,541)	$	—



Liabilities:
Current:
Derivative instruments	$	—	$	9,890	$	—	$	9,890	$	(1,541)	$	8,349
Non-current:
Derivative instruments	$	—	$	3,373	$	—	$	3,373	$	—	$	3,373


	As of December 31, 2022
	Level 1		Level 2		Level 3		Total Gross Fair Value		Gross Amounts Offset in Balance Sheet		Net Fair Value Presented in Balance Sheet
	(In thousands)
Assets:
Current:
Derivative instruments	$	—	$	13,296	$	—	$	13,296	$	(3,968)	$	9,328
Non-current:

Derivative instruments	$	—	$	1,911	$	—	$	1,911	$	(1,469)	$	442
Liabilities:
Current:
Derivative instruments	$	—	$	3,968	$	—	$	3,968	$	(3,968)	$	—
Non-current:
Derivative instruments	$	—	$	1,476	$	—	$	1,476	$	(1,469)	$	7

Fair Value Measurements, Nonrecurring

The following table provides the fair value of financial instruments that are not recorded at fair value in the condensed consolidated balance sheets:


	June 30, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
Debt:
Revolving credit facility	$	224,000	$	224,000	$	152,000	$	152,000
5.375% senior notes due 2027(1)	$	425,416	$	413,097	$	424,895	$	411,634

(1) The carrying value includes associated deferred loan costs and any discount.

ORGANIZATION AND BASIS OF PRESENTATION (Details)	6 Months Ended
ORGANIZATION AND BASIS OF PRESENTATION (Details)	Jun. 30, 2023 segment
Limited Partners' Capital Account [Line Items]
Number of reportable segments	1
Viper Energy Partners LP \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Percent of general partner interest	100.00%
Percent of limited partnership interest	57.00%

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) - Affiliated Entity - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Royalty Income Receivable
Related Party Transaction [Line Items]
Royalty income receivable (net of allowance for credit losses)	$ 4,400,000		$ 4,400,000		$ 6,300,000
Midland Basin Lease Bonus Income
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction	$ 1,300,000	$ 0	$ 8,300,000	$ 6,300,000

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Accrued Liabilities) (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Interest payable	$ 4,449	$ 3,972
Ad valorem taxes payable	9,963	12,492
Derivatives instruments payable	1,756	1,684
Other	1,959	1,452
Total accrued liabilities	$ 18,127	$ 19,600

REVENUE FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Disaggregation of Revenue [Line Items]
Royalty income	$ 158,197	$ 238,830	$ 319,282	$ 431,919
Oil income
Disaggregation of Revenue [Line Items]
Royalty income	139,300	191,195	275,919	346,246
Natural gas income
Disaggregation of Revenue [Line Items]
Royalty income	5,090	23,793	14,081	38,983
Natural gas liquids income
Disaggregation of Revenue [Line Items]
Royalty income	$ 13,807	$ 23,842	$ 29,282	$ 46,690

ACQUISITIONS AND DIVESTITURES - Acquisitions (Details) $ in Millions		6 Months Ended	12 Months Ended
	Mar. 08, 2023 USD ($) a bbl	Jun. 30, 2023 USD ($) a	Dec. 31, 2022 USD ($) a
2023 Acquisition Permian Basin
Asset Acquisition [Line Items]
Aggregate purchase price \| $		$ 48.1
Net royalty (acres) \| a		203
2022 Acquisition Permian Basin
Asset Acquisition [Line Items]
Aggregate purchase price \| $			$ 65.8
Net royalty (acres) \| a			375
Drop Down Acquisition
Asset Acquisition [Line Items]
Aggregate purchase price \| $	$ 74.5
Net royalty (acres) \| a	660
Percentage of acreage acquired	100.00%
Average net royalty interest	7.20%
Oil production per day \| bbl	300
Production of oil, rate	72.00%

ACQUISITIONS AND DIVESTITURES - Divestitures (Details) - Discontinued Operations, Disposed of by Sale $ in Millions	3 Months Ended
	Dec. 31, 2022 USD ($) a	Sep. 30, 2022 USD ($) a	Mar. 31, 2022 USD ($) a
Midland Basin \| Third Party Operated Acreage
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Area of land divested \| a			325
Proceeds from sale of acres \| $			$ 29.3
Delaware Basin \| Third Party Operated Acreage
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Area of land divested \| a		93
Proceeds from sale of acres \| $		$ 29.9
Delaware Basin \| Eagle Ford Shale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Area of land divested \| a	681
Proceeds from sale of acres \| $	$ 53.7

OIL AND NATURAL GAS INTERESTS (Details)	3 Months Ended		6 Months Ended
OIL AND NATURAL GAS INTERESTS (Details)	Jun. 30, 2023 USD ($) a	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) a	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) a
Oil and natural gas interests:
Subject to depletion	$ 2,394,553,000		$ 2,394,553,000		$ 2,167,598,000
Not subject to depletion	1,195,923,000		1,195,923,000		1,297,221,000
Gross oil and natural gas interests	3,590,476,000		3,590,476,000		3,464,819,000
Accumulated depletion and impairment	(785,286,000)		(785,286,000)		(720,234,000)
Oil and natural gas interests, net	2,805,190,000		2,805,190,000		2,744,585,000
Land	5,688,000		5,688,000		5,688,000
Property, net	$ 2,810,878,000		$ 2,810,878,000		$ 2,750,273,000
Mineral properties, net royalty acres \| a	27,178		27,178		26,315
Impairment	$ 0	$ 0	$ 0	$ 0

DEBT - Schedule of Debt (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Line of Credit Facility [Line Items]
Unamortized debt issuance costs	$ (1,171)	$ (1,306)
Unamortized discount	(3,763)	(4,149)
Total long-term debt	649,416	576,895
Revolving credit facility
Line of Credit Facility [Line Items]
Long term debt gross	$ 224,000	152,000
5.375 % Senior Notes due 2027 \| Senior Notes
Line of Credit Facility [Line Items]
Debt instrument, interest rate, stated percentage	5.375%
Long term debt gross	$ 430,350	$ 430,350

DEBT - Narrative (Details) - Revolving credit facility - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	May 31, 2023	May 30, 2023
Line of Credit Facility [Line Items]
Credit facility maximum borrowing capacity					$ 2,000,000,000
Credit facility borrowing base					1,000,000,000	$ 580,000,000
Commitment amount					$ 750,000,000	$ 500,000,000
Debt outstanding	$ 224,000,000		$ 224,000,000
Credit facility remaining borrowing capacity	$ 526,000,000		$ 526,000,000
Weighted average interest rate	7.53%	3.20%	7.24%	2.88%

UNITHOLDERS’ EQUITY AND DISTRIBUTIONS - Narrative (Details) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Limited Partners' Capital Account [Line Items]
Stock repurchased	$ 24,509,000	$ 33,022,000	$ 28,949,000	$ 39,260,000
Cash Distribution
Limited Partners' Capital Account [Line Items]
Cash distributions, period after end of each quarter					60 days
Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units outstanding (in shares)	731,500				731,500
Conversion of shares converted (in shares)					1
Viper Energy Partners LP \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Percent of limited partnership interest					57.00%
Ownership percentage by noncontrolling owners	56.00%				56.00%
Common Units
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units issued (in shares)	71,206,622				71,206,622		73,229,645
Limited partners' capital account, units outstanding (in shares)	71,206,622				71,206,622		73,229,645
Conversion of shares, stock issued (in shares)					1
Common Units \| Common Unit Repurchase Program
Limited Partners' Capital Account [Line Items]
Authorized amount	$ 750,000,000				$ 750,000,000
Stock repurchased	24,300,000		$ 28,900,000		57,000,000	$ 68,200,000
Remaining authorized repurchase amount	$ 472,400,000				$ 472,400,000
Common Units \| Common Unit Repurchase Program \| Affiliated Entity
Limited Partners' Capital Account [Line Items]
Stock repurchased						$ 37,300,000
Stock repurchased (in shares)						1,500,000
Common Units \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units issued (in shares)	731,500				731,500
Limited partners' capital account, units outstanding (in shares)	731,500				731,500
Class B Units
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units issued (in shares)	90,709,946				90,709,946		90,709,946
Limited partners' capital account, units outstanding (in shares)	90,709,946				90,709,946		90,709,946
Conversion of shares converted (in shares)					1
Class B Units \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units issued (in shares)	90,709,946				90,709,946
Limited partners' capital account, units outstanding (in shares)	90,709,946				90,709,946
Operating Company Units \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units outstanding (in shares)	90,709,946				90,709,946

UNITHOLDERS’ EQUITY AND DISTRIBUTIONS - Partnership Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands			3 Months Ended
	Apr. 26, 2023	Feb. 15, 2023	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2022
Limited Partners' Capital Account [Line Items]
Distributions			$ 23,513	$ 35,253	$ 51,077	$ 35,830
Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units outstanding (in shares)			731,500
Common Units
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units outstanding (in shares)			71,206,622				73,229,645
Common Units \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Limited partners' capital account, units outstanding (in shares)			731,500
Cash Distribution
Limited Partners' Capital Account [Line Items]
Cash distributions, amount per common unit (in USD per share)	$ 0.33	$ 0.49
Cash Distribution \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Cash distributions, amount per common unit (in USD per share)	$ 0.42	$ 0.54
Cash Distribution \| Common Units
Limited Partners' Capital Account [Line Items]
Distributions	$ 23,797	$ 35,683
Cash Distribution \| Common Units \| Diamondback Energy, Inc.
Limited Partners' Capital Account [Line Items]
Distributions	$ 38,097	$ 48,983

UNITHOLDERS’ EQUITY AND DISTRIBUTIONS - Ownership Interest in Subsidiary Changes (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2023	Jun. 30, 2022
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Net income (loss) attributable to the Partnership	$ 30,550		$ 34,022		$ 64,517	$ 50,627
Change in ownership of consolidated subsidiaries	0	$ 0	0	$ 0
Limited Partners
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Net income (loss) attributable to the Partnership	30,550		34,022		64,517	50,627
Change in ownership of consolidated subsidiaries	16,749		11,523		28,198	25,718
Change from net income (loss) attributable to the Partnership's unitholders and transfers to non-controlling interest	$ 47,299		$ 45,545		$ 92,715	$ 76,345

EARNINGS PER COMMON UNIT (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Earnings Per Share [Abstract]
Net income (loss) attributable to the period	$ 30,550	$ 34,022	$ 64,517	$ 50,627
Less: distributed and undistributed earnings allocated to participating securities	56	113	123	177
Net income (loss) attributable to common unitholders	$ 30,494	$ 33,909	$ 64,394	$ 50,450
Weighted average common units outstanding:
Basic weighted average common units outstanding (in shares)	71,771,000	76,620,000	72,249,000	76,861,000
Effect of dilutive securities:
Potential common units issuable (in shares)	0	109,000	0	117,000
Diluted weighted average common units outstanding (in shares)	71,771,000	76,729,000	72,249,000	76,978,000
Net income (loss) per common unit, basic (in USD per share)	$ 0.42	$ 0.44	$ 0.89	$ 0.66
Net income (loss) per common unit, diluted (in USD per share)	$ 0.42	$ 0.44	$ 0.89	$ 0.66
Anti-dilutive for potentially dilute basic earnings per common unit (in shares)	0	0	0	0

INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
INCOME TAXES (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Tax Disclosure [Abstract]
Provision for (benefit from) income taxes	$ 8,450	$ 6,182	$ 17,856	$ 8,812
Effective tax rate	9.60%	3.50%	9.60%	2.90%

DERIVATIVES - Open Derivative Positions (Details) bbl in Thousands, Mcf in Thousands	6 Months Ended
	Jun. 30, 2023 $ / bbl $ / MMBTU bbl Mcf
OIL \| WTI Cushing \| Puts \| 2023 \| Jul. - Sep.
Derivative [Line Items]
Volume \| bbl	12
Weighted average differential (per Bbl)	0
Strike Price (USD per Bbl)	55.00
Deferred premium at a weighted average price (USD per Bbl)	1.80
OIL \| WTI Cushing \| Puts \| 2023 \| Oct. - Dec.
Derivative [Line Items]
Volume \| bbl	12
Weighted average differential (per Bbl)	0
Strike Price (USD per Bbl)	55.00
Deferred premium at a weighted average price (USD per Bbl)	1.85
OIL \| Argus WTI Midland \| Basis Swap \| 2023 \| Jul. - Dec.
Derivative [Line Items]
Volume \| bbl	4
Weighted average differential (per Bbl)	1.05
Strike Price (USD per Bbl)	0
Deferred premium at a weighted average price (USD per Bbl)	0
NATURAL GAS \| Waha Hub \| Basis Swap \| 2023 \| Jul. - Dec.
Derivative [Line Items]
Volume \| Mcf	30
Weighted average differential (per Bbl) \| $ / MMBTU	(1.33)
Strike Price (USD per Bbl)	0
Deferred premium at a weighted average price (USD per Bbl)	0
NATURAL GAS \| Waha Hub \| Basis Swap \| 2024 \| Jan. - Dec.
Derivative [Line Items]
Volume \| Mcf	30
Weighted average differential (per Bbl)	(1.20)
Strike Price (USD per Bbl)	0
Deferred premium at a weighted average price (USD per Bbl)	0

DERIVATIVES - Gains and Losses on Derivative Instruments Included in Statement of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gain (loss) on derivative instruments	$ (12,594)	$ (1,889)	$ (27,697)	$ (20,248)
Net cash receipts (payments) on derivatives	$ (3,997)	$ (6,765)	$ (6,212)	(17,029)
Cash paid on commodity contract				$ 4,200

FAIR VALUE MEASUREMENTS - Recurring Measurements (Details) - Fair Value, Recurring - Derivative instruments - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
Current Assets
Assets:
Total Gross Fair Value	$ 1,541	$ 13,296
Gross Amounts Offset in Balance Sheet	(1,541)	(3,968)
Net Fair Value Presented in Balance Sheet	0	9,328
Noncurrent Assets
Assets:
Total Gross Fair Value		1,911
Gross Amounts Offset in Balance Sheet		(1,469)
Net Fair Value Presented in Balance Sheet		442
Current Liabilities
Liabilities:
Total Gross Fair Value	9,890	3,968
Gross Amounts Offset in Balance Sheet	(1,541)	(3,968)
Net Fair Value Presented in Balance Sheet	8,349	0
Noncurrent Liabilities
Liabilities:
Total Gross Fair Value	3,373	1,476
Gross Amounts Offset in Balance Sheet	0	(1,469)
Net Fair Value Presented in Balance Sheet	3,373	7
Level 1 \| Current Assets
Assets:
Total Gross Fair Value	0	0
Level 1 \| Noncurrent Assets
Assets:
Total Gross Fair Value		0
Level 1 \| Current Liabilities
Liabilities:
Total Gross Fair Value	0	0
Level 1 \| Noncurrent Liabilities
Liabilities:
Total Gross Fair Value	0	0
Level 2 \| Current Assets
Assets:
Total Gross Fair Value	1,541	13,296
Level 2 \| Noncurrent Assets
Assets:
Total Gross Fair Value		1,911
Level 2 \| Current Liabilities
Liabilities:
Total Gross Fair Value	9,890	3,968
Level 2 \| Noncurrent Liabilities
Liabilities:
Total Gross Fair Value	3,373	1,476
Level 3 \| Current Assets
Assets:
Total Gross Fair Value	0	0
Level 3 \| Noncurrent Assets
Assets:
Total Gross Fair Value		0
Level 3 \| Current Liabilities
Liabilities:
Total Gross Fair Value	0	0
Level 3 \| Noncurrent Liabilities
Liabilities:
Total Gross Fair Value	$ 0	$ 0

FAIR VALUE MEASUREMENTS - Fair Value of Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Thousands	Jun. 30, 2023	Dec. 31, 2022
5.375% senior notes due 2027 \| Senior Notes
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt instrument, interest rate, stated percentage	5.375%
Carrying Value \| Fair Value, Nonrecurring \| 5.375% senior notes due 2027
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	$ 425,416	$ 424,895
Carrying Value \| Fair Value, Nonrecurring \| Revolving credit facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	224,000	152,000
Fair Value \| Fair Value, Nonrecurring \| 5.375% senior notes due 2027
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	413,097	411,634
Fair Value \| Fair Value, Nonrecurring \| Revolving credit facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt	$ 224,000	$ 152,000

SUBSEQUENT EVENTS (Details) - $ / shares	Jul. 25, 2023	Apr. 26, 2023	Feb. 15, 2023	Jun. 30, 2023
Cash Distribution
Subsequent Event [Line Items]
Cash distributions, amount per common unit (in USD per share)		$ 0.33	$ 0.49
Fixed Dividend \| Common Units
Subsequent Event [Line Items]
Dividends payable (usd per share)				$ 0.27
Variable Dividend \| Common Units
Subsequent Event [Line Items]
Dividends payable (usd per share)				$ 0.09
Subsequent Event
Subsequent Event [Line Items]
Dividends declared per share (in USD per share)	$ 1.08
Subsequent Event \| Cash Distribution \| Common Units
Subsequent Event [Line Items]
Cash distributions, amount per common unit (in USD per share)	0.36
Subsequent Event \| Cash Distribution \| Common Class B
Subsequent Event [Line Items]
Cash distributions, amount per common unit (in USD per share)	$ 0.44