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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
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☒ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the Quarterly Period Ended June 30, 2023
OR
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☐ | 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)
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DE | | | 46-5001985 |
(State or Other Jurisdiction of Incorporation or Organization) | | | (I.R.S. Employer Identification Number) |
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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:
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| 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):
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Large Accelerated Filer | | ☒ | | Accelerated Filer | | ☐ |
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Non-Accelerated Filer | | ☐ | | Smaller Reporting Company | | ☐ |
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| | | | 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
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”):
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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. |
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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. |
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Condensate | Liquid hydrocarbons associated with the production of a primarily natural gas reserve. |
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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. |
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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. |
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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. |
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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. |
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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. |
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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. |
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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. |
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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:
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ASU | Accounting Standards Update. |
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Exchange Act | The Securities Exchange Act of 1934, as amended. |
GAAP | Accounting principles generally accepted in the United States. |
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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. |
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SEC | United States Securities and Exchange Commission. |
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SOFR | The secured overnight financing rate |
Notes | The 5.375% Senior Notes due 2027 issued on October 16, 2019. |
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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;
•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.
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 | |
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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 | |
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Derivative instruments | 3,373 | | | 7 | |
Total liabilities | 680,868 | | | 598,848 | |
Commitments and contingencies (Note 12) | | | |
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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.
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 | |
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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 | |
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Depletion | 34,064 | | | 31,962 | | | 65,051 | | | 59,373 | |
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General and administrative expenses | 2,008 | | | 1,880 | | | 4,772 | | | 3,833 | |
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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) | |
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Gain (loss) on derivative instruments, net | (12,594) | | | (1,889) | | | (27,697) | | | (20,248) | |
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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 | |
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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.
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 | |
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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) | | | — | |
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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 | |
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Unit-based compensation | — | | | 259 | | | — | | | — | | | — | | | — | | | 259 | |
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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) | | | — | |
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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 | |
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See accompanying notes to condensed consolidated financial statements.
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 | |
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Unit-based compensation | — | | | 284 | | | — | | | — | | | — | | | — | | | 284 | |
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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) | | | — | |
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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 | |
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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 | |
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See accompanying notes to condensed consolidated financial statements.
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 | |
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(Gain) loss on derivative instruments, net | 27,697 | | | 20,248 | |
Net cash receipts (payments) on derivatives | (6,212) | | | (17,029) | |
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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) | |
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Accounts payable and accrued liabilities | (2,583) | | | (5,580) | |
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Accounts payable—related party | (306) | | | — | |
Income tax payable | 673 | | | 2,288 | |
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Other | (4,370) | | | (513) | |
Net cash provided by (used in) operating activities | 252,669 | | | 299,020 | |
Cash flows from investing activities: | | | |
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Acquisitions of oil and natural gas interests—related party | (75,073) | | | — | |
Acquisitions of oil and natural gas interests | (48,609) | | | 1,862 | |
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Proceeds from sale of oil and natural gas interests | (1,975) | | | 29,336 | |
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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) | |
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Repayment of senior notes | — | | | (48,963) | |
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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 | |
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See accompanying notes to condensed consolidated financial statements.
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
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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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 | |
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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):
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| | | | | | | | |
| | | | | | | | |
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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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.
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| | | | | 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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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) | |
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| | | | | | | |
(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:
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| 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 | |
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
| | | | | | | | | | | | | | | | | | | | |
| 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.
Viper Energy Partners LP
Condensed Notes to Consolidated Financial Statements - (Continued)
(Unaudited)
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.
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.”
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.
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 | | | | | |
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.
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.
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 | |
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.
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.
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.
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.
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.
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.
Recent Accounting Pronouncements
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%.
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.
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.
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.
ITEM 6. EXHIBITS
| | | | | | | | |
Exhibit Number | | Description |
2.1 | | |
3.1 | | |
3.2 | | |
3.3 | | |
3.4 | | |
3.5 | | |
| | |
3.6 | | |
4.1 | | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
4.2 | | |
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* | | |
31.2* | | |
32.1** | | |
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. |
| |
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”).
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/ 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) |
| | | |
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v3.23.2
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
|
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v3.23.2
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
|
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- DefinitionThe sum of the capitalized costs incurred, as of the balance sheet date, of unproved properties excluded from amortization including acquisition costs, exploration costs, development costs, and production costs.
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v3.23.2
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
|
X |
- DefinitionThe noncash expense charged against earnings to recognize the consumption of oil and gas reserves that are part of an entities' assets.
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v3.23.2
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
|
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v3.23.2
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
|
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v3.23.2
ORGANIZATION AND BASIS OF PRESENTATION
|
6 Months Ended |
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.
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v3.23.2
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
|
6 Months Ended |
Jun. 30, 2023 |
Accounting Policies [Abstract] |
|
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES |
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Use of Estimates
Certain amounts included in or affecting the Partnership’s financial statements and related disclosures must be estimated by management, requiring certain assumptions to be made with respect to values or conditions that cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts the Partnership reports for assets and liabilities and the Partnership’s disclosure of contingent assets and liabilities 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.
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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v3.23.2
REVENUE FROM CONTRACTS WITH CUSTOMERS
|
6 Months Ended |
Jun. 30, 2023 |
Revenue from Contract with Customer [Abstract] |
|
REVENUE FROM CONTRACTS WITH CUSTOMERS |
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 | |
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v3.23.2
ACQUISITIONS AND DIVESTITURES
|
6 Months Ended |
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.
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v3.23.2
OIL AND NATURAL GAS INTERESTS
|
6 Months Ended |
Jun. 30, 2023 |
Extractive Industries [Abstract] |
|
OIL AND NATURAL GAS INTERESTS |
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.
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v3.23.2
DEBT
|
6 Months Ended |
Jun. 30, 2023 |
Debt Disclosure [Abstract] |
|
DEBT |
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
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.
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v3.23.2
UNITHOLDERS’ EQUITY AND DISTRIBUTIONS
|
6 Months Ended |
Jun. 30, 2023 |
Equity [Abstract] |
|
UNITHOLDERS’ EQUITY AND DISTRIBUTIONS |
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. 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 | |
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v3.23.2
EARNINGS PER COMMON UNIT
|
6 Months Ended |
Jun. 30, 2023 |
Earnings Per Share [Abstract] |
|
EARNINGS PER COMMON UNIT |
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. 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.
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- DefinitionThe entire disclosure for earnings per share.
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v3.23.2
INCOME TAXES
|
6 Months Ended |
Jun. 30, 2023 |
Income Tax Disclosure [Abstract] |
|
INCOME TAXES |
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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- DefinitionThe entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.
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v3.23.2
DERIVATIVES
|
6 Months Ended |
Jun. 30, 2023 |
Derivative Instruments and Hedging Activities Disclosure [Abstract] |
|
DERIVATIVES |
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. 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.
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v3.23.2
FAIR VALUE MEASUREMENTS
|
6 Months Ended |
Jun. 30, 2023 |
Fair Value Disclosures [Abstract] |
|
FAIR VALUE MEASUREMENTS |
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 | |
| | | | | | | | | | | | | | | | | | | | | | 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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- DefinitionThe entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.
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v3.23.2
COMMITMENTS AND CONTINGENCIES
|
6 Months Ended |
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.
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v3.23.2
SUBSEQUENT EVENTS
|
6 Months Ended |
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.
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v3.23.2
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)
|
6 Months Ended |
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.
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v3.23.2
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 | |
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v3.23.2
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 | |
|
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- DefinitionTabular disclosure of disaggregation of revenue into categories depicting how nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factor.
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v3.23.2
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 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
|
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- DefinitionTabular disclosure of aggregate capitalized costs relating to an enterprise's oil and gas producing activities and the aggregate related accumulated depreciation, depletion, amortization, and valuation allowances.
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v3.23.2
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 | |
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v3.23.2
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 | |
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v3.23.2
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 | |
(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.
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v3.23.2
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 | % |
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- DefinitionTabular disclosure of the reconciliation using percentage or dollar amounts of the reported amount of income tax expense attributable to continuing operations for the year to the amount of income tax expense that would result from applying domestic federal statutory tax rates to pretax income from continuing operations.
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v3.23.2
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 |
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.
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v3.23.2
FAIR VALUE MEASUREMENTS (Tables)
|
6 Months Ended |
Jun. 30, 2023 |
Fair Value Disclosures [Abstract] |
|
Fair Value Consolidated Balance Sheets |
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 | |
| | | | | | | | | | | | | | | | | | | | | | 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 |
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 | |
| | | | | | | | | | | | | | | | | | | | | | 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 |
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 | |
| | | | | | | | | | | | | | | | | | | | | | 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.
|
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v3.23.2
X |
- DefinitionPercentage investment held by the managing member or general partner of the limited liability company (LLC) or limited partnership (LP).
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v3.23.2
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
|
|
X |
- DefinitionAmount, after allowance for credit loss, of right to consideration from customer for product sold and service rendered in normal course of business, classified as current.
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v3.23.2
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
|
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v3.23.2
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
|
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v3.23.2
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
|
|
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v3.23.2
OIL AND NATURAL GAS INTERESTS (Details)
|
3 Months Ended |
6 Months Ended |
|
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
|
|
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v3.23.2
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
|
X |
- DefinitionAmount, before unamortized (discount) premium and debt issuance costs, of long-term debt. Includes, but is not limited to, notes payable, bonds payable, commercial loans, mortgage loans, convertible debt, subordinated debt and other types of debt.
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v3.23.2
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%
|
|
|
X |
- DefinitionThe carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement.
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v3.23.2
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
|
|
|
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v3.23.2
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
|
|
|
|
|
|
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|
|
|
|
|
|
|
Limited Partners' Capital Account [Line Items] |
|
|
|
|
|
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|
$ 48,983
|
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|
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v3.23.2
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
|
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v3.23.2
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
|
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v3.23.2
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- DefinitionLine items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.
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v3.23.2
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
|
X |
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v3.23.2
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
|
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v3.23.2
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 |
|
|
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413,097
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411,634
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Fair Value | Fair Value, Nonrecurring | Revolving credit facility |
|
|
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] |
|
|
Debt |
$ 224,000
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$ 152,000
|
X |
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Viper Energy (NASDAQ:VNOM)
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