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YoY shift: Neutral
Year-over-year tone shift - average net-tone change across Risk Factors and MD&A vs the prior 10-K. This filing is 0.02pp more bullish than last year's.
Why YoY instead of absolute: the LM lexicon has ~6.6× more negative words than positive (legal/risk-disclosure language is heavy on hedging), so every 10-K reads bearish on raw tone. Year-over-year change strips that bias and surfaces the actual shift in management's framing.
Tone shift by section
The two components the gauge averages: how Risk Factors and MD&A each shifted in net tone versus last year's 10-K. The headline above is their average, so a green needle over a soft section just means the other section carried it.
Risk Factors
-0.12pp
Flat
Net-tone change vs last year's 10-K.
MD&A
+0.16pp
Flat
Net-tone change vs last year's 10-K.
Per-snippet highlights
Sentence-level sentiment highlighting with category and subcategory filters is coming once the snippet-scoring pipeline lands. For now, dig into the actual section text on the Sections tab.
Language change vs prior 10-K
Risk Factors (Item 1A) - words with the biggest YoY frequency increase
Negative rising
closing+6
adversely+4
problems+2
delay+2
diversion+2
Positive rising
beneficially+2
benefit+2
advancements+2
able+1
successful+1
Risk Factors (Item 1A)
10,864 words
ITEM 1A. RISK FACTORS
The nature of our business activities subjects us to certain hazards and risks. The following is a summary of some of the material risks relating to our business activities. Other risks are also described in Items 1 and 2. Business and Properties , Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and Item 7A. Quantitative and Qualitative Disclosures About Market Risk of this report. These risks are not the only risks we face. We could also face additional risks and uncertainties not currently known to us or that we currently deem to be immaterial. If any of these risks actually occurs, it could materially harm our business, financial condition or results of operations and the trading price of our shares could decline.
Risks Related to Our Business
Market conditions for oil and natural gas, and particularly volatility in prices for oil and natural gas, have in the past adversely affected, and may in the future adversely affect, our revenue, cash flows, profitability, growth and production.
From the beginning of 2022 through the end of 2024, NYMEX WTI has ranged from $65.75 to $123.70 per Bbl, and the NYMEX Henry Hub price of natural gas has ranged from $1.58 to $9.68 per MMBtu, with seven-year highs reached in 2023. The war in Ukraine, the Israel-Hamas War, rising interest rates, global supply chain , about a potential economic or , recent measures to combat inflation, and actions taken by OPEC and its non-OPEC allies, collectively OPEC+, continued to contribute to economic and pricing . These factors and the of the energy markets make it extremely to predict future oil and natural gas price movements with any certainty. If the prices of oil and natural gas , our operations and financial condition may be materially and affected.
Language change vs prior 10-K
MD&A (Item 7) - words with the biggest YoY frequency increase
Negative rising
closing+5
loss+2
divestiture+2
divested+2
divestitures+1
Positive rising
gain+2
benefit+1
strong+1
successfully+1
profitability+1
MD&A (Item 7)
7,131 words
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion and analysis should be read in conjunction with our consolidated financial statements and notes thereto presented in Item 8. Financial Statements and Supplementary Data of this report. 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 discussed further in Item 1A. Risk Factors and Cautionary Statement Regarding Forward-Looking Statements of this report.
Overview
We are a publicly traded Delaware corporation focused on owning and acquiring mineral and royalty interests in oil and natural gas properties primarily in the Permian Basin. We operate in one reportable segment.
The following discussion includes a comparison of our results of operations, including changes in our operating income, and liquidity and capital resources for fiscal year 2024 and fiscal year 2023. A discussion of changes in our results of operations from fiscal year 2023 compared to fiscal year 2022 has been omitted from this report, but may be found in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10 -K for the fiscal year ended December 31, 2023 , filed with the SEC on February 22, 2024, and is incorporated by reference in this report from such prior Annual Report on Form 10-K.
Diamondback and certain of our other operators increased production on our acreage during 2024, but continued to exercise capital discipline by using the majority of their excess cash flow for debt repayment and/or return to their stockholders rather than expanding their drilling programs. We cannot reasonably predict whether production levels will remain at current levels or the impact the full extent of the events above may have on our industry and our business.
Based on the current commodity pricing environment and industry conditions, we did not record any impairments in 2024. However, if commodity prices fall below current levels, we may be required to record impairments in future periods and such impairments could be material. Further, if commodity prices decrease, our production, proved reserves and cash flows will be adversely impacted. Lower oil and natural gas prices may also result in a reduction in the borrowing base under the Operating Company’s revolving credit facility, which may be determined at the discretion of our lenders.
Other significant factors that are likely to continue to affect commodity prices in future periods include, but are not limited to, the effect of U.S. energy, monetary and trade policies, U.S. and global economic conditions, U.S. and global political and economic developments, including the new administration’s energy and environmental policies, all of which are beyond our control. Our business may be also adversely impacted by any future government rule, regulation or order that may impose production limits, as well as pipeline capacity and storage constraints, in the Permian Basin where we have mineral and royalty interests. We cannot predict the ultimate impact of these factors on our business, financial condition and cash available for dividends to our stockholders.
Our commodity price derivatives could result in financial losses, may fail to protect us from declines in commodity prices, prevent us from fully benefiting from commodity price increases and may expose us to other risks, including counterparty credit risk.
We use fixed price swap contracts, fixed price basis swap contracts and costless collar contracts with corresponding put and call options to reduce price volatility associated with certain of our royalty income. Our derivative contracts are based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on NYMEX WTI pricing (WTI Cushing and Argus WTI Midland) and with natural gas derivative settlements based on the NYMEX Henry Hub and Waha Hub pricing. By using derivative instruments to economically hedge exposure to changes in commodity prices, we expose ourselves to credit risk and market risk. At settlement, market prices for commodities may exceed the contract prices in our commodity price derivatives agreements, resulting in our need to make significant cash payments to our counterparties. Further, by using commodity derivative instruments, we expose ourselves to credit risk if we are in a positive position at contract settlement and the counterparty fails to perform under the terms of the derivative contract. Our counterparties have been determined to have an acceptable credit risk; therefore, we do not require collateral from our counterparties. By using derivative instruments, we may be prevented from fully realizing the benefits of increases in the prices of oil, natural gas liquids and natural gas above the price levels of the commodity price derivatives used to manage price risk.
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For additional information regarding our use of commodity price derivatives and our outstanding derivative contracts as of December 31, 2024, see Note 10— Derivatives in Item 8. Financial Statements and Supplementary Data, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and Item 7A. Quantitative and Qualitative Disclosures About Market Risk —Commodity Price Risk of this report.
The IRA and other risks relating to climate change could accelerate the transition to a low carbon economy and could impose new costs on our operations that may have a material and adverse effect on us.
Governmental and regulatory bodies, investors, consumers, industry and other stakeholders have been increasingly focused on climate change matters in recent years. This focus, together with changes in consumer and industrial/commercial behavior, preferences and attitudes with respect to the generation and consumption of energy, the use of hydrocarbons, and the use of products manufactured with, or powered by, hydrocarbons, may result in; (i) the enactment of climate change-related regulations, policies and initiatives by governments, investors, and other companies, including alternative energy or “zero carbon” requirements and fuel or energy conservation measures, (ii) technological advances with respect to the generation, transmission, storage and consumption of energy (including advances in wind, solar and hydrogen power, as well as battery technology), (iii) increased availability of, and increased demand from consumers and industry for, energy sources other than oil and natural gas (including wind, solar, nuclear, and geothermal sources as well as electric vehicles), and (iv) development of, and increased demand from consumers and industry for, lower-emission products and services (including electric vehicles and renewable residential and commercial power supplies) as well as more efficient products and services.
Any of these developments may reduce the demand for products manufactured with (or powered by) hydrocarbons and the demand for, and in turn the prices of, the oil and natural gas that we produce and sell, which would likely have a material adverse impact on us. The enactment of climate change-related regulations, policies and initiatives may also result in increases in our compliance costs and other operating costs and have other adverse effects, such as a greater potential for governmental investigations or litigation.
In recent years, federal, state and local governments have taken steps to reduce emissions of greenhouse gases. For example, the Infrastructure Investment and Jobs Act and the IRA include billions of dollars in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles, investments in advanced biofuels and supporting infrastructure and carbon capture and sequestration. Also, in March 2024, the EPA finalized ambitious rules to reduce harmful air pollutant emissions, including greenhouse gases, from light-, medium-, and heavy-duty vehicles beginning in model year 2027. These incentives and regulations could accelerate the transition of the economy away from the use of fossil fuels towards lower- or zero-carbon emissions alternatives, which could decrease demand for, and in turn the prices of, the oil and natural gas that we produce and sell and adversely impact our business. Additionally, the IRA imposes the first ever federal fee on greenhouse gas emissions through a methane emissions charge, which could increase our operating costs and thereby adversely impact our business, financial condition and cash flows. On January 20, 2025, President Trump signed multiple executive orders seeking to reverse these climate incentives, including pausing the disbursement of funds under the IRA. The same day, President Trump also issued executive orders to encourage fossil fuel production and exploration on federal lands and waters, while moving away from incentivizing renewable energy and electric vehicles. It is unclear what effect these actions will have.
In addition to potentially reducing (i) demand for our oil and natural gas and (ii) the availability of oilfield services and midstream and downstream customers, any further regulatory or other climate change initiatives, to the extent they continue, may create reputational risks associated with the exploration for, and production of, hydrocarbons, which may adversely affect the availability and cost to us of capital. For example, in recent years, certain stakeholders and capital providers sought to restrict or seek more stringent conditions with respect to their investment in or financing of certain carbon intensive sectors. If financial institutions and other investors refuse to invest in or provide capital to the oil and gas sector in the future because of these reputational risks, that could result in capital being unavailable to us, or only at a significantly increased cost.
For further discussion regarding the risks to us of climate change-related regulations, policies and initiatives, see Item 1 and 2. Business and Properties —Regulation—Climate Change of this report.
Changing political and social perspectives on climate change and other environmental, social and governance factors may create risks and uncertainties impacting our business.
In recent years, increased attention to global climate change resulted in increased investor attention and an increased risk of public and private litigation.
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Perspectives on environmental, social and governance (“ESG”) considerations continue to evolve, and we cannot currently predict how regulators’, investors’ and other stakeholders’ views on ESG matters may affect the regulatory and investment landscape and affect our business, financial condition, and results of operations. If we do not, or are perceived to not, adapt or comply with investor or stakeholder expectations and standards on ESG matters, we may suffer from reputational damage and our business, financial condition and results of operations could be materially and adversely affected.
The SEC published final rules on March 28, 2024 relating to the disclosure of a range of climate-related risks and other information. Several lawsuits have been filed challenging the rules. In April 2024, the SEC agreed to pause the rules to facilitate an orderly judicial resolution. To the extent the rules are implemented, we and/or our customers could incur increased costs related to the assessment and disclosure of climate-related information.
Additionally, cities, counties, and other governmental entities in several states in the U.S. have filed lawsuits against energy companies seeking damagesallegedly associated with climate change. Similar lawsuits may be filed in other jurisdictions. If any such lawsuits were to be filed against us, whether due to our activities or the activities of the acquired entities or operations prior to their acquisition by us, we could incur substantial legal defense costs and, if any such litigation were adversely determined, we could incur substantial damages. Any of these climate change-related litigation risks could result in unexpected costs, negative sentiments about our company, disruptions to our business, and increases to our operating expenses, which in turn could have an adverse effect on our business, financial condition and cash flow.
Conservation measures and technological advances could reduce demand for oil and natural gas.
Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to oil and natural gas, technological advances in fuel economy and energy generation devices could reduce demand for oil and natural gas. The impact of the changing demand for oil and natural gas services and products may have a material adverse effect on our business, financial condition, results of operations and cash available to return to our stockholders.
Increased costs of capital could adversely affect our business.
Our business could be harmed by factors such as the availability, terms and cost of capital, increases in interest rates or a reduction in our credit rating. Changes in any one or more of these factors could cause our cost of doing business to increase, limit our access to capital, limit our ability to pursue acquisition opportunities, reduce our cash flows available and place us at a competitive disadvantage. Continuing disruptions and volatility in the global financial markets may lead to an increase in interest rates or a contraction in credit availability impacting our ability to finance our activities. A significant reduction in the availability of credit could materially and adversely affect our ability to achieve our business strategy and cash flows.
We may not have sufficient available cash to pay any quarterly dividend on our Common Stock, our cash available for dividends may vary significantly from quarter to quarter and our board of directors may in the future modify or revoke our cash dividend policy at any time at its discretion. Our dividend policy could limit our ability to grow and make acquisitions.
We may not have sufficient cash available to pay base or variable dividends to our common stockholders each quarter. Furthermore, our cash dividend policy does not require us to pay dividends on a quarterly basis or otherwise. The amount of cash we have to distribute each quarter principally depends upon the amount of royalty income we generate, which is dependent upon the volumes of production sold and the prices that our operators realize from the sale of such production. In addition, the actual amount of cash we will have to distribute each quarter under our cash dividend policy will be reduced by payments in respect of income taxes, debt service and other contractual obligations and fixed charges, increases in reserves for future operating or capital needs that the board of directors may determine is appropriate, lease bonus income, distribution equivalent rights payments and preferred dividends, if any, and any common share repurchases. The board of directors may further modify or revoke our dividend policy at any time in the future at its discretion. During 2022, the board of directors approved a dividend policy, effective beginning with the Company’s dividend payable for the third quarter of 2022, consisting of a base and variable dividend, that takes into account capital returned to stockholders via our Common Stock repurchase program. For information regarding our dividend policy and the recent modifications, see Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securitie s —Cash Dividend Policy and Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of this report. As a result, quarterly dividends paid to our stockholders may vary significantly from quarter to quarter and may be zero.
As a result of our cash dividend policy, we will have limited cash available to reinvest in our business or to fund acquisitions, and we will rely primarily upon external financing sources, including commercial bank borrowings and the issuance of debt and equity securities, to fund our acquisitions and growth capital expenditures. As such, to the extent we are unable to finance growth externally, our dividend policy will significantly impair our ability to grow.
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To the extent we issue additional shares in connection with any acquisitions or growth capital expenditures or as in-kind dividends, the payment of dividends on those additional shares may increase the risk that we will be unable to maintain or increase our per share dividend level.
We depend on a small number of operators for a substantial portion of the development and production on our mineral and royalty acreage. A reduction in the expected number of wells to be drilled on our acreage by these operators or the failure of an operator to adequately and efficiently develop and operate our acreage could have an adverse effect on our expected growth and our results of operations.
The failure of our operators to adequately or efficiently perform operations or an operator’s failure to act in ways that are in our best interests could reduce production and revenues . Any development and production activities on our properties are subject to our operators’ reasonable discretion. The level, success and timing of drilling and development activities on our properties, and whether the operators elect to drill any additional wells on our acreage, depends on a number of factors that will be largely outside of our control, including: commodity prices; the timing and amount of capital expenditures by our operators, which could be significantly more than anticipated; the ability of our operators to access capital; the availability, high cost or shortages of rigs and other suitable drilling equipment, raw materials, supplies and oilfield services; the availability of production and transportation infrastructure and qualified operating personnel; regulatory restrictions; the operators’ expertise, operating efficiency and financial resources; approval of other participants in drilling wells; the operators’ expected return on investment in wells drilled on our acreage as compared to opportunities in other areas; the selection of technology; the selection of counterparties for the sale of production; and the rate of production of the reserves.
The operators may elect not to undertake development activities, or may undertake such activities in an unanticipated fashion, which may result in significant fluctuations in our royalty income and cash available for dividends to our stockholders. If reductions in production by the operators are implemented on our properties and sustained, our revenues may also be substantially affected. Additionally, if an operator were to experience financial difficulty, the operator might not be able to pay its royalty payments or continue its operations, which could have a material adverse impact on us.
The development of our proved undeveloped reserves may take longer and may require higher levels of capital expenditures by operators than we currently anticipate.
Approximately 16% of our total estimated proved reserves as of December 31, 2024 were proved undeveloped reserves and may not be ultimately developed or produced. Recovery of proved undeveloped reserves requires significant capital expenditures and successful drilling operations by the operators on our mineral and royalty acreage. The reserve data included in the reserve reports of our independent petroleum engineers assumes that substantial capital expenditures are required to develop such reserves. We cannot be certain that the estimated costs of the development of these reserves are accurate, that development will occur as scheduled or that the results of such development will be as estimated. Delays in the development of our reserves, increases in costs to drill, complete and develop such reserves, or further decreases in commodity prices will reduce the future net revenues of our estimated proved undeveloped reserves and may result in some projects becoming uneconomical. In addition, delays in the development of reserves could force us to reclassify certain of our proved reserves as unproved reserves.
We may not be able to terminate our leases if any of our operators declare bankruptcy, and we may experience delays and be unable to replace operators that do not make royalty payments.
Generally, a failure on the part of our operators to make royalty payments to us gives us the right to terminate the applicable lease, repossess the property and enforce payment obligations under the lease. If we repossessed any of our properties, we would seek a replacement operator. However, we might not be able to find a replacement operator and, if we did, we might not be able to enter into a new lease on favorable terms within a reasonable period of time. In addition, the outgoing operator could be subject to bankruptcy proceedings that could prevent the execution of a new lease or the assignment of the existing lease to another operator. In addition, if we enter into a new lease, the replacement operator may not achieve the same levels of production or sell oil or natural gas at the same price as the operator it replaced.
The producing properties in which we have mineral and royalty interests are primarily concentrated in the Permian Basin of West Texas, making us vulnerable to risks (including weather-related risks) associated with a single geographic area. In addition, a large amount of our proved reserves is attributable to a small number of producing horizons within this area.
The producing properties in which we have mineral and royalty interests are currently geographically primarily concentrated in the Permian Basin of West Texas. As a result of this concentration, we may be disproportionatelyexposed to
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the impact of regional supply and demand factors, delays or interruptions of production from wells in this area caused by governmental regulation, processing or transportation capacity constraints faced by our operators or their customers, availability of equipment, facilities, personnel or services market limitations or interruption of the processing or transportation of crude oil, natural gas or natural gas liquids on our mineral and royalty acreage, and extreme weather conditions and their adverse impact on production volumes, availability of electrical power, road accessibility and transportation facilities on our mineral and royalty acreage.
Extreme regional weather events may occur that can affect our operators’ suppliers or customers, which could adversely affect us. For example, a significant hurricane or similar weather event could damage refining and other oil and natural gas-related facilities on the Gulf Coast of Texas and Louisiana, which (if significant enough) could limit the availability of gathering and transportation facilities across Texas and could then cause production in the Permian Basin (potentially including production on our mineral and royalty acreage) to be curtailed or shut in or (in the case of natural gas) flared. Climate changes may also increase the frequency and severity of significant weather events over time. Further, any increase in flaring of natural gas production on our mineral and royalty acreage due to weather-related events, or otherwise, could expose us to reputational risks and adversely impact our or our operators’ contractual and other business relationships. Any of the above-referenced events could have a material adverse effect on us. Likewise, a weather event could reduce the availability of electrical power, road accessibility, and transportation facilities, which could have an adverse impact on production volumes on our mineral and royalty acreage (and therefore on our financial condition and results of operations).
In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic oil and natural gas producing areas such as the Permian Basin, which may cause these conditions to occur with greater frequency or magnify the effects of these conditions. Due to the concentrated nature of our mineral and royalty acreage, we could experience any of these conditions at the same time, resulting in a relatively greater impact on us than they might have on other companies that have a more diversified portfolio of assets. Such delays or interruptions could have a material adverse effect on our business, financial condition and cash flow.
In addition to the geographic concentration of our mineral and royalty acreage, as of December 31, 2024, most of our proved reserves are concentrated in the Wolfberry resource play in the Midland Basin. This concentration of assets within a small number of producing horizons exposes us to additional risks, such as changes in field-wide rules and regulations that could cause our operators to permanently or temporarily shut-in all of the wells on our mineral and royalty acreage.
Our future success depends on the development or acquisition of additional reserves, and our failure to successfully identify, complete and integrate acquisitions of properties or businesses could slow our growth and adversely affect our results of operations and cash available for dividends.
Our future success depends upon the development or acquisition of additional oil and natural gas reserves that are economically recoverable, as our proved reserves will generally decline as reserves are depleted. To increase reserves and production, we would need to undertake replacement activities or use third-party operators to undertake development, exploration and other replacement activities, requiring substantial capital expenditures. Neither we nor our third-party operators may have sufficient resources to acquire additional reserves or to undertake exploration, development, production or other replacement activities. Such activities by our third-party operators may not result in significant additional reserves and efforts to drill productive wells at low finding costs may be unsuccessful. In addition, we do not expect to retain cash from our operations for replacement capital expenditures. Furthermore, although our revenues and cash available for dividends may increase if prevailing oil and natural gas prices increase significantly, finding costs for additional reserves could also increase.
There is intense competition for acquisition opportunities in our industry. The successful acquisition of producing properties requires an assessment of several factors, including; recoverable reserves, future oil and natural gas prices and their applicable differentials, operating costs and potential environmental and other liabilities. The accuracy of these assessments is inherently uncertain and we may not be able to identify attractive acquisition opportunities. In connection with these assessments, we perform a review of the subject properties that we believe to be generally consistent with industry practices. Our review will not reveal all existing or potential problems including title defects or environmental issues, which, if material, can render an interest worthless, nor will it permit us to become sufficiently familiar with the properties to assess fully their deficiencies and capabilities. Inspections may not always be performed on every well, and environmental problems, such as groundwater contamination, are not necessarily observable even when an inspection is undertaken. Environmental or other regulatory issues may arise with respect to acquired entities or operations years after the acquisitions, any of which can adversely affect our results of operations, financial condition and cash available for dividends. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or part of the problems. Significant acquisitions and other strategic transactions may involve other risks that may cause our business to be adversely impacted, including diversion of our management’s attention to evaluating and negotiating such transactions and our failure to
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realize the full benefit that we expect in estimated proved reserves, production volume or other benefits anticipated therefrom, or to realize these benefits within the expected time frame.
We may not be able to complete acquisitions or do so on commercially acceptable terms, as our ability to complete acquisitions is dependent upon, among other things, our ability to obtain debt and equity financing and, in some cases, regulatory approvals. Further, our future acquisitions may be in geographic regions in which we do not currently hold properties. If we enter into new geographic markets, we may be subject to additional and unfamiliar legal and regulatory requirements and other unforeseendifficulties. Compliance with regulatory requirements may impose substantial additional obligations on us and our management, cause us to expend additional time and resources in compliance activities and increase our exposure to penalties or fines for non-compliance with such additional legal requirements. Further, the success of any completed acquisition will depend on our ability to effectively integrate the acquired business into our existing operations, the process of which may involve unforeseendifficulties and may require a disproportionate amount of our managerial and financial resources. In addition, possible future acquisitions may be larger and for purchase prices significantly higher than those paid for earlier acquisitions. Any of the unfavorable circumstances mentioned above could have a material adverse effect on our financial condition, results of operations and cash available for dividends. The inability to effectively manage the integration of acquisitions could reduce our focus on subsequent acquisitions and current operations, which, in turn, could negatively impact our growth, results of operations and cash available for dividends. See also “Risks Related to the Pending 2025 Drop Down” below for a description of risk factors specific to that transaction.
Project areas on our properties, which are in various stages of development, may not yield oil or natural gas in commercially viable quantities.
Project areas on our properties are in various stages of development, ranging from project areas with current drilling or production activity to project areas that have limited drilling or production history. If the wells in the process of being completed are on our property and do not produce sufficient revenues or if dry holes are drilled, our financial condition, results of operations and cash available for dividends may be materially affected.
Our estimated reserves are based on many assumptions that may turn out to be inaccurate. Any material inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves.
Oil and natural gas reserve engineering is not an exact science and requires subjective estimates of underground accumulations of oil and natural gas and assumptions concerning future oil and natural gas prices, production levels, ultimate recoveries and operating and development costs, if any. As a result, estimated quantities of proved reserves, projections of future production rates and the timing of development expenditures may be incorrect. Over time, we may make material changes to reserve estimates taking into account the results of actual drilling, testing and production. Also, certain assumptions regarding future oil and natural gas prices, production levels and operating and development costs, if any, may prove incorrect. Any significant variance from these assumptions to actual figures could greatly affect our estimates of reserves, the economically recoverable quantities of oil and natural gas attributable to any particular group of properties, the classifications of reserves based on risk of recovery and estimates of future net cash flows. A substantial portion of our reserve estimates are made without the benefit of a lengthy production history, which are less reliable than estimates based on a lengthy production history. Numerous changes over time to the assumptions on which our reserve estimates are based, as described above, often result in the actual quantities of oil and natural gas that we ultimately recover being different from our reserve estimates. Reserve estimates do not include any value for probable or possible reserves that may exist, nor do they include any value for unproved undeveloped acreage.
We are dependent on electrical power, internet and telecommunication infrastructure and information and computer systems. If any of these systems are compromised or unavailable, our business could be adversely affected.
We are dependent on electric power, internet and telecommunication infrastructure and Diamondback’s information systems and computer based programs. If any of such infrastructure, systems or programs were to fail or become unavailable or compromised, or create erroneous information in our hardware or software network infrastructure, our ability to safely and effectively conduct our business will be limited and any such consequence could have a material adverse effect on our business.
We are subject to cybersecurity risks. A cyber incident could occur and result in information theft, data corruption, operational disruption and/or financial loss.
We rely extensively on Diamondback’s information technology systems, including internally developed software, data hosting platforms, real-time data acquisition systems, third-party software, cloud services and other internally or externally
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hosted hardware and software platforms, to (i) estimate our oil and natural gas reserves, (ii) process and record financial and operating data, and (iii) communicate with our management and board of directors, as well as, our vendors, suppliers and other third parties. Further, our reliance on technology has increased due to the increased use of personal devices, remote communications and work-from-home or hybrid work practices.
Risks from cybersecurity threats have not materially affected, and are not currently anticipated to materially affect, our company, including our business strategy, results of operations and financial condition. However, our systems and networks (which are provided by Diamondback), and those of its vendors, service providers and other third-party providers, may become the target of cybersecurity attacks, including, without limitation, denial-of-service attacks; malicious software; data privacy breaches by insiders or others with authorized access; cyber or phishing-attacks; ransomware; attempts to gainunauthorized access to our data and Diamondback’s systems; and other electronic security breaches. Security incidents can also occur as a result of non-technical issues, such as physical theft. More recently, advancements in artificial intelligence (“AI”) may pose serious risks for many of the traditional tools used to identify individuals, including voice recognition (whether by machine or the human ear), facial recognition or screening questions to confirm identities. In addition, generative AI systems may also be used by malicious actors to create more sophisticated cyber-attacks (i.e., more realistic phishing or other attacks). The advancements in AI could lead to an increase in the frequency of identity fraud or cyberattacks (whether successful or unsuccessful), which could cause us or our providers to incur increasing costs, including costs associated with additional personnel, protection technologies and policies and procedures and third-party experts and consultants. If any of these security breaches were to occur, we could sufferdisruptions to our operations, normal business functions and other aspects of our business.
Diamondback provides personnel and general and administrative services to us, including personnel and infrastructure that underlie our cybersecurity risk management program. In connection therewith, Diamondback has implemented and invested in, and will continue to implement and invest in, controls, procedures and protections (including internal and external personnel), and has implemented a cybersecurity governance program, that are designed, in each case, to protect its systems; identify and remediate, on a regular basis, vulnerabilities in its systems and related infrastructure and monitor and mitigate the risk of data loss and other cybersecurity threats. Diamondback has also engaged third-party consultants to conduct penetration testing and risk assessments. Such measures, however, cannot entirely eliminate cybersecurity threats and may prove to be ineffective. As cyber incidents continue to evolve, Diamondback may be required to expend additional resources (for which we may be partially responsible) to continue to modify or enhance protective measures or to investigate and remediate any vulnerability to cyber incidents. Diamondback maintains specialized insurance for possible liability resulting from a cyberattack on its assets, however, we cannot assure you that the insurance coverage will be adequate to cover claims that may arise, or that Diamondback will be able to maintain adequate insurance at rates we consider reasonable. A loss not fully covered by insurance could have a material adverse effect on our business, financial condition and cash flows. See “ Item 1C—Cybersecurity ” below for additional information.
Evolving privacy-related laws could give rise to liabilities, which could adversely impact our business, results of operations or financial condition.
A variety of U.S. federal, state and international laws and regulations govern the collection, use, retention, sharing and security of personal data. All 50 states have enacted legislation on data breach notification requirements and many states continue to enact laws on matters of privacy, data protection and cybersecurity. The existing privacy-related laws and regulations are evolving and subject to potentially differing interpretations. In addition, various U.S. federal, state and foreign legislative and regulatory bodies continue to enact new laws regarding privacy and data protection, as well as expand the scope of existing laws. For example, Texas recently passed the Texas Data Privacy and Security Act, which establishes new laws for collecting, storing, processing, and selling consumer information. Several other states, such as California, Utah, Colorado, Virginia, Connecticut, Michigan, Ohio, Pennsylvania, and New Jersey, among others, have proposed or passed legislation regarding data privacy and use. We cannot predict the impact of any such evolving privacy-related laws on our business, results of operations or financial condition, but may find it necessary to enhance the existing systems and procedures, which may involve substantial expense or distraction from other aspects of our business. In addition, any violations of applicable privacy-related laws or regulations may require us to address legal claims, sustain monetary penalties or incur other liabilities, as well as cause reputational damage, any of which could adversely impact our business, results of operations or financial condition.
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Risks Related to Our Indebtedness
Implementing our capital programs may, under certain circumstances, require an increase in our total leverage through additional debt issuances. In addition, a significant reduction in availability under the revolving credit facility and the inability to otherwise obtain financing for our capital programs could require us to curtail our capital expenditures.
As a result of our cash dividend policy, we have limited cash available to reinvest in our business or to fund acquisitions and have historically relied on availability under the Operating Company’s revolving credit facility to fund a portion of our capital expenditures and for other purposes. We expect that we will continue to fund a portion of our capital expenditures and other needs with borrowings under the revolving credit facility and from the proceeds of debt and equity offerings. In the past, we have created availability under the revolving credit facility by repaying outstanding borrowings with the proceeds from equity and debt offerings. We cannot assure you that we will choose to or be able to access the capital markets to repay any such future borrowings. If the availability under the revolving credit facility were reduced, and we were otherwise unable to secure other sources of financing, we may be required to curtail our capital expenditures, which could result in an inability to complete acquisitions or finance the capital expenditures necessary to replace our reserves.
Restrictive covenants in the Operating Company’s revolving credit facility, the indentures governing the Notes and future debt instruments may limit our ability to respond to changes in market conditions or pursue business opportunities.
The Operating Company’s revolving credit facility and the indentures governing the Notes outstanding contain, and the terms of any future indebtedness may contain, restrictive covenants that limit our and the Operating Company’s ability to, among other things: incur or guarantee additional indebtedness; make certain investments; create additional liens; sell or transfer assets; lease property as a lessee; issue redeemable or preferred equity; voluntarily redeem or prepay debt (including the Notes); merge or consolidate with another entity; pay or declare dividends; designate certain of our subsidiaries as unrestricted subsidiaries; create unrestricted subsidiaries; engage in transactions with affiliates; enter into gas imbalances, take-or-pay and similar agreements; and enter into certain swap agreemen ts.
We may be prevented from taking advantage of business opportunities that arise because of the limitations imposed on us and the Operating Company by the restrictive covenants contained in the revolving credit facility and the indentures that govern the Notes. In addition, the revolving credit facility requires us to maintain certain financial ratios and tests. The requirement that we comply with these provisions may materially adversely affect our ability to react to changes in market conditions, take advantage of business opportunities we believe to be desirable, obtain future financing, fund needed capital expenditures or withstand a continuing or future downturn in our business.
Our and the Operating Company’s future ability to comply with these restrictions and covenants is uncertain and will be affected by the levels of cash flow from our operations and other events or circumstances beyond our control. If market or other economic conditions deteriorate, our ability to comply with these covenants may be impaired. A breach of any of these restrictive covenants could result in default under the revolving credit facility. If a default occurs, the lenders under the revolving credit facility may elect to declare all borrowings outstanding, together with accrued interest and other fees, to be immediately due and payable, which would result in an event of default under the indentures governing the Notes. The lenders will also have the right in these circumstances to terminate any commitments they have to provide further borrowings. If we and the Operating Company are unable to repay outstanding borrowings when due, the lenders under the revolving credit facility will also have the right to proceed against the collateral granted to them to secure the indebtedness. If the indebtedness under the revolving credit facility and the Notes were to be accelerated, we cannot assure you that our assets would be sufficient to repay in full that indebtedness.
Any significant reduction in the borrowing base under the Operating Company’s revolving credit facility as a result of the periodic borrowing base redeterminations, or otherwise, may negatively impact our ability to fund our operations, and we may not have sufficient funds to repay borrowings under the revolving credit facility if required as a result of a borrowing base redetermination.
A decline in commodity prices could result in a redetermination that lowers the borrowing base. Any significant reduction in the borrowing base as a result of such borrowing base redeterminations or otherwise may negatively impact our liquidity and our ability to fund our operations and, as a result, may have a material adverse effect on our financial position, results of operation and cash flow. Further, if the outstanding borrowings under the revolving credit facility were to exceed the borrowing base as a result of any such redetermination, we and the Operating Company would be required to repay the excess. We may not have sufficient funds to make such repayments. If we do not have sufficient funds and we are otherwise unable to negotiate renewals of the borrowings or arrange new financing, we may have to sell significant assets. Any such sale could have a material adverse effect on our business and financial results.
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Servicing our indebtedness requires a significant amount of cash, and we may not have sufficient cash flow from our business to pay our substantial indebtedness.
Our ability to make scheduled payments of the principal, to pay interest on or to refinance our indebtedness depends on our future performance, which is subject to economic, financial, competitive and other factors beyond our control. We are dependent on cash flow generated by the Operating Company to repay the Notes. The Operating Company’s business may not generate cash flow from operations in the future sufficient to service our debt and make necessary capital expenditures. If the Operating Company is unable to generate such cash flow, we may be required to adopt one or more alternatives, such as reducing or delaying capital expenditures, selling assets, restructuring debt or obtaining additional capital on terms that may be onerous or highly dilutive. However, we cannot assure you that undertaking alternative financing plans, if necessary, would allow us to meet our debt obligations. In the absence of such cash flows, we could have substantial liquidity problems and might be required to sell material assets to attempt to meet our debt service and other obligations. The Operating Company’s revolving credit facility and the indentures governing the Notes outstanding restrict our ability to use the proceeds from asset sales. We may not be able to consummate those asset sales to raise capital or sell assets at prices that we believe are fair, and proceeds that we do receive may not be adequate to meet any debt service obligations then due. Our ability to refinance our indebtedness will depend on the capital markets and our financial condition at the time. We may not be able to engage in any of these activities or engage in these activities on desirable terms, which could result in a default on our debt obligations and have an adverse effect on our financial condition.
If we experience liquidity concerns, we could face a downgrade in our debt ratings which could restrict our access to, and negatively impact the terms of, current or future financings or trade credit.
Our ability to obtain financings and trade credit and the terms of any financings or trade credit is, in part, dependent on the credit ratings assigned to our debt by independent credit rating agencies. We cannot provide assurance that any of our current ratings will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a rating agency if, in its judgment, circumstances so warrant. Factors that may impact our credit ratings include debt levels, planned asset purchases or sales and near-term and long-term production growth opportunities, liquidity, asset quality, cost structure, product mix and commodity pricing levels. A ratings downgrade could adversely impact our ability to access financings or trade credit and increase our or the Operating Company’s borrowing costs.
The borrowings under the Operating Company’s revolving credit facility expose us to interest rate risk.
Our earnings are exposed to interest rate risk associated with borrowings under the Operating Company’s revolving credit facility. The terms of the Operating Company’s revolving credit facility provide for interest on borrowings at a floating rate equal to an alternative base rate that, since November 2022 has been tied to SOFR. SOFR tends to fluctuate based on multiple factors, including general short-term interest rates, rates set by the U.S. Federal Reserve, and other central banks and general economic conditions. We have not hedged our interest rate exposure with respect to our floating rate debt. The Operating Company’s weighted average interest rate on borrowings under its revolving credit facility was 7.34% during the year ended December 31, 2024. If interest rates increase, so will our interest costs, which may have a material adverse effect on our results of operations and financial condition.
Risks Inherent in an Investment in Us
Diamondback controls us and its interests may conflict with ours or yours in the future.
As of the date of this Annual Report on Form 10-K, Diamondback beneficially owned approximately 39% of the outstanding voting power of our capital stock, and we currently estimate that following the closing of the Pending 2025 Drop Down, Diamondback will beneficially own approximately 52% of our outstanding Common Stock, on a fully diluted basis. For so long as Diamondback continues to have voting power over a significant percentage of our capital stock, even at times when such amount is less than 50%, it will be able to significantly influence the composition of our board of directors and the approval of actions requiring stockholder approval. Although the holders of our Common Stock are entitled to vote on all matters on which stockholders of a corporation are generally entitled to vote on under the Delaware General Corporation Law (the “DGCL”), including the election of our board of directors, pursuant to our certificate of incorporation, for so long as Diamondback and any of its subsidiaries collectively beneficially own at least 25% of our outstanding Common Stock (i) Diamondback has the right to designate up to three persons to serve as members of our board of directors, and (ii) our board of directors may not appoint any person other than a Diamondback seconded employee as an executive officer of our company unless such appointment is approved, in advance, by either (x) Diamondback (which approval may not be unreasonably
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withheld or conditioned), or (y) the affirmative vote of the holders of at least 80% of the voting power of our capital stock. Currently, there are two Diamondback designees to our board of directors—Travis Stice and Kaes Van’t Hof. Further, in connection with the Conversion, we entered into the services and secondment agreement with Diamondback E&P LLC and OpCo, pursuant to which Diamondback continues to provide personnel and general and administrative services to us and OpCo, including the services of the executive officers and other employees, in a similar manner as Diamondback provided to us before the Conversion. Accordingly, Diamondback will have significant influence with respect to our board of directors, management, business plans and policies, including the appointment and removal of our officers. In particular, for so long as Diamondback continues to beneficially own a significant percentage of our capital stock, it will be able to cause or prevent a change of control of our company or a change in the composition of our board of directors and could preclude any unsolicited acquisition of our company. The concentration of ownership could deprive you of an opportunity to receive a premium for your shares of Common Stock as part of a sale of our company and ultimately might affect the market price of our Common Stock.
We do not have any employees, and we rely solely on the employees of Diamondback to manage our business. The management team of Diamondback, which includes the individuals who manage us, also perform similar services for Diamondback and certain of its affiliates, and thus are not solely focused on our business.
We do not have any employees and we rely solely on Diamondback to provide us with personnel and general and administrative services, including the services of the executive officers, senior management and other employees, under the terms and conditions of the services and secondment agreement discussed above. Because Diamondback provides services to us that are similar to those it performs for itself and its affiliates, it may not have sufficient human, technical and other resources to provide those services at a level that it would be able to provide to us if it were solely focused on our business and operations. Diamondback may make internal decisions on how to allocate its available resources and expertise that may not always be in our best interest compared to Diamondback’s interests. There is no requirement that Diamondback favor us over itself or others in providing its services. If Diamondback does not devote sufficient attention to the management and operation of our business or otherwise breaches the provisions of the services and secondment agreement, our financial results may suffer and our ability to pay dividends to our stockholders may be reduced. Many key responsibilities within our business have been assigned to a small number of individuals. The loss of their services could adversely affect our business. In particular, the loss of the services of one or more members of the executive team could disrupt our business. Further, we do not maintain “key person” life insurance policies on any of our executive team or other key personnel. As a result, we are not insured against any losses resulting from the death of these key individuals.
State and local income and other tax reimbursements due to Diamondback for our share of state and local and other taxes borne by Diamondback will reduce cash available for dividends to our common stockholders.
We have entered into a tax sharing agreement with Diamondback pursuant to which we are required to reimburse Diamondback for our share of state and local income and other taxes borne by Diamondback as a result of our results being included in a combined or consolidated tax return filed by Diamondback. The reimbursement of our share of state and local income and other taxes borne by Diamondback will reduce the amount of cash available for dividends from us to our common stockholders.
The market price of our shares of Class A Common Stock could be adversely affected by sales of substantial amounts of our Class A Common Stock in the public or private markets.
Sales by holders of a substantial number of our Class A Common Stock in the public markets, or the perception that such sales might occur, could have a material adverse effect on the price of our Class A Common Stock or could impair our ability to obtain capital through an offering of equity securities. In addition, we have provided registration rights to Diamondback and other parties. Pursuant to these registration rights, we have registered, under the Securities Act, all of the Class A Common Stock owned by Diamondback and those other parties for resale (including Class A Common Stock issuable in respect of the Class B Common Stock under the related exchange agreement).
U.S. tax legislation may adversely affect our business, results of operations, financial condition and cash flow.
From time to time, legislation has been proposed that, if enacted into law, would make significant changes to U.S. federal and state income tax laws affecting the oil and natural gas industry, including (i) eliminating the immediate deduction for intangible drilling and development costs, (ii) the repeal of the percentage depletion allowance for oil and natural gas properties, and (iii) an extension of the amortization period for certain geological and geophysical expenditures. No accurate prediction can be made as to whether any such legislative changes will be proposed or enacted in the future or, if enacted, what the specific provisions or the effective date of any such legislation would be. These proposed changes in the U.S. tax law, if adopted, or other similar changes that would impose additional tax on our activities or reduce or eliminate deductions currently
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available with respect to natural gas and oil exploration, development or similar activities, could adversely affect our business, results of operations, financial condition and cash flow.
On August 16, 2022, President Biden signed into law the IRA, which, among other changes, imposes a 15% corporate alternative minimum tax (“CAMT”) on the “adjusted financial statement income” of certain large corporations (generally, corporations reporting more than $1 billion average adjusted pre-tax net income on their consolidated financial statements) for tax years beginning after December 31, 2022. If we are or become subject to CAMT including as a result of our affiliation with Diamondback, our cash tax obligations for U.S. federal income taxes could be significantly accelerated.
The IRA also imposes an excise tax of 1% on the fair market value of certain public company stock repurchases occurring on or after January 1, 2023. The excise tax is imposed on the repurchasing corporation, and the amount of the excise tax is generally 1% of the aggregate fair market value of the stock repurchased during the taxable year. However, for purposes of calculating the excise tax, repurchasing corporations are permitted to net the fair market value of certain new stock issuances against the fair market value of stock repurchases during the same taxable year. To the extent the 1% excise tax applies to repurchases of shares under our common stock repurchase program, the number of shares we repurchase and our cash flow may be affected.
The U.S. Treasury Department, the Internal Revenue Service and other standard-setting bodies are expected to issue additional guidance on how CAMT, stock buyback excise tax and other provisions of the IRA will be applied or otherwise administered that may differ from our interpretations. We continue to evaluate the IRA and its effect on our financial results and operating cash flow.
The provision of our certificate of incorporation requiring exclusive venue in the Court of Chancery in the State of Delaware for certain types of lawsuits may have the effect of discouraging lawsuits against us and our directors, officers and stockholders.
Our certificate of incorporation requires, to the fullest extent permitted by law, that any claim, demand, action, suit or proceeding, whether civil, criminal, administrative or investigative, and whether formal or informal, and including appeals, arising out of or relating in any way to our certificate of incorporation or any of our stock may only be brought in the Court of Chancery of the State of Delaware or, if such court does not have subject matter jurisdiction thereof, any other court in the State of Delaware with subject matter jurisdiction. This provision may have the effect of discouraging lawsuits against us and our directors, officers and stockholders.
Our certificate of incorporation does not limit the ability of Diamondback and certain of its directors, principals, officers, employees and their respective affiliates to compete with us.
Our certificate of incorporation provides that none of Diamondback, any of its directors, principals, officers, employees or respective affiliates will have any duty to refrain from engaging, directly or indirectly, in the same business activities or similar business activities or lines of business in which we operate. In the ordinary course of their business activities, these persons may engage in activities where their interests conflict with our interests or those of our other stockholders.
These persons also may pursue acquisition opportunities that may be complementary to our business, and, as a result, those acquisition opportunities may not be available to the Company. In addition, these persons may have an interest in our pursuing acquisitions, divestitures and other transactions that, in their judgment, could enhance their investment, even though such transactions might involve risks to our common stockholders.
Anti-takeover provisions in our organizational documents and Delaware law might discourage or delay acquisition attempts for us that you might consider favorable.
Our certificate of incorporation and bylaws contain provisions that may make the merger or acquisition of our company more difficult without the approval of our board of directors. Among other things, these provisions would allow us to authorize the issuance of shares of one or more series of preferred stock, including in connection with a stockholder rights plan, financing transactions or otherwise, the terms of which series may be established and the shares of which may be issued without stockholder approval, and which may include super voting, special approval, dividend, or other rights or preferences superior to the rights of the holders of Common Stock; prohibit stockholder action by written consent unless such action is consented to by the board of directors; provide for certain limitations on convening special stockholder meetings; provide (i) that the board of directors is expressly authorized to make, alter, or repeal our bylaws, and (ii) that our stockholders may only amend our bylaws with the approval of at least a majority of all of the outstanding shares of our capital stock entitled to vote; and establish
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advance notice requirements for nominations for elections to our board or for proposing matters that can be acted upon by stockholders at stockholder meetings.
Further, as a Delaware corporation, we are also subject to provisions of Delaware law which may impede or discourage a takeover attempt that our stockholders may find beneficial. These anti-takeover provisions and other provisions under Delaware law could discourage, delay or prevent a transaction involving a change in control of our company, including actions that our stockholders may deem advantageous, or could negatively affect the trading price of our Common Stock. These provisions could also discourage proxy contests and make it more difficult for you and other stockholders to elect directors of your choosing and to cause us to take other corporate actions you desire.
Our ability to pay base and variable dividends to the holders of our Class A Common Stock or make share repurchases under our repurchase program may be limited by requirements under our certificate of incorporation, our holding company structure, applicable provisions of Delaware law and contractual restrictions or obligations.
Under our current dividend policy, we pay quarterly base plus variable cash dividends on our Class A Common Stock. The outstanding shares of Class B Common Stock are entitled to an aggregate quarterly preferred dividend of $20,000 in cash. Other than the insignificant preferred dividend requirement, we are not required to pay dividends to our stockholders on a quarterly or other basis, and declaration of any other dividends in the future will be solely in the discretion of our board of directors, which may change our dividend policy at any time. Our ability to pay cash dividends to holders of our Class A Common Stock depends on a number of factors, including among other things, general economic and business conditions, our strategic plans and prospects, our businesses and investment opportunities, our financial condition and operating results, capital requirements and other anticipated cash needs, contractual restrictions and obligations, legal, tax and regulatory restrictions and other factors.
Additionally, as a holding company, our ability to pay dividends or repurchase shares of our Class A Common Stock is subject to the ability of our operating subsidiary OpCo and any future subsidiaries to provide cash to us. Viper Energy, Inc. has no material assets other than its membership interest in OpCo, which holds all of the mineral and royalty interests and other assets consolidated on our balance sheet.
Under the DGCL we may only pay dividends to our stockholders out of (i) our surplus, as defined and computed under the provisions of the DGCL, or (ii) our net profits for the fiscal year in which the dividend is declared and/or the preceding fiscal year. If we do not have sufficient surplus or net profits, we will be prohibited by law from paying any such dividend. In addition, the terms of the OpCo’s revolving credit facility include, and any other debt instruments or financing arrangements may from time to time include covenants or other restrictions that could constrain our ability to pay dividends, make other distributions or repurchase shares of our Class A Common Stock. Our certificate of incorporation contains provisions authorizing us to issue series of preferred stock that may have designations, preferences, rights, powers and duties that are different from, and may be senior to, those applicable to our Class A Common Stock.
For additional information regarding stockholders’ equity and our repurchase program, see Note 7— Stockholders' Equity in Item 8. Financial Statements and Supplementary Data of this report.
Risks Related to the Pending 2025 Drop Down
Our ability to complete the Pending 2025 Drop Down is subject to various closing conditions outside of our control, including approval by the majority of unaffiliated stockholders and regulatory clearance.
The Pending 2025 Drop Down is subject to a number of conditions to closing as specified in the equity purchase agreement for the Pending 2025 Drop Down. These closing conditions include, among others, (i) the approval of the Pending 2025 Drop Down by (a) the holders of a majority of the voting power of our Common Stock entitled to vote on such proposal, voting together as a single class, at the special meeting of our stockholders, excluding the shares beneficially owned by Diamondback and its subsidiaries, and (b) the holders of a majority of our outstanding Common Stock, in each case as required by Delaware law, (ii) the expiration or termination of the waiting period under the HSR Act relating to the Pending 2025 Drop Down and (iii) the satisfaction or waiver of other customary closing conditions. The Equity Issuance is subject to the approval by our stockholders representing a majority of the total votes cast at the special meeting on such proposal, as required by the rules of the Nasdaq Stock Market LLC.
We expect to hold the special meeting of our stockholders and close the Pending 2025 Drop Down during the second quarter of 2025. No assurance can be given, however, that the requisite stockholder approvals or the HSR Act regulatory clearance will be obtained or that the other required closing conditions will be satisfied. Even if the requisite stockholder
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approvals and the HSR regulatory clearance are obtained, no assurance can be given as to the timing of such approval or clearance. Any delay in completing the Pending 2025 Drop Down could cause us not to be able to realize, or to be delayed in realizing, some or all of the benefits that we expect to achieve if the Pending 2025 Drop Down is successfully completed within its expected time frame. We cannot provide any assurance that these conditions will not result in the abandonment or delay of the Pending 2025 Drop Down. The occurrence of any of these events individually or in combination could have a material adverse effect on our results of operations and the trading price of our Class A Common Stock.
We may be unable to realize anticipated cash flows or other benefits from the Pending 2025 Drop Down.
Our ability to achieve the anticipated benefits from the Pending 2025 Drop Down will depend in part upon an assessment of several factors, including:
• recoverable reserves;
• future natural gas and oil prices and their appropriate differentials;
• existing and future production on the mineral and royalty acreage subject to the Pending 2025 Drop Down and Diamondback’s plans with respect to such Diamondback-operated acreage;
• any title defects; and
• environmental and other regulatory, permitting and similar matters.
The accuracy of these assessments is inherently uncertain. In connection with these assessments, we have performed a review of the subject properties that we believe to be generally consistent with industry practices. Our review may not reveal all existing or potential problems or permit us to become sufficiently familiar with the assets to fully assess their deficiencies and potential recoverable reserves. Inspections will not always be performed on every well, and structural and environmental problems are not necessarily observable even when an inspection is undertaken. The integration process may be subject to delays or changed circumstances, and we can give no assurance that the Endeavor Mineral and Royalty Interests will generate cash flow in accordance with our expectations. Significant acquisitions, such as the Pending 2025 Drop Down, and other strategic transactions may involve other risks that may cause our business to be adversely impacted, including:
• diversion of our management’s attention to evaluating and negotiating significant acquisitions and strategic transactions; and
• the failure to realize the full benefit that we expect in estimated proved reserves, production volume or other benefits anticipated from an acquisition, or to realize these benefits within the expected time frame.
Recent Developments
2025 Transactions
Morita Ranches Acquisition
On February 14, 2025, we completed the Morita Ranches Acquisition for consideration consisting of approximately (i) $211.0 million in cash and (ii) 2.40 million OpCo Units together with an equal number of shares of Class B Common Stock to be issued to the Morita Ranches Equity Recipients, subject to certain transaction costs and post-closing adjustments. The mineral and royalty interests acquired in the Morita Ranches Acquisition represent approximately 1,691 net royalty acres located in the Permian Basin. We funded the cash consideration for the Morita Ranches Acquisition with cash on hand.
2025 Equity Offering
On February 3, 2025, we completed an underwritten public offering of approximately 28.34 million shares of our Class A Common Stock, which included approximately 3.70 million shares issued pursuant to an option to purchase additional shares of Class A Common Stock granted to the underwriters, at a price to the public of $44.50 per share for total net proceeds of approximately $1.2 billion, after the underwriters’ discount and transaction costs (the “2025 Equity Offering”). We intend to use the proceeds from the 2025 Equity Offering to fund the cash consideration for the Pending 2025 Drop Down, if it closes, and will use the remaining proceeds for general corporate purposes. If the Pending 2025 Drop Down does not close, we will use the proceeds from the 2025 Equity Offering for general corporate purposes.
Pending 2025 Drop Down Transaction
On January 30, 2025, we and the Operating Company entered into a definitive equity purchase agreement with Endeavor and the Endeavor Subsidiaries, each of which is a subsidiary of Diamondback, to acquire the Endeavor Subsidiaries from Endeavor for consideration consisting of (i) $1.0 billion in cash and (ii) the issuance of approximately 69.63 million OpCo Units and an equivalent number of shares of our Class B Common Stock, in each case subject to customary closing adjustments, including, among other things, for net title benefits. The mineral and royalty interests acquired in the Pending 2025 Drop Down represent approximately 22,847 net royalty acres in the Permian Basin, 69% of which are operated by Diamondback. The Pending 2025 Drop Down is expected to close in the second quarter of 2025, subject to certain conditions discussed further in Note 13— Subsequent Events in Item 8. Financial Statements and Supplementary Data of this report.
See Note 13— Subsequent Events in Item 8. Financial Statements and Supplementary Data of this report for further information.
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2024 Acquisitions and Divestitures Update
Tumbleweed Acquisitions
On October 1, 2024, we completed the TWR Acquisition for consideration consisting of approximately (i) $464.2 million in cash, including transaction costs and certain customary post-closing adjustments, (ii) 10.09 million OpCo Units to TWR IV, (iii) the TWR Class B Option, and (iv) contingent cash consideration of up to $41.0 million, payable in January of 2026, based on the WTI 2025 Average. The mineral and royalty interests acquired in the TWR Acquisition represent approximately 3,067 net royalty acres located primarily in the Permian Basin.
On September 3, 2024, we completed (i) the Q Acquisition, which consisted of approximately 406 net royalty acres primarily in the Permian Basin, for a purchase price of approximately $114.0 million in cash, including transaction costs and certain customary post-closing adjustments, and contingent cash consideration of up to $5.4 million payable in January of 2026, based on the WTI 2025 Average and (ii) the M Acquisition, which consisted of approximately 267 net royalty acres primarily in the Permian Basin, for a purchase price of approximately $76.1 million in cash, including transaction costs and certain customary post-closing adjustments, and contingent cash consideration of up to $3.6 million payable in January of 2026, based on the WTI 2025 Average.
Other Acquisitions
During the year ended December 31, 2024 , we acquired, in individually insignificant transactions from unrelated third-party sellers, mineral and royalty interests representing 261 net royalty acres in the Permian Basin for an aggregate net purchase price of approximately $54.2 million, including customary closing adjustments.
Divestiture
In the second quarter of 2024, we divested all of our non-Permian assets for a purchase price of approximately $87.2 million, including transaction costs and customary post-closing adjustments. The divested properties consisted of approximately 2,713 net royalty acres with current production of approximately 450 BO/d.
After giving effect to the recently completed Morita Ranches Acquisition and the Pending 2025 Drop Down, our footprint of mineral and royalty interests totaled approximately 60,209 net royalty acres, approximately 59% of which are operated by Diamondback.
See Note 4— Acquisitions and Divestitures in Item 8. Financial Statements and Supplementary Data of this report for further information.
2024 Equity Offering
On September 13, 2024, we completed an underwritten public offering of approximately 11.50 million shares of our Class A Common Stock, which included 1.50 million shares issued pursuant to an option to purchase additional shares of Class A Common Stock granted to the under writers, at a price to the public of $42.50 per share fo r total net proceeds of approximately $475.9 million , after the underwriters’ discount and transaction costs (the “2024 Equity Offering”). The proceeds from the 2024 Equity Offering were primarily used to fund the cash portion of the TWR Acquisition.
Diamondback Offering
On March 8, 2024, Diamondback completed an underwritten public offering in which it sold approximately 13.2 million shares of our Class A Common Stock (the “Diamondback Offering”). See Note 1— Organization and Basis of Presentat ion in Item 8. Financial Statements and Supplementary Data of this report for further information.
Commodity Prices and Certain Other Market Considerations
Prices for oil, natural gas and natural gas liquids are determined primarily by prevailing market conditions. Regional and worldwide economic activity, 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. OPEC and its non-OPEC allies, known collectively as OPEC+, continue to meet regularly to evaluate the state of global oil supply, demand and inventory levels and can heavily influence volatility in oil prices. During 2024, 2023 and 2022, WTI prices averaged $75.76, $77.60 and $94.33 per Bbl, respectively, and Henry Hub prices averaged $2.41, $2.66 and 6.54 per MMBtu, respectively. For additional
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information around risks related to commodity prices, see Part II. Item 7A. Quantit ative and Qualitat ive Discl osures About Market Ri sk —Commodity Price Risk.
Based on 2024 commodity prices, industry conditions and the results of the quarterly ceiling tests, we were not required to record an impairment on our proved oil and natural gas interests during the year ended December 31, 2024. If commodity prices fall below current levels, we may be required to record impairments in future periods and such impairments could be material. Further, if commodity prices decrease, our production, proved reserves and cash flows may be adversely impacted. Our business may also be adversely impacted by any pipeline capacity and storage constraints.
Cash Distributions
On August 1, 2024, our board of directors approved increasing our annual base dividend to $1.20 per share of Class A Common Stock beginning with the dividend payable for the second quarter of 2024. On January 30, 2025, we declared a combined base and variable cash dividend of $0.65 per share of Class A Common Stock and $0.69 per OpCo Unit payable on March 13, 2025.
2025 Guidance
The following table presents our current estimates of certain financial and operating results for the first quarter of 2025:
2025 Guidance
Q1 2025 net production - MBO/d
Q1 2025 net production - MBOE/d
Costs ($/BOE)
Depletion
Cash general and administrative expenses
Non-cash share-based compensation
Net interest expense
Production and ad valorem taxes (% of revenue)
Cash tax rate (% of pre-tax income attributable to Viper Energy, Inc.)
Q1 2025 cash taxes (In millions) (1)
(1) Attributable to Viper Energy, Inc.
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Production and Operational Update
As of December 31, 2024, there were 54 gross rigs operating on our mineral and royalty acreage, 10 of which are operated by Diamondback. We continue to deliver strong organic production growth on our legacy assets and successfully execute on our differentiated acquisition strategy.
The following table summarizes our gross well information as of December 31, 2024, unless otherwise specified:
Diamondback Operated
Third-Party Operated
Total
Horizontal wells turned to production (fourth quarter 2024) (1) :
Gross wells
Net 100% royalty interest wells
Average percent net royalty interest
Horizontal wells turned to production (year ended December 31, 2024) (2) :
Gross wells
Net 100% royalty interest wells
Average percent net royalty interest
Horizontal producing well count:
Gross wells
Net 100% royalty interest wells
Average percent net royalty interest
Horizontal active development well count (3) :
Gross wells
Net 100% royalty interest wells
Average percent net royalty interest
Line of sight wells (4) :
Gross wells
Net 100% royalty interest wells
Average percent net royalty interest
(1) Average lateral length of 10,818 feet.
(2) Average lateral length of 11,381 feet.
(3) The total 867 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.
(4) The total 1,191 line-of-sight wells are those that are not currently in the process of active development, but for which Viper has reason to believe 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 net royalty acreage does not ensure that those wells will be turned to production given the volatility in oil prices.
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Results of Operations
Comparison of the Years Ended December 31, 2024 and 2023
For a discussion of the results of operations for the year ended December 31, 2023 as compared to the year ended December 31, 2022, please refer to Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations in our Annual Report on Form 10-K for the year ended December 31, 2023 (filed with the SEC on February 22, 2024), which is incorporated in this report by reference from such prior report on Form 10-K.
The following table summarizes our income and expenses for the periods indicated:
Year Ended December 31,
(In thousands)
Operating income:
Oil income
Natural gas income
Natural gas liquids income
Royalty income
Lease bonus income—related party
Lease bonus income
Other operating income
Total operating income
Costs and expenses:
Production and ad valorem taxes
Depletion
General and administrative expenses—related party
General and administrative expenses
Other operating (income) expense
Total costs and expenses
Income (loss) from operations
Other income (expense):
Interest expense, net
Gain (loss) on derivative instruments, net
Other income, net
Total other expense, net
Income (loss) before income taxes
Provision for (benefit from) income taxes
Net income (loss)
Net income (loss) attributable to non-controlling interest
Net income (loss) attributable to Viper Energy, Inc.
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The following table summarizes our production data, average sales prices and average costs for the periods indicated:
Year Ended December 31,
Production data:
Oil (MBbls)
Natural gas (MMcf)
Natural gas liquids (MBbls)
Combined volumes (MBOE) (1)
Average daily oil volumes (BO/d)
Average daily combined volumes (BOE/d)
Average sales prices:
Oil ($/Bbl)
Natural gas ($/Mcf)
Natural gas liquids ($/Bbl)
Combined ($/BOE) (2)
Oil, hedged ($/Bbl) (3)
Natural gas, hedged ($/Mcf) (3)
Natural gas liquids ($/Bbl) (3)
Combined price, hedged ($/BOE) (3)
Average costs ($/BOE):
Production and ad valorem taxes
General and administrative - cash component
Total operating expense - cash
General and administrative - non-cash stock compensation expense
Interest expense, net
Depletion
(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 on our matured commodity derivative transactions on our average sales prices.
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 increased $136.5 million during the year ended December 31, 2024 compared to the same period in 2023. This net increase consisted of an additional $179.4 million in royalty income from the 27% growth in production, partially offset by a decrease of $42.9 million due to lower average oil, natural gas and natural gas liquids prices received from our production during 2024 compared to the same period in 2023.
Approximately 64% of the overall increase in production is attributable to the GRP Acquisition and approximately 12% is attributable to the Tumbleweed Acquisitions. The remainder of the growth comes from new wells added between periods. See Note 4— Acquisitions and Divestitures in Item 8. Financial Statements and Supplementary Data of this report for definition and further discussion of our acquisitions.
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Lease Bonus Income — Related Party. Lease bonus income from Diamondback decreased $107.6 million during the year ended December 31, 2024 due to receiving payment for three new leases covering approximately 85 acres in Martin County Texas, compared to (i) one lease of $95.8 million in our Spanish Trail prospect in Midland County, Texas, (ii) nine other new leases in Martin, Midland, Pecos and Wheeler Counties; Texas, and (iii) two lease extensions in Martin County, Texas, in the same period in 2023.
Production and Ad Valorem Taxes. The following table presents production and ad valorem taxes for the periods indicated:
Year Ended December 31,
Amount
(In thousands)
Per BOE
Percentage of Royalty Income
Amount
(In thousands)
Per BOE
Percentage of Royalty Income
Production taxes
Ad valorem taxes
Total production and ad valorem taxes
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 year ended December 31, 2024 remained consistent with 2023.
Ad valorem taxes are based, among other factors, on property values driven by prior year commodity prices. Ad valorem taxes for the year ended December 31, 2024 remained consistent with 2023 as a percentage of royalty income and on a per BOE basis.
Depletion. The increase in depletion expense of $68.3 million for the year ended December 31, 2024 compared to the same period in 2023 consisted primarily of (i) $39.7 million from growth in production volumes, and (ii) $28.6 million due to an increase in the depletion rate to $11.77 per BOE for the year ended December 31, 2024, resulting primarily from the addition of leasehold costs and reserves from the GRP Acquisition and the Tumbleweed Acquisitions compared to $10.20 per BOE for the same period in 2023.
General and Administrative Expenses. The following table shows general and administrative expenses for the periods presented:
Year Ended December 31,
(In thousands, except per BOE amounts)
General and administrative expenses—related party
General and administrative expenses
General and administrative expenses
General and administrative expenses ($ per BOE)
The $8.0 million increase in general and administrative expenses for the year ended December 31, 2024 compared to 2023 consists of (i) a $6.8 million increase in expenses billed by Diamondback as discussed below, and (ii) a $1.2 million net increase of non-cash compensation related to unvested employee restricted stock units.
Prior to 2024, we reimbursed Diamondback a flat quarterly fee for management and administrative services provided to us by Diamondback. Beginning in 2024, Diamondback began billing us for estimated actual salary and benefit costs incurred for services provided to us by seconded employees under the services and secondment agreement.
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Interest Expense, Net. Net interest expense increased by $26.5 million for the year ended December 31, 2024, compared to the same period in 2023. The increase primarily consisted of (i) approximately $23.7 million due to recording a full year of interest expense for our 2031 Notes, which were issued in October 2023, (ii) approximately $1.8 million in additional interest expense on our revolving credit facility, and (iii) other individually insignificant changes. See Note 6— Debt in Item 8. Financial Statements and Supplementary Data of this report for definition and additional discussion of our 2031 Notes.
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:
Year Ended December 31,
(In thousands)
Gain (loss) on derivative instruments
Net cash receipts (payments) on derivatives
The change to a gain on derivative instruments from a loss on derivative instruments for the year ended December 31, 2024 compared to 2023 is primarily due to an increase in the differential between prices for Waha Hub and Henry Hub resulting in a gain on our natural gas basis swaps in the year ended December 31, 2024 compared to a loss in 2023. See Note 10— Derivatives in Item 8. Financial Statements and Supplementary Data of this report for additional discussion of our open contracts at December 31, 2024.
Provision for (Benefit from) Income Taxes. We recorded an income tax benefit of $99.7 million and an income tax expense of $46.0 million for the years ended December 31, 2024 and 2023, respectively. This change is primarily due to the release of our remaining valuation allowance of $155.9 million during the fourth quarter of 2024. This was slightly offset by an increase in taxable income attributable to Viper Energy, Inc. in 2024. See Note 9— Income Taxes in Item 8. Financial Statements and Supplementary Data of this report for further details.
Net Income (Loss) Attributable to Non-controlling Interest. The $56.9 million decrease in net income attributable to non-controlling interest for the year ended December 31, 2024 compared to the same period in 2023 is primarily due to a reduction in Diamondback’s ownership in the Operating Company following the completion of the Diamondback Offering and the 2024 Equity Offering in which Viper received additional OpCo Units from the Operating Company in exchange for the proceeds of the 2024 Equity Offering .
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, 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 revolving credit facility. Our primary uses of cash have been dividends to our stockholders, Operating Company distributions to the holders of OpCo Units, repayments of debt, capital expenditures for the acquisition of our mineral and royalty interests in oil and natural gas properties, including the Tumbleweed Acquisitions and repurchases of our Class A Common Stock. At December 31, 2024, we had approximately $1.0 billion of liquidity consisting of $26.9 million in cash and cash equivalents and $989.0 million available under the Operating Company’s revolving credit facility . As noted above in "— Recent Developments ,” in February 2025 we raised an additional $1.2 billion in net cash proceeds from the 2025 Equity Offering, which will be used to fund the cash portion of the Pending 2025 Drop Down, if it closes. If the Pending 2025 Drop Down does not close, then the $1.2 billion in net cash proceeds from the 2025 Equity Offering will be used for general corporate purposes. See further discussion of changes in our sources of cash in “ — Capital Resources ” below.
Our working capital requirements are supported by our cash and cash equivalents and the Operating Company’s revolving credit facility. We may draw on the Operating Company’s revolving credit facility 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 future acquisitions of
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mineral and royalty interests, dividends, debt service obligations, repayment of debt maturities, repurchases of our Class A Common Stock or any of our Notes, and any amounts that may ultimately be paid in connection with contingencies.
In order to mitigate volatility in oil and natural gas prices, we have entered into commodity derivative contracts as discussed further in Part II. Item 7A. Quantitative and Qualitative Disclosures About Market Risk —Commodity Price Risk of this report.
Continued prolongedvolatility in the capital, financial and/or credit markets due to the war in Ukraine, the Israel-Hamas War and other conflicts in the Middle East, and/or adverse macroeconomic conditions, including higher interest rates, global supply chain disruptions and actions taken by OPEC members and other exporting nations 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 period indicated:
Year Ended December 31,
(In thousands)
Cash flow data:
Net cash provided by (used in) operating activities
Net cash provided by (used in) investing activities
Net cash provided by (used in) financing activities
Net increase (decrease) in cash and cash equivalents
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 year ended December 31, 2024 compared to the same period in 2023 was primarily driven by (i) a reduction in related party lease bonus income, (ii) an increase in cash paid for interest expense due to the issuance of our 2031 Notes in the fourth quarter of 2023, (iii) changes in our working capital accounts, (iv) an increase in cash costs for production and ad valorem taxes and payments to Diamondback related to the change in the Pre-Conversion reimbursement methodology contemplated by the services and secondment agreement beginning on January 1, 2024, and (v) an increase in cash paid for taxes. These decreases in cash flow were offset by (i) an increase in royalty income, and (ii) a decrease in cash paid for derivatives. See “ — Results of Operations ” above for further discussion of significant changes in our income and expenses.
Investing Activities
Net cash used in investing activities during the year ended December 31, 2024 primarily related to acquisitions of oil and natural gas interests from third parties, which includes $654.3 million in cash paid for the Tumbleweed Acquisitions, partially offset by proceeds of $87.7 million primarily from the divestiture of non-Permian oil and natural gas interests.
Net cash used in investing activities during the year ended December 31, 2023 primarily related to acquisitions of oil and natural gas interests from third parties, which includes $747.5 million in cash paid for the GRP Acquisition, and $74.5 million in cash paid for the acquisition of other oil and natural gas interests in the 2023 Drop Down.
Financing Activities
Net cash used in financing activities during the year ended December 31, 2024 was primarily attributable to $481.0 million of dividends paid to stockholders and the Operating Company’s unitholders and net repayments of $2.0 million on the Operating Company’s revolving credit facility, offset by proceeds of $475.9 million from the 2024 Equity Offering .
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Net cash provided by financing activities for the year ended December 31, 2023 primarily resulted from (i) net proceeds from the 2031 Notes of $394.0 million, (ii) proceeds from the 2023 Viper Issuance of $200.0 million, and (iii) net borrowings of $111.0 million under the Operating Company’s revolving credit facility. These cash inflows were partially offset by dividends paid to stockholders of $324.8 million and $95.2 million of Class A Common Stock repurchases. See Note 7— Stockholders' Equity in Item 8. Financial Statements and Supplementary Data of this report for additional discussion of the 2023 Viper Issuance.
Capital Resources
The Operating Company’s Revolving Credit Facility
On November 22, 2024, t he Operating Company entered into a thirteenth amendment to the existing credit facility, which, (i) maintained the maximum credit amount of $2.0 billion, (ii) maintained the borrowing base of $1.3 billion, and (iii) increased the aggregate elected commitment amount from $850.0 million to $1.3 billion.
The Operating Company had $261.0 million in outstanding borrowings and $989.0 million of availability on its revolving credit facility at December 31, 2024.
As of December 31, 2024, the Operating Company was in compliance, and expects to be in compliance, with all financial maintenance covenants under its credit facility. See Note 6— Debt in Item 8. Financial Statements and Supplementary Data of this report for additional discussion of our outstanding debt at December 31, 2024.
Capital Requirements
Pending 2025 Drop Down
On January 30, 2025, in connection with the Pending 2025 Drop Down, we entered into a definitive equity purchase agreement with Endeavor and the Endeavor Subsidiaries, pursuant to which and subject to the terms and conditions of such equity purchase agreement, we are obligated to pay Diamondback $1.0 billion in cash at the closing of, and as part of the total consideration for, the Pending 2025 Drop Down, which is expected to close during the second quarter of 2025.
See Note 13— Subsequent Events in Item 8. Financial Statements and Supplementary Data of this report for additional information on the Pending 2025 Drop Down.
Senior Notes
At December 31, 2024, we have total principal payments due on our outstanding Notes of $430.4 million in 2027 and $400.0 million in 2031. Additionally, we have a remaining aggregate interest expense obligation of $275.9 million on the Notes with $52.6 million due in 2025, an aggregate of $105.3 million due for years 2026 to 2027, an aggregate of $59.0 million due for years 2028 to 2029, and $59.0 million due thereafter. The Notes are not subject to any mandatory redemption or sinking fund requirements. See Note 6— Debt in Item 8. Financial Statements and Supplementary Data of this report for further information on the Notes.
Repurchases of Securities
Under our current common stock repurchase program, the board of directors has authorized us to acquire up to $750.0 million of our Common Stock, excluding excise tax. As of December 31, 2024, $434.2 million remains avail able for use to repurchase shares under this repurchase program. See Note 7— Stockholders' Equity in Item 8. Financial Statements and Supplementary Data of this report for further discussion of the stock repurchase program.
We may also from time to time opportunistically repurchase some of the outstanding Notes in open market purchases or in privately negotiated transactions.
Cash Dividends
We paid a total of $481.0 million and $324.8 million in distributions or dividends, as applicable, on our common shares, OpCo Units and participating securities under the LTIP during 2024 and 2023, respectively.
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The dividend for the fourth quarter of 2024 is $0.65 per share of Class A Common Stock and $0.69 per OpCo Unit, and in each case is payable on March 13, 2025 to eligible holders of record at the close of business on March 6, 2025. The dividend on our Class A Common Stock consists of a base quarterly dividend of $0.30 per share and a variable quarterly dividend of $0.35 per share. See Note 7— Stockholders' Equity in Item 8. Financial Statements and Supplementary Data of this report for further discussion of our dividends. We expect to continue paying quarterly cash dividends in respect of our common shares. Future base and variable dividends are not required and are at the discretion of the board of directors, who may change the dividend policies at any time.
Critical Accounting Estimates
The discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with GAAP.
Certain amounts included in or affecting our consolidated financial statements and related disclosures must be estimated by our management, requiring certain assumptions to be made with respect to values or conditions that cannot be known with certainty at the time the consolidated financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities and our disclosure of contingent assets and liabilities at the date of the consolidated financial statements. Accounting estimates are considered to be critical if (i) the nature of the estimates and assumptions is material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters or the susceptibility of such matters to change, and (ii) the impact of the estimates and assumptions on financial condition or operating performance is material. We evaluate these estimates on an ongoing basis, using historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Any effects on our 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.
We consider the following to be our most critical accounting estimates and have reviewed these critical accounting estimates with the Audit Committee of our Board of Directors.
Royalty Income and Revenue Recognition
We record revenue in the month production is delivered to the purchaser. However, settlement statements for certain oil, natural gas and natural gas liquids sales from third-party operators other than Diamondback may not be received for 30 to 90 days after the date production is delivered. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the royalties related to expected sales volumes and prices for those properties are estimated and recorded based upon the Company’s interest. Where available, historical actual data is used to calculate volume estimates for wells operated by third parties. If historical actual data is not available for these wells, engineering estimates are used to calculate expected volumes. As such, estimated volumes utilized in period end royalty income accruals are subject to revision as additional actual data becomes available and such revisions may have a material impact on our results of operations and our royalty income receivables. Pricing estimates are based upon actual prices realized in an area by adjusting the market price for the average basis differential from market on a basin-by-basin basis. We record the differences between our estimates and the actual amounts received for royalties from third parties in the month that payment is received from the producer. We have existing internal controls for our royalty income estimation process and related accruals, but actual third-party royalty income in future periods could differ materially from estimated amounts. At December 31, 2024, our accrual for third-party royalty income was approximately $102.8 million. Actual revenues received during 2024 for prior years’ production from third parties were approximately $7.3 million, or 9%, higher than the amount accrued at December 31, 2023.
Oil and Natural Gas Accounting and Reserves
We account for oil and natural gas producing activities using the full cost method of accounting, which is dependent on the estimation of proved reserves to determine the rate at which we record depletion on our oil and natural gas properties and whether the value of our evaluated oil and natural gas properties is permanently impaired based on the quarterly full cost ceiling impairment test. Further, we utilize estimated proved reserves to assign fair value to acquired mineral and royalty interests. As such, we consider the estimation of proved reserves to be a critical accounting estimate.
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Oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be precisely measured and the accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Proved oil and natural gas reserve estimates and their associated future net cash flows were prepared by our internal reservoir engineers and audited by Ryder Scott, independent petroleum engineers, as of December 31, 2024, 2023 and 2022. The process of estimating oil and natural gas reserves is complex, requiring significant decisions in the evaluation of available geological, geophysical, engineering and economic data. Significant inputs included in the calculation of future net cash flows include anticipated production of proved reserves and other relevant data. The data for a given property may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and a continual reassessment of the viability of production under changing economic conditions. As a result, material revisions to existing reserve estimates occur from time to time, and reserve estimates are often different from the quantities of oil and natural gas that are ultimately recovered. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the subjective decisions and variances in available data for various properties increase the likelihood of significant changes in these estimates. If such changes are material, they could significantly affect future depletion of capitalized costs and result in impairment of assets that may be material. No impairments were recorded on our proved oil and natural gas properties during the years ended December 31, 2024, 2023 and 2022. Based on the historical 12-month average trailing SEC prices for oil and natural gas throughout 2024 and into 2025, we are not currently projecting a full cost ceiling impairment in the first quarter of 2025. Any future impairment could be material to our consolidated financial statements.
Additionally, costs associated with unevaluated properties are excluded from the full cost pool until we have made a determination as to the existence of proved reserves. We assess all items classified as unevaluated property (on an individual basis or as a group if properties are individually insignificant) at least annually for possible impairment. This assessment is subjective and includes consideration of the following factors, among others: (i) monitoring information available from third-party operators of our acreage for future drilling plans, (ii) the success of operators drilling on our acreage, (iii) the assignment of proved reserves, and (iv) current market prices for mineral acreage within our primary basins. At December 31, 2024, our unevaluated properties totaled $2.2 billion. We did not record any impairment on our unevaluated properties during the year ended December 31, 2024, but any such future impairment could be material to our consolidated financial statements.
Acquisitions of Mineral and Royalty Interests
Acquisitions of mineral and royalty interests are accounted for as asset acquisitions, whereby the purchase price and associated transaction costs are capitalized and allocated to the acquired mineral and royalty interests. The allocation is determined based on whether the interests acquired relate to proved or unproved oil and natural gas properties, utilizing the estimated fair value of proved reserves as of the date of acquisition. The valuation of proved reserves is based on a projection of future cash flows using objective future pricing assumptions and a discount rate consistent with our estimated cost of capital at the time of the acquisition.
Income Taxes
The amount of income taxes we record requires interpretations of complex rules and regulations of federal, state, and provincial tax jurisdictions. We use the asset and liability method of accounting for income taxes, under which deferred tax assets and liabilities are recognized for the future tax consequences of (i) temporary differences between the financial statement carrying amounts and the tax bases of existing assets and liabilities, and (ii) operating loss and tax credit carryforwards. Deferred income tax assets and liabilities are based on enacted tax rates applicable to the future period when those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period the rate change is enacted. A valuation allowance is provided for deferred tax assets when it is more likely than not the deferred tax assets will not be realized after considering all positive and negative evidence available concerning the realizability of our deferred tax assets. Positive evidence may include forecasts of future taxable income, assessment of future business assumptions and any applicable tax planning strategies available to the Company. Negative evidence may include losses in recent years, if any, or the projection of losses in future periods. Estimating future taxable income requires numerous judgments and assumptions, including projections of future operating conditions which may be impacted by volatile future prices for our oil, natural gas and natural gas production, the expected timing and quantity of future production volumes, and the impact of our commodity derivative instruments on our income. These assumptions are discussed further in the critical accounting estimates titled “— Royalty Income and Revenue Recognition” and “— Oil and Natural Gas Accounting and Reserves.” Due to the impact these various assumptions and estimates can have on our estimates of taxable income, an estimate of the sensitivity to changes is not practicable.
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In 2024, management’s assessment of all available evidence, both positive and negative, supporting realizability of the Company’s deferred tax assets as required by applicable accounting standards, resulted in recognition of a deferred income tax benefit of $149.1 million for an increase in the portion of the Company’s deferred tax assets considered more likely than not to be realized. A variety of positive evidence was assessed. The original recording of the valuation allowance was precipitated by the impact of the COVID-19 pandemic, which resulted in a collapse of worldwide oil prices that adversely affected the Company’s profitability and its ability to reliably forecast future commodity prices and the pattern of development of undeveloped reserves. Since that time, the Company has sustained continuous net income due in part to higher commodity prices resulting from strong and stable market conditions that have resumed in the four years since the onset of the pandemic. Further, the locations in which we operate have experienced a sustained and increasing pattern of development by a wide variety of operators, consistent with a resumption of more readily predictable development pattern for our properties. Along with price and market stabilization, the significant acquisitions completed by the Company, including the Tumbleweed Acquisitions, provide additional production capacity to generate future taxable income for utilization of our deferred tax assets. Based on these factors, the Company released its remaining valuation allowance on its deferred tax assets in the fourth quarter of 2024. As of December 31, 2024, the Company had a net deferred tax asset of $184.8 million.
The accruals for deferred tax assets and liabilities are often based on assumptions that are subject to a significant amount of judgment by management. These assumptions and judgments are reviewed and adjusted as facts and circumstances change. Material changes to our income tax accruals may occur in the future based on the progress of ongoing audits, changes in legislation or resolution of pending matters.
Recent Accounting Pronouncements
See Note 2— Summary of Significant Accounting Policies in Item 8. Financial Statements and Supplementary Data of this report for discussion of recent accounting pronouncements and a full listing of our significant accounting policies.
Off-Balance Sheet Arrangements
We currently have no off-balance sheet arrangements.
