MV Oil Trust 10-K

Item 1A. Risk Factors. Operating Risks Prices of oil, natural gas and natural gas liquids fluctuate, and lower prices could reduce proceeds to the trust and cash distributions to unitholders. The reserves attributable to the underlying properties and the quarterly cash distributions of the trust are highly dependent upon the prices realized from the sale of oil, natural gas and natural gas liquids. Prices of oil, natural gas and natural gas liquids can fluctuate widely on a quarter-to-quarter basis in response to a variety of factors that are beyond the control of the trust and MV Partners. These factors include, among others: • political conditions or hostilities in oil and natural gas producing regions, including the Middle East, North Africa and South America; ​ • the outbreak of armed conflict between Russia and Ukraine and the potential destabilizing effect such conflict may pose for the European continent or the global oil and gas markets; ​ • weather conditions or force majeure events; ​ • the occurrence or threat of epidemic or pandemic diseases, such as the COVID-19 pandemic, or any government response to such occurrence or threat; ​ • the actions of OPEC and other foreign, oil-exporting countries; ​ • regional, domestic and foreign levels of supply of and demand for oil, natural gas and natural gas liquids; ​ 28 TABLE OF CONTENTS • U.S. and worldwide economic conditions; ​ • the price and availability of alternative fuels; ​ • the proximity to, and capacity of, refineries and gathering and transportation facilities; ​ • governmental regulations and taxation; and ​ • energy conservation and environmental measures. ​ Crude oil prices have been volatile during the last several years, and in 2021 ranged from a high of $84.65 to a low of $47.62. The NYMEX crude oil spot prices per Bbl were $61.06, $48.52 and $75.21 as of December 31, 2019, 2020 and 2021, respectively. Neither MV Partners nor the trust can predict the timing or the duration of any economic cycle and, depending on the prices realized, the operating results of MV Partners and the financial condition of the trust could be materially and adversely affected. The terms of the conveyance of the net profits interest prohibit MV Partners from entering into hedging arrangements for the benefit of the trust. As a result, the amounts of cash distributions by the trust may fluctuate significantly as a result of changes in commodity prices because there will be no hedge contracts in place to reduce the effects of any changes in commodity prices. Low prices of oil, natural gas and natural gas liquids will reduce the amount of the net proceeds to which the trust is entitled and may ultimately reduce the amount of oil, natural gas and natural gas liquids that is economic to produce from the underlying properties. As a result, the operator of any of the underlying properties could determine during periods of low commodity prices to shut in or curtail production from wells on the underlying properties. In addition, the operator of the underlying properties could determine during periods of low commodity prices to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. Because the underlying properties are mature, with many of them being in production since the early 1900s, decreases in commodity prices could have a more significant effect on the economic viability of these properties compared to more recently discovered properties. The commodity price sensitivity of these mature wells is due to a culmination of factors that vary from well-to-well, including the additional costs associated with water handling and disposal, chemicals, surface equipment maintenance, downhole casing repairs and reservoir pressure maintenance activities that are necessary to maintain production. As a result, the volatility of commodity prices may cause the amount of future cash distributions to trust unitholders to fluctuate, and a substantial decline in the price of oil, natural gas or natural gas liquids will reduce the amount of cash available for distribution to the trust unitholders. The ongoing COVID-19 pandemic and related economic turmoil have affected and could continue to adversely affect proceeds to the Trust and quarterly cash distributions to unitholders. The COVID-19 pandemic and the measures put in place to address it have created significant volatility, uncertainty, and economic disruption since the first quarter of 2020. Over the course of the pandemic, public health officials have recommended or mandated certain precautions to mitigate the spread of COVID-19, including quarantines, shelter-in-place orders and business and government shutdowns. Although some of these limitations and mandates have been relaxed in certain jurisdictions, others have been reinstated in areas that have experienced a resurgence of COVID-19 cases and there is no guarantee restrictions will not be reimposed in the future. Despite the increased availability of vaccines in certain jurisdictions, the COVID-19 pandemic may continue or worsen during the upcoming months, including as a result of the emergence of more infectious variants of the virus, vaccine hesitancy or increased business and social activities, which may cause governmental authorities to reinstate restrictions. As a result, the ongoing impact of the COVID-19 pandemic remains uncertain and will depend on the severity, location and duration of the effects and spread of the disease, the effectiveness and duration of actions taken by authorities to contain the virus or treat its effect, the availability and effectiveness of vaccines or other treatments, and how quickly and to what extent economic conditions improve. Furthermore, the impact of the pandemic, including a resulting reduction in demand for oil and natural gas, coupled with the sharp decline in commodity prices following the announcement of price reductions and production increases in March 2020 by members of OPEC, led to significant global economic 29 TABLE OF CONTENTS contraction generally and in the oil and gas industry in particular, which experienced a significant downturn during 2020 and into 2021. Oil and natural gas prices are expected to continue to be volatile as a result of the ongoing COVID-19 pandemic and other factors affecting the global economy, and the trust cannot predict whether or when prices will stabilize. The trust cannot predict the full impact that COVID-19 or the significant disruption and volatility currently being experienced in the oil and natural gas markets will have on MV Partners’ business, financial condition and results of operations or on proceeds to the trust and the trust’s reserves and quarterly cash distributions to unitholders due to numerous uncertainties. The extent to which COVID-19 negatively impacts the operators of and production from the underlying properties will depend on the severity, location and duration of the effects and spread of COVID-19, the actions undertaken by federal, state and local governments and health officials to contain the virus or treat its effects, and how quickly and to what extent economic conditions improve and normal business and operating conditions resume. A prolonged period of low crude oil prices will adversely affect the operators of the underlying properties. For example, as a result of the decreased price of crude oil during the second quarter of 2020, there was no distribution made to unitholders in the third quarter of 2020. If commodity prices for crude oil were to decline again, quarterly cash distributions to unitholders will be substantially lower than historical distributions, and in certain periods there may be no distribution to unitholders. Low prices of oil may ultimately reduce the amount of oil that is economic to produce from the underlying properties. As a result, the operator of the underlying properties could determine, during periods of low commodity prices, to shut in or curtail production on the underlying properties. In addition, the operator of the underlying properties could determine, during periods of low commodity prices, to plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. The ultimate impact of COVID-19 will depend on future developments, which are highly uncertain, difficult to predict and largely outside of the trust’s control, including, among others, the continued spread, duration and severity of the pandemic outbreak; the occurrence, spread, duration and severity of any new variants of COVID-19, such as the Delta or Omicron variants; the consequences of governmental and other measures designed to prevent the spread of the virus; the development of effective treatments; actions taken by governmental authorities, MV Partners’ customers and other third parties; workforce availability; and the timing and extent to which normal economic and operating conditions resume. To the extent COVID-19 adversely affects production from the underlying properties or the business, results of operations and financial condition of the operators of the underlying properties, it may also have the effect of heightening many of the other risks described in this Form 10-K. Actual reserves and future production may be less than current estimates of proved reserves, which could reduce cash distributions by the trust and the value of the trust units. The value of the trust units and the amount of future cash distributions to the trust unitholders will depend upon, among other things, the accuracy of the production and reserves estimated to be attributable to the underlying properties and the net profits interest. Estimating production and reserves is inherently uncertain. Ultimately, actual production, revenues and expenditures for the underlying properties could vary both positively and negatively from estimates and those variations could be material. Petroleum engineers consider many factors and make assumptions in estimating production and reserves. Those factors and assumptions include: • historical production from the area compared with production rates from other producing areas; ​ • the assumed effect of governmental regulation; and ​ • assumptions about future prices of oil, natural gas and natural gas liquids, production and development expenses, gathering and transportation costs, severance and excise taxes and capital expenditures. ​ Changes in these assumptions can materially increase or decrease production and reserve estimates. The estimated reserves attributable to the net profits interest and the estimated future net revenues attributable to the net profits interest are based on estimates of reserve quantities and revenues for the 30 TABLE OF CONTENTS underlying properties. See “Item 1. Business — Description of the Underlying Properties — Reserves” for a discussion of the method of allocating proved reserves to the underlying properties and the net profits interest. The quantities of reserves attributable to the underlying properties and the net profits interest may decrease in the future as a result of future decreases in the price of oil, natural gas or natural gas liquids. Risks associated with the production, gathering, transportation and sale of oil, natural gas and natural gas liquids could adversely affect cash distributions by the trust. The revenues of the trust, the value of the trust units and the amount of cash distributions to the trust unitholders depend upon, among other things, the costs incurred by MV Partners to develop and exploit oil and natural gas reserves attributable to the underlying properties. Drilling, production or transportation accidents that temporarily or permanently halt the production and sale of oil, natural gas and natural gas liquids at any of the underlying properties will reduce trust distributions by reducing the amount of net proceeds available for distribution. For example, accidents may occur that result in personal injuries, property damage, damage to productive formations or equipment and environmental damages. Any costs incurred by MV Partners in connection with any such accidents that are not insured against will have the effect of reducing the net proceeds available for distribution to the trust. In addition, curtailments or damage to pipelines used by MV Partners to transport oil, natural gas and natural gas liquid production to markets for sale could reduce the amount of net proceeds available for distribution. Any such curtailment or damage to the gathering systems used by MV Partners could also require MV Partners to find alternative means to transport the oil, natural gas and natural gas liquid production from the underlying properties, which alternative means could require MV Partners to incur additional costs that will have the effect of reducing net proceeds available for distribution by the trust. The trust does not maintain any type of insurance against any of the risks of conducting oil and gas exploration and production activities. The ability or willingness of OPEC and other oil exporting nations to set and maintain production levels has a significant impact on oil and natural gas commodity prices, which could reduce the amount of cash available for distribution to Trust unitholders. OPEC is an intergovernmental organization that seeks to manage the price and supply of oil on the global energy market. Actions taken by OPEC members, including those taken alongside other oil exporting nations, have a significant impact on global oil supply and pricing. For example, OPEC and certain other oil exporting nations have previously agreed to take measures, including production cuts, to support crude oil prices. There can be no assurance that OPEC members and other oil exporting nations will agree to future production cuts or other actions to support and stabilize oil prices, nor can there be any assurance that they will not further reduce oil prices or increase production. Uncertainty regarding future actions to be taken by OPEC members or other oil exporting countries could lead to increased volatility in the price of oil, which could adversely affect the financial condition and economic performance of the operators of the underlying properties and may reduce the net proceeds to which the Trust is entitled, which could materially reduce or completely eliminate the amount of cash available for distribution to Trust unitholders. Production of oil, natural gas and natural gas liquids on the underlying properties could be materially and adversely affected by severe or unseasonable weather. Production of oil, natural gas and natural gas liquids on the underlying properties could be materially and adversely affected by severe weather. Repercussions of severe weather conditions may include: • evacuation of personnel and curtailment of operations; ​ • weather-related damage to drilling rigs or other facilities, resulting in suspension of operations; ​ • inability to deliver materials to worksites; and ​ • weather-related damage to pipelines and other transportation facilities. ​ Interruptions in production could have a material adverse effect on the trust’s financial condition, results of operations and cash flows, and could reduce the amount of cash distributions to unitholders. 31 TABLE OF CONTENTS Shortages or increases in costs of oil field equipment, services and qualified personnel available to MV Partners could reduce the amount of cash available for distribution to the trust unitholders. The demand for qualified and experienced field personnel to drill wells and conduct field operations, geologists, geophysicists, engineers and other professionals in the oil and natural gas industry can fluctuate significantly, often in correlation with oil and natural gas prices, causing periodic shortages. Historically, there have been shortages of drilling rigs and other oilfield equipment as demand for rigs and equipment has increased along with the number of wells being drilled. These factors also cause significant increases in costs for equipment, services and personnel. Higher oil and natural gas prices generally stimulate demand and result in increased prices for drilling rigs, crews and associated supplies, equipment and services. Shortages of field personnel and equipment or price increases could significantly decrease the amount of cash available for distribution to the trust unitholders or restrict the ability of MV Partners to drill the wells and conduct the operations which it currently has planned for the underlying properties. Financial Risks The reserves attributable to the underlying properties are depleting assets and production from those reserves will diminish over time. Furthermore, the trust is precluded from acquiring other oil and natural gas properties or net profits interests to replace the depleting assets and production. The net proceeds payable to the trust from the net profits interest are derived from the sale of oil, natural gas and natural gas liquids produced from the underlying properties. The reserves attributable to the underlying properties are depleting assets, which means that the reserves attributable to the underlying properties will decline over time. As a result, the quantity of oil and natural gas produced from the underlying properties is expected to decline over time. Based on the estimated production volumes in the reserve report, the oil and natural gas production from proved reserves attributable to the underlying properties is projected to decline at an average annual rate of approximately 9.0% over the next 20 years assuming no additional developmental drilling or other capital expenditures are made after 2026 on the underlying properties. The anticipated rate of decline is an estimate and actual decline rates may vary from those estimated. The net profits interest will terminate on the later to occur of (1) June 30, 2026, or (2) the time when 14.4 MMBoe have been produced from the underlying properties and sold (which amount is the equivalent of 11.5 MMBoe in respect of the trust’s right to receive 80% of the net proceeds from the underlying properties pursuant to the net profits interest). Future maintenance projects on the underlying properties beyond those which are currently estimated may affect the quantity of proved reserves that can be economically produced from the underlying properties. The timing and size of these projects will depend on, among other factors, the market prices of oil, natural gas and natural gas liquids. In addition, because MV Partners has agreed to limit the amount of capital expenditures that may be taken into account in calculating net proceeds attributable to the net profits interest during a specified period preceding the termination of the net profits interest, MV Partners may choose to delay certain capital projects that may otherwise benefit the trust unitholders until the termination of the net profits interest. If operators of the wells to which the underlying properties relate do not implement required maintenance projects when warranted, the future rate of production decline of proved reserves may be higher than the rate currently expected by MV Partners or estimated in the reserve report. The trust agreement provides that the trust’s business activities are limited to owning the net profits interest and any activity reasonably related to such ownership, including activities required or permitted by the terms of the conveyance related to the net profits interest. As a result, the trust is not permitted to acquire other oil and natural gas properties or net profits interests to replace the depleting assets and production attributable to the net profits interest. Because the net proceeds payable to the trust are derived from the sale of depleting assets, the portion of the distributions to unitholders attributable to depletion may be considered to have the effect of a return of capital as opposed to a return on investment. Eventually, the underlying properties burdened by the net profits interest may cease to produce in commercially paying quantities and the trust may, therefore, cease to receive any distributions of net proceeds therefrom. 32 TABLE OF CONTENTS The amount of cash available for distribution by the trust will be reduced by the amount of any production and development costs, taxes, capital expenditures and post-production costs. Production and development costs on the underlying properties are deducted in the calculation of the trust’s share of net proceeds. In addition, production and property taxes, capital expenditures or post-production costs are deducted in the calculation of the trust’s share of net proceeds. Accordingly, higher production and development expenses, taxes, capital expenditures and post-production costs will directly decrease the amount of cash received by the trust in respect of its net profits interest. For a summary of these costs for the last three years, see “Item 1. Business — Description of the Underlying Properties — Producing Acreage and Well Counts.” Historical costs may not be indicative of future costs. In addition, cash available for distribution by the trust will be further reduced by the trust’s general and administrative expenses. If development and production costs of the underlying properties exceed the proceeds of production from the underlying properties, the trust will not receive net proceeds from those properties until future proceeds from production exceed the total of the excess costs plus accrued interest during the deficit period. Development activities may not generate sufficient additional revenue to repay the costs. If annual cash proceeds received by the trust are less than $1.0 million for each of two consecutive years, then under the terms of the trust agreement, the trust would be required to dissolve. The trust has established a cash reserve for contingent liabilities and to pay expenses in accordance with the trust agreement, which would reduce net profits payable to the trust and distributions to unitholders. The trust’s source of capital is the cash flows from the net profits interest. Pursuant to the trust agreement, the trust may establish a cash reserve through the withholding of cash for contingent liabilities and to pay expenses, which will reduce the amount of cash otherwise available for distribution to unitholders. In November 2021 the trustee notified MV Partners that the trustee intends to build a reserve for the payment of future known, anticipated or contingent expenses or liabilities. Commencing with the distribution paid to unitholders in February 2022, the Trustee is withholding, and in the future intends to withhold, a portion of the proceeds otherwise available for distribution each month to gradually build a cash reserve of approximately $1.265 million. This cash is reserved for the payment of future known, anticipated or contingent expenses or liabilities of the trust. The trustee may increase or decrease the targeted amount at any time, and may increase or decrease the rate at which it is withholding funds to build the cash reserve at any time, without advance notice to the unitholders. A purchaser’s failure to pay MV Partners for purchased production could have a significant adverse impact on MV Partners, which in turn could result in MV Partners not having sufficient net proceeds attributable to the net profits interest for MV Partners to distribute cash to the trust. A purchaser’s failure to pay for purchased production could have a significant adverse impact on MV Partners’ business, which in turn could adversely affect the trust. The recent tightening of credit in the financial markets may make it more difficult for purchasers to obtain financing and depending on the degree to which this occurs, there may be a material increase in the nonpayment and nonperformance by such purchasers. If the financial position of MV Partners degrades in the future, MV Partners may not be able to satisfy its obligations to the trust. MV Partners is a privately held limited liability company engaged in the exploration, development, production, gathering and aggregation and sale of oil and natural gas, primarily in the Mid-Continent region in the United States, and it is responsible for operating substantially all of the underlying properties. The operating agreement of MV Partners provides that Vess Oil and Murfin Drilling will operate the underlying properties on behalf of MV Partners for which MV Partners is designated as the operator. The conveyance provides that MV Partners is obligated to market, or cause to be marketed, the production related to the underlying properties. The ability of MV Partners to perform its obligations related to the operation of the underlying properties will depend on MV Partners’ future financial condition and economic performance, which in 33 TABLE OF CONTENTS turn will depend upon the supply and demand for oil and natural gas, prevailing economic conditions, collections of payments due from third parties, and upon financial, business and other factors, many of which are beyond the control of MV Partners. Risks Related to the Structure of the Trust The trust and the public trust unitholders have no voting or managerial rights with respect to MV Partners, the operator of the underlying properties. As a result, public trust unitholders have no ability to influence the operation of the underlying properties. Oil and natural gas properties are typically managed pursuant to an operating agreement among the working interest owners of oil and natural gas properties. The typical operating agreement contains procedures whereby the owners of the working interests in the property designate one of the interest owners to be the operator of the property. Under these arrangements, the operator is typically responsible for making all decisions relating to drilling activities, sale of production, compliance with regulatory requirements and other matters that affect the property. MV Partners is currently designated as the operator of substantially all of the underlying properties. MV Partners has contracted with two of its affiliates, Vess Oil and Murfin Drilling, to operate these properties on its behalf. Neither the trustee nor the public trust unitholders has any contractual ability to influence or control the field operations of, sale of oil and natural gas from, or future development of, these properties. The public trust unitholders also have no voting rights with respect to MV Partners and, therefore, have no managerial, contractual or other ability to influence MV Partners’ or its affiliates’ activities as operator of the oil and natural gas properties to which substantially all of the underlying properties relate. MV Partners may transfer all or a portion of the underlying properties at any time, subject to specified limitations, and MV Partners may abandon individual wells or properties that it reasonably believes to be uneconomic. Under these circumstances, trust unitholders have no ability to prevent MV Partners from transferring the underlying properties to another operator, even if the trust unitholders do not believe that operator would operate the underlying properties in the same manner as MV Partners. MV Partners may at any time transfer all or part of the underlying properties. Trust unitholders are not entitled to vote on any transfer of the underlying properties, and the trust will not receive any proceeds from any such transfer, except in the limited circumstances when the net profits interest is released in connection with such transfer, in which case the trust will receive an amount equal to the fair market value of the net profits interest released. See “Business — Description of the Underlying Properties — Sale and Abandonment of Underlying Properties.” Following any material sale or transfer of any of the underlying properties, such underlying properties will continue to be subject to the net profits interest of the trust, and the net proceeds attributable to the transferred property will be calculated as part of the computation of net proceeds described in this Form 10-K. MV Partners may delegate to the transferee responsibility for all of MV Partners’ obligations relating to the net profits interest on the portion of the underlying properties transferred. MV Partners or any transferee of the underlying properties may abandon any well or property if it reasonably believes that the well or property can no longer produce oil or natural gas in commercially economic quantities. This could result in termination of the net profits interest relating to the abandoned well or property. In making such decisions, MV Partners and any such transferee will be required under the applicable conveyance to act as a reasonably prudent operator in the State of Kansas under the same or similar circumstances would act if it were acting with respect to its own properties, disregarding the existence of the net profits interest as a burden on such property. The trustee may, under certain circumstances, sell the net profits interest and dissolve the trust prior to the expected termination of the trust. As a result, trust unitholders may not recover their investment. The trustee must sell the net profits interest if the holders of a majority of the trust units approve the sale or vote to dissolve the trust. The trustee must also sell the net profits interest if the annual cash proceeds from the underlying properties attributable to the net profits interest are less than $1.0 million for each of 34 TABLE OF CONTENTS any two consecutive years. The sale of the net profits interest will result in the dissolution of the trust. The net proceeds of any such sale will be distributed to the trust unitholders. Conflicts of interest could arise between MV Partners and the trust unitholders. The interests of MV Partners and the interests of the trust and the trust unitholders with respect to the underlying properties could at times differ. As a working interest owner in the underlying properties, MV Partners could have interests that conflict with the interests of the trust and the trust unitholders. For example: • MV Partners’ interests may conflict with those of the trust and the trust unitholders in situations involving the development, maintenance, operation or abandonment of the underlying properties. MV Partners may make decisions with respect to development expenditures that adversely affect the underlying properties. These decisions include reducing development expenditures on these properties, which could cause oil and natural gas production to decline at a faster rate and thereby result in lower cash distributions by the trust in the future, or increasing development expenditures on the underlying properties during the final years of the term of the trust, which expenditures will benefit the unitholders only to the extent that they reduce the natural decline in oil and natural gas production during the term of the trust by an amount that more than offsets the cost of these development expenditures. ​ • MV Partners may sell some or all of the underlying properties and such sale may not be in the best interests of the trust unitholders. In the event MV Partners sells all or any portion of the underlying properties, the purchaser of such underlying properties will acquire such underlying properties subject to the net profits interest relating thereto and, in connection therewith, such purchaser will be subject to the same standards of conduct with respect to development, operation and abandonment of such underlying properties as are imposed on MV Partners. MV Partners also has the right, subject to significant limitations as described herein, to cause the trust to release all or a portion of the net profits interest in connection with a sale of a portion of the underlying properties to which such net profits interest relates. In such an event, the trust is entitled to receive its proportionate share of the proceeds from the sale attributable to the net profits interest released. See “Business — Description of the Underlying Properties — Sale and Abandonment of Underlying Properties.” ​ In addition, affiliates of MV Partners may engage in activities whereby such affiliates could have interests that conflict with the interests of MV Partners, which could, depending on the circumstances, negatively impact MV Partners’ business. In making decisions with respect to the development, operation, abandonment or sale of the underlying properties, MV Partners and any successor operator will be required under the applicable conveyance to act as a reasonably prudent operator in the State of Kansas under the same or similar circumstances would act if it were acting with respect to its own properties, disregarding the existence of the net profits interest. Except for specified matters that require approval of the trust unitholders, the documents governing the trust do not provide a mechanism for resolving these conflicting interests. The trust is managed by a trustee who cannot be replaced except by a majority vote of the trust unitholders at a special meeting, which may make it difficult for trust unitholders to remove or replace the trustee. The business and affairs of the trust are managed by the trustee. The voting rights of a trust unitholder are more limited than those of stockholders of most public corporations. For example, there is no requirement for annual meetings of trust unitholders or for an annual or other periodic re-election of the trustee. The trust agreement provides that the trustee may only be removed and replaced by the holders of a majority of the outstanding trust units at a special meeting of trust unitholders called by either the trustee or the holders of not less than 10% of the outstanding trust units. MV Energy and VAP-I, LLC (“VAP-I”) collectively own 25% of the outstanding trust units. As a result, it will be difficult to remove or replace the trustee, particularly without the approval of the members of MV Partners. 35 TABLE OF CONTENTS Risks Related to Ownership of the Trust Units The disposal by the two members of MV Partners of their remaining trust units may reduce the market price of the trust units. As of the date of this Form 10-K, the two members of MV Partners, MV Energy and VAP-I, owned 25% of the outstanding trust units. The two members of MV Partners may use some or all of the remaining trust units they own for a number of corporate purposes, including: • selling them for cash; and ​ • exchanging them for interests in oil and natural gas properties or securities of oil and natural gas companies. ​ If they sell additional trust units or exchange trust units in connection with acquisitions, then additional trust units will be available for sale in the market. The sale of additional trust units may reduce the market price of the trust units. MV Partners and the trust have entered into a registration rights agreement pursuant to which the trust has agreed to file a registration statement or a shelf registration statement to register the resale of the remaining trust units held by MV Partners and any transferee of the trust units upon request by such holders. See “Item 13. Certain Relationships and Related Transactions, and Director Independence — Registration Rights.” The market price for the trust units may not reflect the value of the net profits interest held by the trust. The trading price for publicly traded securities similar to the trust units tends to be tied to recent and expected levels of cash distributions. The amounts available for distribution by the trust will vary in response to numerous factors outside the control of the trust, including prevailing prices for sales of oil, natural gas and natural gas liquid production from the underlying properties. Consequently, the market price for the trust units may not necessarily be indicative of the value that the trust would realize if it sold the net profits interest to a third-party buyer. In addition, such market price may not necessarily reflect the fact that since the assets of the trust are depleting assets, a portion of each cash distribution paid on the trust units should be considered by investors as a return of capital, with the remainder being considered as a return on investment. As a result, distributions made to a trust unitholder over the life of these depleting assets may not equal or exceed the purchase price paid by the trust unitholder. Trust unitholders have limited ability to enforce provisions of the net profits interest. The trust agreement permits the trustee to sue MV Partners or any other future owner of the underlying properties on behalf of the trust to enforce the terms of the conveyance creating the net profits interest. If the trustee does not take appropriate action to enforce provisions of the conveyance, recourse of the trust unitholders would be limited to bringing a lawsuit against the trustee to compel the trustee to take specified actions. The trust agreement expressly limits the trust unitholders’ ability to directly sue MV Partners or any other third party other than the trustee. As a result, the unitholders will not be able to sue MV Partners or any future owner of the underlying properties to enforce these rights. Courts outside of Delaware may not recognize the limited liability of the trust unitholders provided under Delaware law. Under the Delaware Statutory Trust Act, trust unitholders are entitled to the same limitation of personal liability extended to stockholders of private corporations under the General Corporation Law of the State of Delaware. Courts in jurisdictions outside of Delaware, however, may not give effect to such limitation. Legal, Environmental and Regulatory Risks The trust’s net profits interest may be characterized as an executory contract in bankruptcy, which could be rejected in bankruptcy, thus relieving MV Partners from its obligations to make payments to the trust with respect to the net profits interest. MV Partners has recorded the conveyance of the net profits interest in Kansas in the real property records in each Kansas county where the properties are located. MV Partners has informed the trustee that 36 TABLE OF CONTENTS MV Partners believes that the delivery and recording of the conveyance constitute fully conveyed and vested property interests in the trust under Kansas law. If in a bankruptcy proceeding in which MV Partners becomes involved as a debtor a determination were made that the conveyance constitutes an executory contract and the net profits interest is not a fully conveyed property interest under the laws of Kansas, and if such contract were not to be assumed in a bankruptcy proceeding involving MV Partners, the trust would be treated as an unsecured creditor of MV Partners with respect to such net profits interest in the pending bankruptcy proceeding. Oil and gas leases are real property interests under Colorado law. The net profits interest is a non-operating, non-possessory interest carved out of the oil and gas leasehold estate. MV Partners has informed the trustee that MV Partners believes that it is possible that the net profits interest for the underlying properties located in Colorado may not be treated as a real property interest under the laws of Colorado. MV Partners has recorded the conveyance of the net profits interest in the real property records of Colorado in accordance with local recording acts. MV Partners has informed the trustee that MV Partners believes that, if, during the term of the trust, MV Partners becomes involved as a debtor in a bankruptcy proceeding, the net profits interest relating to the underlying properties located in Colorado should be treated as a fully conveyed personal property interest under the laws of Colorado. In such a proceeding, however, a determination could be made that the conveyance constitutes an executory contract and the net profits interest is not a fully conveyed personal property interest under the laws of Colorado, and if such contract were not to be assumed in a bankruptcy proceeding involving MV Partners, the trust would be treated as an unsecured creditor of MV Partners with respect to such net profits interest in the pending bankruptcy proceeding. The operations of the underlying properties are subject to environmental laws and regulations and operational safety matters that may result in significant costs and liabilities, which could reduce the amount of cash available for distribution to trust unitholders. Significant costs and liabilities can be incurred as a result of environmental and safety requirements applicable to the oil and natural gas exploration, development and production activities of the underlying properties. These costs and liabilities could arise under a wide range of federal, state and local environmental and safety laws and regulations, including regulations and enforcement policies, which have tended to become increasingly strict over time. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of cleanup and site restoration costs and liens, and to a lesser extent, issuance of injunctions to limit or cease operations. In addition, claims for damages to persons or property may result from environmental and other impacts of the operations of the underlying properties. Strict, joint and several liability may be imposed under certain environmental laws, which could cause liability for the conduct of others or for the consequences of one’s own actions that were in compliance with all applicable laws at the time those actions were taken. New laws, regulations or enforcement policies could be more stringent and impose unforeseen liabilities or significantly increase compliance costs. If it were not possible to recover the resulting costs through insurance or increased revenues, this could have a material adverse effect on the cash distributions to the trust unitholders. Please read “Item 1. Business — Description of the Underlying Properties — Regulation — Environmental Matters and Regulation” for more information. Governmental authorities may enact climate change regulations that could increase MV Partners’ costs to operate and, therefore, adversely affect distributions to the trust unitholders. From time to time, the U.S. Congress has considered legislation directed at reducing greenhouse gas emissions. The EPA has proposed rules to regulate greenhouse gases and regional initiatives have formed to control greenhouse gases. Additionally, the states in which MV Partners operates may implement air pollution control regulations that are more stringent than existing and proposed federal regulations, in particular the regulation of emissions of greenhouse gases. The adoption of laws and regulations to implement controls of greenhouse gases, including the imposition of fees or taxes, could adversely affect MV Partners’ operations and, therefore, distributions to the trust unitholders. 37 TABLE OF CONTENTS Regulation of greenhouse gases and climate change could adversely affect trust distributions. Some scientific studies have suggested that emissions of certain gases, commonly referred to as greenhouse gases, including carbon dioxide and methane, may be contributing to the warming of the Earth’s atmosphere and other climatic changes. In response to such studies, the issue of climate change and the effect of greenhouse gas emissions, in particular emissions from fossil fuels, is attracting increasing attention worldwide. Legislative and regulatory measures to address concerns that emissions of greenhouse gases are contributing to climate change are in various phases of discussions or implementation at the international, national, regional and state levels. In response to findings that emissions of carbon dioxide, methane and other “greenhouse gases” present an endangerment to public health and the environment, the EPA has issued regulations to restrict emissions of greenhouse gases under existing provisions of the Clean Air Act. These regulations include limits on tailpipe emissions from motor vehicles and pre-construction and operating permit requirements for certain large stationary sources. The EPA also has adopted rules requiring the reporting of greenhouse gas emissions from specified large greenhouse gas emission sources in the United States, including certain onshore oil and natural gas production facilities, on an annual basis. Regulations promulgated under the Clean Air Act may require MV Partners to incur development expenses to install and utilize specific equipment, technologies, or work practices to control methane emissions from its operations. At the international level, the U.S. joined the international community at the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change in Paris, France, which resulted in an agreement intended to nationally determine their contributions and set greenhouse gas emission reduction goals every five years beginning in 2020. While the Agreement did not impose direct requirements on emitters, national plans to meet its pledge could have resulted in new regulatory requirements. The U.S. withdrew from the Paris Agreement effective on November 4, 2020, but formally rejoined the Paris Agreement in February 2021. The Trust cannot predict whether re-entry into the Paris Agreement or pledges made in connection therewith will result in new regulatory requirements or whether such requirements will cause MV Partners to incur material costs. In a separate executive order issued on January 20, 2021, President Biden asked the heads of all executive departments and agencies to review and take action to address any Federal regulations, orders, guidance documents, policies and any similar agency actions promulgated during the prior administration that may be inconsistent with or present obstacles to the administration’s stated goals of protecting public health and the environment, and conserving national monuments and refuges. The executive order also established an Interagency Working Group on the Social Cost of Greenhouse Gases, which is called on to, among other things, capture the full costs of greenhouse gas emissions, including the “social cost of carbon,” “social cost of nitrous oxide” and “social cost of methane,” which are “the monetized damages associated with incremental increased in greenhouse gas emissions,” including “changes in net agricultural productivity, human health, property damage from increased flood risk, and the value of ecosystem services.” Although it is not currently possible to predict how executive orders or any proposed or future state or federal greenhouse gas legislation or regulation will impact the business of MV Partners, any regulation of greenhouse gas emissions that may be imposed in areas in which MV Partners conduct business could result in increased compliance costs or additional operating restrictions or reduced demand for MV Partners’ production. Existing or future laws, regulations, treaties or international agreements related to greenhouse gases and climate change, including incentives to conserve energy or use alternative energy sources, could have a negative impact on the operations of the underlying properties and the trust if such laws, regulations, treaties or international agreements reduce the worldwide demand for oil and natural gas or otherwise result in reduced economic activity generally. In addition, such laws, regulations, treaties or international agreements could result in increased compliance costs or additional operating restrictions, which may have a negative impact on the operations of the underlying properties and the trust. In addition to potential impacts on the operations of the underlying properties and the trust directly or indirectly resulting from climate change legislation or regulations, the operations of the underlying properties and the trust also could be negatively affected by climate-change-related physical changes or changes in weather patterns. 38 TABLE OF CONTENTS The operations of the underlying properties are subject to complex federal, state, local and other laws and regulations that could adversely affect the cash distributions to the trust unitholders. The exploration, development and production operations of the underlying properties are subject to complex and stringent laws and regulations. In order to conduct its operations in compliance with these laws and regulations, MV Partners must obtain and maintain numerous permits, approvals and certificates from various federal, state and local governmental authorities. MV Partners may incur substantial costs and experience delays in order to maintain compliance with these existing laws and regulations, and the net profits interest will bear its share of these costs. In addition, the costs of compliance may increase or the operations of the underlying properties may be otherwise adversely affected if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to such operations. Such costs could have a material adverse effect on the cash distributions to the trust unitholders. Laws and regulations governing exploration and production may also affect production levels. MV Partners is required to comply with federal and state laws and regulations governing conservation matters, including: provisions related to the unitization or pooling of oil and natural gas properties; the establishment of maximum rates of production from wells; the spacing of wells; the plugging and abandonment of wells; and the removal of related production equipment. These and other laws and regulations can limit the amount of oil and natural gas MV Partners can produce from its wells, limit the number of wells it can drill, or limit the locations at which it can conduct drilling operations, which in turn could negatively impact trust distributions, estimated and actual future net revenues to the trust and estimates of reserves attributable to the trust’s interests. New laws or regulations, or changes to existing laws or regulations, may unfavorably impact MV Partners, could result in increased operating costs or have a material adverse effect on MV Partners’ financial condition and results of operations and reduce the amount of cash received by the trust. For example, Congress is currently considering legislation that, if adopted in its proposed form, would subject companies involved in oil and natural gas exploration and production activities to, among other items, additional regulation of and restrictions on hydraulic fracturing of wells, the elimination of certain U.S. federal tax incentives and deductions available to oil and natural gas exploration and production activities, and the prohibition or additional regulation of private energy commodity derivative and hedging activities. These and other potential regulations could increase the operating costs of the underlying properties, reduce MV Partners’ liquidity, delay MV Partners’ operations or otherwise alter the way MV Partners conducts its business, any of which could have a material adverse effect on the net profits interest and the trust’s cash flows. Tax Risks Related to the Trust Units The trust has not requested a ruling from the IRS regarding the tax treatment of ownership of the trust units or the tax treatment of the net profits interest. If the IRS were to determine (and be sustained in that determination) that the trust is not a grantor trust for federal income tax purposes, or that the net profits interest is not a debt instrument for federal income tax purposes, the trust unitholders may receive different and less advantageous tax treatment than that described in this Form 10-K. Tax counsel to MV Partners advised the trust at the time of formation that, for federal income tax purposes, in its opinion MV Partners will be treated as a grantor trust and not as an unincorporated business entity. Tax counsel to MV Partners also advised the trust at the time of formation that, for federal income tax purposes, based upon representations made by MV Partners regarding the expected economic life of the underlying properties and the expected duration of the net profits interest, in its opinion the net profits interest should be treated as a “production payment” under Section 636 of the Code or otherwise as a debt instrument. If the net profits interest were not treated as a debt instrument, or if the trust were not treated as a grantor trust, for federal income tax purposes, the tax treatment of tax items in respect of an investment in trust units may be affected. The effects of this different tax treatment may be less advantageous to trust unitholders. 39 TABLE OF CONTENTS ​ Neither MV Partners nor the trustee has requested a ruling from the IRS regarding these tax questions, and neither MV Partners nor the trust can assure the trust unitholders that such a ruling would be granted if requested or that the IRS will not challenge these positions on audit. See “Item 1. Business — Federal Income Tax Matters” for more information about the various matters described under this risk factor. Cybersecurity Risks Cyber-attacks or other failures in telecommunications or information technology systems could result in information theft, data corruption and significant disruption of MV Partners’ business operations. MV Partners relies on information technology (“IT”) systems and networks in connection with its business activities, including exploration, development and production activities. MV Partners relies on digital technology, including information systems and related infrastructure, as well as cloud applications and services, to, among other things, estimate quantities of oil and natural gas reserves, analyze seismic and drilling information, process and record financial and operating data and communicate with employees and third parties. As dependence on digital technologies has increased, cyber incidents, including deliberate attacks and attempts to gain unauthorized access to computer systems and networks, have increased in frequency and sophistication. These threats pose a risk to the security of MV Partners’ systems and networks, the confidentiality, availability and integrity of its data and the physical security of its employees and assets. MV Partners has experienced, and expects to continue to experience, attempts from hackers and other third parties to gain unauthorized access to its IT systems and networks. Although prior cyber-attacks have not had a material adverse effect on MV Partners’ operations or financial performance, MV Partners may not be successful in preventing cyber-attacks or mitigating their effect. Any cyber-attack could have a material adverse effect on MV Partners’ reputation, competitive position, business, financial condition and results of operations, and could have a material adverse effect on the trust. Cyber-attacks or security breaches also could result in litigation or regulatory action, as well as significant additional expense to MV Partners to implement further data protection measures. In addition to the risks presented to MV Partners’ systems and networks, cyber-attacks affecting oil and natural gas distribution systems maintained by third parties, or the networks and infrastructure on which they rely, could delay or prevent delivery to markets. A cyber-attack of this nature would be outside MV Partners’ ability to control but could have a material adverse effect on MV Partners’ business, financial condition and results of operations, and could have a material adverse effect on the trust. Cyber-attacks or other failures in telecommunications or IT systems could result in information theft, data corruption and significant disruption of the Trustee’s operations. The trustee depends heavily upon IT systems and networks in connection with its business activities. Despite a variety of security measures implemented by the trustee, events such as the loss or theft of back-up tapes or other data storage media could occur, and the trustee’s computer systems could be subject to physical and electronic break-ins, cyber-attacks and similar disruptions from unauthorized tampering, including threats that may come from external factors, such as governments, organized crime, hackers and third parties to whom certain functions are outsourced, or may originate internally from within the respective companies. If a cyber-attack were to occur, it could potentially jeopardize the confidential, proprietary and other information processed and stored in, and transmitted through, the trustee’s computer systems and networks, or otherwise cause interruptions or malfunctions in the operations of the trust, which could result in litigation, increased costs and regulatory penalties. Although steps are taken to prevent and detect such attacks, it is possible that a cyber incident will not be discovered for some time after it occurs, which could increase exposure to these consequences. Item 1B. Unresolved Staff Comments. ​ None. 40 TABLE OF CONTENTS ​ ​ ​ Item 2. Properties. ​ Reference is made to “Item 1 — Business” and “Item 7 — Trustee’s Discussion and Analysis of Financial Condition and Results of Operations — Planned Development and Workover Program,” which are incorporated herein by reference. Item 3. Legal Proceedings. ​ Currently, there are no legal proceedings pending to which the trust is a party or of which any of its property is the subject. Item 4. Mine Safety Disclosures. ​ None. 41 TABLE OF CONTENTS ​ ​ ​ PART II Item 5. Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities. ​ The trust units commenced trading on the New York Stock Exchange on January 19, 2007 under the symbol “MVO.” As of March 17, 2022, the 11,500,000 units outstanding were held by 10 unitholders of record. Each quarter, the trustee determines the amount of funds available for distribution to the trust unitholders. Available funds are the excess cash, if any, received by the trust from the net profits interest and other sources (such as interest earned on any amounts reserved by the trustee) that quarter, less the trust’s expenses for that quarter. Available funds are reduced by any cash that the trustee decides to hold as a reserve against future expenses. Quarterly cash distributions during the term of the trust are made by the trustee on or before the 25 th day of the month following the end of each quarter to the trust unitholders of record on the 15 th day of the month following the end of each quarter (or the next succeeding business day). Equity Compensation Plans The trust does not have any employees and, therefore, does not maintain any equity compensation plans. Recent Sales of Unregistered Securities There were no equity securities sold by the trust during the year ended December 31, 2021 that were not registered under the Securities Act of 1933, as amended, which we refer to herein as the “Securities Act.” Purchases of Equity Securities There were no purchases of trust units by the trust or any affiliated purchaser during the fourth quarter of the year ended December 31, 2021. Item 6. [Reserved] ​ Item 7. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations. ​ The following review of the trust’s financial condition and results of operations should be read in conjunction with the financial statements and notes thereto. The trust’s purpose is, in general, to hold the net profits interest, to distribute to the trust unitholders cash that the trust receives in respect of the net profits interest, and to perform certain administrative functions in respect of the net profits interest and the trust units. The trust derives substantially all of its income and cash flows from the net profits interest. Critical Accounting Policies The trust uses the modified cash basis of accounting to report receipts by the trust of the net profits interest and payments of expenses incurred. The net profits interest represents the right to receive revenues (oil, gas and natural liquid gas sales) less direct operating expenses (lease operating, maintenance and overhead expenses and production and property taxes) and an adjustment for lease equipment cost and lease development expenses (which are capitalized in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”)) of the underlying properties times 80%. Cash distributions of the trust will be made based on the amount of cash received by the trust pursuant to terms of the conveyance creating the net profits interest. The financial statements of the trust, as prepared on a modified cash basis, reflect the trust’s assets, trust corpus, earnings and distributions as follows: (a) Income from the net profits interest is recorded when distributions are received by the trust; ​ 42 TABLE OF CONTENTS (b) Distributions to trust unitholders are recorded when paid by the trust; ​ (c) Trust general and administrative expenses (which include the trustee’s fees as well as accounting, engineering, legal and other professional fees) are recorded when paid; ​ (d) Cash reserves for trust expenses may be established by the trustee for certain expenditures that would not be recorded as contingent liabilities under U.S. GAAP; ​ (e) Amortization of the investment in net profits interest, calculated using the units-of-production method based upon total estimated proved reserves, is charged directly to trust corpus and does not affect distributable income; and ​ (f) The trust evaluates its investment in the net profits interest periodically to determine whether its aggregate value has been impaired below its total capitalized cost based on the underlying properties. The trust will provide a write-down to its investment in the net profits interest if and when total capitalized costs, less accumulated amortization, exceed undiscounted future net cash flows attributable to the trust’s interests in the proved oil and gas reserves of the underlying properties. ​ While these statements differ from financial statements prepared in accordance with U.S. GAAP, the modified cash basis of reporting revenues and distributions is considered most meaningful because quarterly distributions to the trust unitholders are based on net cash receipts received from MV Partners. This comprehensive basis of accounting other than U.S. GAAP corresponds to the accounting permitted for royalty trusts by the SEC as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts. Comparison of Results of the Trust for the Years Ended December 31, 2021 and 2020 The following represents a discussion of the Comparison of Results of the Trust for the Years ended December 31, 2021 and 2020. Refer to “Item 7. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report on Form 10-K for the year ended December 31, 2020, filed with the SEC on March 16, 2021 for a discussion of the Comparison of Results of the Trust for the Years ended December 31, 2020 and 2019. Income for the trust from the net profits interest was $12.1 million for the year ended December 31, 2021 compared to $6.8 million for the year ended December 31, 2020. The trustee withheld $0.8 million and $1.2 million for future trust expenses for the years ended December 31, 2021 and 2020, respectively. General and administrative expense for the trust was $0.96 million for 2021 and $0.85 million for 2020. These factors resulted in distributable income of $11.3 million, or $0.985 per unit, in 2021 compared to $5.6 million, or $0.490 per unit, in 2020. The revenues from oil production are typically received by MV Partners one month after production; thus, the cash received by the trust during the year ended December 31, 2021 substantially represented the production by MV Partners from September 2020 through August 2021, and the cash received by the trust during the year ended December 31, 2020 substantially represented the production by MV Partners from September 2019 through August 2020. MV Partners computes net proceeds quarterly on a calendar basis and distributes to the trust 80% of the aggregate of such net proceeds attributable to a computation period on or before the 25th day of the month following the computation period. As a result, for the year ended December 31, 2021, the trust’s net profits interest represented the cash proceeds received by the trust, which was based upon the cash receipts for the oil and gas production collected by MV Partners from October 1, 2020 through September 30, 2021. For the year ended December 31, 2020, the trust’s net profits interest represented the cash proceeds received by the trust, which was based upon the cash receipts for the oil and gas production collected by MV Partners from October 1, 2019 through September 30, 2020. Excess of revenues over direct operating expenses and lease equipment and development costs from the underlying properties was $15.1 million for the period from October 1, 2020 through September 30, 2021. The trust’s net profits interest (80%) of this total was $12.1 million for the year ended December 31, 2021. During the year ended December 31, 2021, MV Partners did not withhold or release any dollar amounts due to the Trust from previously established cash reserves for future capital expenditures, which resulted in total cash proceeds received by the trust of $12.1 million for the year ended December 31, 2021. 43 TABLE OF CONTENTS Excess of revenues over direct operating expenses and lease equipment and development costs from the underlying properties was $8.5 million for the period from October 1, 2019 through September 30, 2020. The trust’s net profits interest (80%) of this total was $6.8 million for the year ended December 31, 2020. During the year ended December 31, 2020, MV Partners released $0.4 million during the third quarter and withheld $0.4 million during the fourth quarter from previously established cash reserves for future capital expenditures, which resulted in total cash proceeds received by the trust of $6.8 million for the year ended December 31, 2020. The average price received for crude oil sold during 2021 was $51.97 per Bbl, while the average price received for crude oil sold during 2020 was $41.44 per Bbl. The average price received for natural gas sold during 2021 was $2.22 per Mcf, while the average price received for natural gas sold during 2020 was $1.42 per Mcf. The average prices for 2021 related to production by MV Partners from September 2020 through August 2021, and the average prices for 2020 related to production by MV Partners from September 2019 through August 2020. The overall production volumes sold and delivered to purchasers attributable to the 80% net profits interest that was for the oil and gas production sold and delivered during the period from October 1, 2020 to September 30, 2021 were 519,518 Bbls of oil, 31,708 Mcf of natural gas and 94 Bbls of natural gas liquids, for a total of 524,864 Boe. The overall production volumes sold and delivered to purchasers attributable to the 80% net profits interest that was for the oil and gas production sold and delivered during the period from October 1, 2019 to September 30, 2020 were 530,915 Bbls of oil, 24,029 Mcf of natural gas and 239 Bbls of natural gas liquids, for a total of 535,075 Boe. As noted above, the amounts reflected in the accompanying financial statements for the trust’s year ended December 31, 2021 reflect cash received by the trust during the year. Such cash is primarily derived from production by MV Partners from September 2020 through August 2021. The amounts reflected in the accompanying financial statements for the trust’s year ended December 31, 2020 reflect cash received by the trust during the year. Such cash is primarily derived from production by MV Partners from September 2019 through August 2020. Liquidity and Capital Resources Other than trust administrative expenses, including any reserves established by the trustee for future liabilities, the trust’s only use of cash is for distributions to trust unitholders. Administrative expenses include payments to the trustee as well as an annual administrative fee to MV Partners pursuant to the administrative services agreement. Each quarter, the trustee determines the amount of funds available for distribution. Available funds are the excess cash, if any, received by the trust from the net profits interest and payments from other sources (such as interest earned on any amounts reserved by the trustee) in that quarter, over the trust’s expenses paid for that quarter. Available funds are reduced by any cash the trustee decides to hold as a reserve against future expenses. As of December 31, 2021, the trustee held $297,000 as such a reserve. In November 2021, the Trustee notified MV Partners that the Trustee intends to build a reserve for the payment of future known, anticipated or contingent expenses or liabilities, commencing with the distribution payable in the first quarter of 2022. The Trustee intends to withhold a portion of the proceeds otherwise available for distribution each quarter to gradually build a cash reserve to approximately $1.265 million. This amount is in addition to the letter of credit in the amount of $1.8 million provided to the Trustee by MV Partners to protect the Trust against the risk that it does not have sufficient cash to pay future expenses. The Trustee may increase or decrease the targeted amount at any time, and may increase or decrease the rate at which it is withholding funds to build the cash reserve at any time, without advance notice to the unitholders. Cash held in reserve will be invested as required by the Trust Agreement. Any cash reserved in excess of the amount necessary to pay or provide for the payment of future known, anticipated or contingent expenses or liabilities eventually will be distributed to unitholders, together with interest earned on the funds. The trustee may cause the trust to borrow funds required to pay expenses if the trustee determines that the cash on hand and the cash to be received are insufficient to cover the trust’s liabilities. If the trust borrows funds, the trust unitholders will not receive distributions until the borrowed funds are repaid. During each of 2020 and 2021, the trust made no borrowings. 44 TABLE OF CONTENTS Income to the trust from the net profits interest is based on the calculation and definitions of “gross proceeds” and “net proceeds” contained in the conveyance. As further discussed below, MV Partners’ development and workover program will require MV Partners to make future capital expenditures in connection with the development, exploration and production of oil and gas. Substantially all of the underlying properties are located in mature fields and MV Partners does not expect future costs for the underlying properties to change significantly as compared to recent historical costs other than increases due to increases in the general cost of oilfield services. The trust does not have any transactions, arrangements or other relationships with unconsolidated entities or persons that could materially affect the trust’s liquidity or the availability of capital resources. Planned Development and Workover Program Since acquiring the underlying properties in 1998 and 1999, MV Partners has implemented a development program on the underlying properties to develop further proved undeveloped reserves and to help offset the natural decline in production. These activities included recompletion of certain existing wells into new producing horizons, workovers of existing wells, and the drilling of infill development wells. The development program that MV Partners currently intends to implement over the five years ending December 31, 2026 with respect to the underlying properties categorized as proved undeveloped reserves consists of drilling development wells, recompletion and workover projects, and polymer workovers. The development program that MV Partners currently intends to implement over the next five years with respect to the underlying properties categorized as proved developed non-producing reserves consists of well-reactivation projects, injection well-workover projects, recompletion projects, and well-workover projects. MV Partners has undertaken 3-D seismic surveys covering several leases constituting a part of the underlying properties. These leases have over 20 undrilled offset locations of varying quality based on offset production and subsurface mapping. The 3-D data was utilized to refine the subsurface mapping with respect to the size of mapped sink holes and to define smaller structural features along the edges of the main formation reservoir. Using this data, MV Partners has scheduled the drilling of one proved undeveloped location over the five years ending December 31, 2026. MV Partners has expanded its 3-D seismic program into other fields constituting a part of the underlying properties. MV Partners expects total capital expenditures for the underlying properties during the five years ending December 31, 2026 will be approximately $1.3 million. Of this total, MV Partners contemplates spending approximately $0.4 million to drill development wells in project areas and approximately $0.9 million for recompletion and workovers of existing wells. MV Partners expects that these capital projects will add production that will partially offset the natural decline in production otherwise expected to occur with respect to the underlying properties. The trust is not directly obligated to pay any portion of any capital expenditures made with respect to the underlying properties; however, capital expenditures made by MV Partners with respect to the underlying properties will be deducted from the gross proceeds in calculating the net proceeds from which cash will be paid to the trust. As a result, the trust will indirectly bear an 80% (subject to certain limitations during the final three years of the trust, as described above under “Item 1. Business — Computation of Net Proceeds — Net Profits Interest”) share of any capital expenditures made with respect to the underlying properties. Accordingly, higher or lower capital expenditures will, in general, directly decrease or increase, respectively, the cash received by the trust in respect of its net profits interest, which will have a corresponding effect on cash available for distribution to unitholders. As the cash received by the trust in respect of the net profits interest will be reduced by the trust’s pro rata share of these capital expenditures, MV Partners expects that it will incur capital expenditures with respect to the underlying properties throughout the term of the trust on a basis that balances the impact of the capital expenditures on current cash distributions to the trust unitholders with the longer term benefits of increased oil and natural gas production expected to result from the capital expenditures. In addition, MV Partners may establish a capital reserve of up to $1.0 million in the aggregate at any given time to reduce the impact on distributions of uneven capital expenditure timing. MV Partners, as the operator of the underlying properties, is entitled to make all determinations related to capital expenditures with respect to the underlying properties, and there are no limitations on the 45 TABLE OF CONTENTS ​ amount of capital expenditures that MV Partners may incur with respect to the underlying properties, except as described above under “Item 1. Business — Computation of Net Proceeds — Net Profits Interest.” As the trust unitholders would not be expected to fully realize the benefits of capital expenditures made with respect to the underlying properties toward the end of the term of the trust, during each twelve-month period beginning on the later to occur of (1) June 30, 2023, and (2) the time when 13.2 MMBoe have been produced from the underlying properties and sold (which is the equivalent of 10.6 MMBoe in respect of the net profits interest), capital expenditures that may be taken into account in calculating net proceeds attributable to the net profits interest will be limited to the average annual capital expenditures during the preceding three years, as adjusted for inflation. See “Item 1. Business — Computation of Net Proceeds — Net Profits Interest.” Item 7A. Quantitative and Qualitative Disclosures About Market Risk. ​ The trust is a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and is not required to provide the information under this item. 46 TABLE OF CONTENTS ​ ​ Item 8. Financial Statements and Supplementary Data. ​ REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM Trustee and Unitholders MV Oil Trust Opinion on the financial statements We have audited the accompanying statements of assets and trust corpus of MV Oil Trust (the “Trust”) as of December 31, 2021 and 2020, the related statements of distributable income and changes in trust corpus for each of the three years in the period ended December 31, 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the assets and trust corpus of the Trust as of December 31, 2021 and 2020, and its distributable income and its changes in trust corpus for each of the three years in the period ended December 31, 2021, in conformity with the modified cash basis of accounting described in Note B to the financial statements. Basis of accounting We draw attention to Note B of the financial statements, which describes the basis of accounting. The financial statements are prepared on a modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America. Basis for opinion These financial statements are the responsibility of the Trustee. Our responsibility is to express an opinion on the Trust’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Trust in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Trust is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Trust’s internal control over financial reporting. Accordingly, we express no such opinion. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by the Trustee, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion. Critical audit matters Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the Trustee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters. /s/ Grant Thornton LLP We have served as the Trust’s auditor since 2006. Oklahoma City, Oklahoma March 17, 2022 47 TABLE OF CONTENTS ​ ​ ​ MV OIL TRUST STATEMENTS OF ASSETS AND TRUST CORPUS ​ ​ ​ December 31, ​ ​ ​ ​ 2020 ​ ​ 2021 ​ ASSETS ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Cash and cash equivalents ​ ​ ​ $ 504,571 ​ ​ ​ ​ $ 297,146 ​ ​ Investment in net profits interest ​ ​ ​ ​ 50,383,675 ​ ​ ​ ​ ​ 50,383,675 ​ ​ Accumulated amortization ​ ​ ​ ​ (40,304,938 ) ​ ​ ​ ​ ​ (42,771,353 ) ​ ​ Total assets ​ ​ ​ $ 10,583,308 ​ ​ ​ ​ $ 7,909,468 ​ ​ TRUST CORPUS ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Trust corpus, 11,500,000 Trust units issued and outstanding at December 31, 2020 and 2021 ​ ​ ​ $ 10,583,308 ​ ​ ​ ​ $ 7,909,468 ​ ​ STATEMENTS OF DISTRIBUTABLE INCOME ​ ​ ​ Year ended December 31, ​ ​ ​ ​ 2019 ​ ​ 2020 ​ ​ 2021 ​ Income from net profits interest ​ ​ ​ $ 12,994,052 ​ ​ ​ ​ $ 6,790,443 ​ ​ ​ ​ $ 12,078,886 ​ ​ Cash on hand used (withheld) for Trust expenses ​ ​ ​ ​ 54,135 ​ ​ ​ ​ ​ (302,835 ) ​ ​ ​ ​ ​ 207,425 ​ ​ General and administrative expense (1) ​ ​ ​ ​ (973,187 ) ​ ​ ​ ​ ​ (852,608 ) ​ ​ ​ ​ ​ (958,811 ) ​ ​ Distributable income ​ ​ ​ $ 12,075,000 ​ ​ ​ ​ $ 5,635,000 ​ ​ ​ ​ $ 11,327,500 ​ ​ Distributions per Trust unit (11,500,000 Trust units issued and outstanding for 2019, 2020 and 2021) ​ ​ ​ $ 1.050 ​ ​ ​ ​ $ 0.490 ​ ​ ​ ​ $ 0.985 ​ ​ ​ (1) Includes $98,944, $102,902 and $134,032 paid to MV Partners, LLC and $150,000, $150,000, and $150,000 paid to The Bank of New York Mellon Trust Company, N.A. for the years ended December 31, 2019, 2020 and 2021, respectively. ​ STATEMENTS OF CHANGES IN TRUST CORPUS ​ ​ ​ Year ended December 31, ​ ​ ​ ​ 2019 ​ ​ 2020 ​ ​ 2021 ​ Trust corpus, beginning of year ​ ​ ​ $ 14,706,311 ​ ​ ​ ​ $ 12,487,586 ​ ​ ​ ​ $ 10,583,308 ​ ​ Income from net profits interest ​ ​ ​ ​ 12,994,052 ​ ​ ​ ​ ​ 6,790,443 ​ ​ ​ ​ ​ 12,078,886 ​ ​ Cash distributions ​ ​ ​ ​ (12,075,000 ) ​ ​ ​ ​ ​ (5,635,000 ) ​ ​ ​ ​ ​ (11,327,500 ) ​ ​ Trust expenses ​ ​ ​ ​ (973,187 ) ​ ​ ​ ​ ​ (852,608 ) ​ ​ ​ ​ ​ (958,811 ) ​ ​ Amortization of net profits interest ​ ​ ​ ​ (2,164,590 ) ​ ​ ​ ​ ​ (2,207,113 ) ​ ​ ​ ​ ​ (2,466,415 ) ​ ​ Trust corpus, end of year ​ ​ ​ $ 12,487,586 ​ ​ ​ ​ $ 10,583,308 ​ ​ ​ ​ $ 7,909,468 ​ ​ The accompanying notes are an integral part of these financial statements. 48 TABLE OF CONTENTS ​ MV OIL TRUST NOTES TO FINANCIAL STATEMENTS NOTE A — ORGANIZATION OF THE TRUST MV Oil Trust (the “Trust”) is a statutory trust formed on August 3, 2006, under the Delaware Statutory Trust Act pursuant to a Trust Agreement (the “Trust Agreement”) among MV Partners, LLC (“MV Partners”), as trustor, The Bank of New York Mellon Trust Company, N.A., as Trustee (the “Trustee”), and Wilmington Trust Company, as Delaware Trustee (the “Delaware Trustee”). The Trust was created to acquire and hold a term net profits interest for the benefit of the Trust unitholders pursuant to a conveyance from MV Partners to the Trust. The term net profits interest is an interest in underlying properties consisting of MV Partners’ net interests in all of its oil and natural gas properties located in the Mid-Continent region in the states of Kansas and Colorado (the “underlying properties”). These oil and gas properties include approximately 860 producing oil and gas wells. The net profits interest is passive in nature, and the Trustee has no management control over and no responsibility relating to the operation of the underlying properties. The net profits interest entitles the Trust to receive 80% of the net proceeds attributable to MV Partners’ interest from the sale of production from the underlying properties during the term of the Trust. The net profits interest will terminate on the later to occur of (1) June 30, 2026 or (2) the time when 14.4 million barrels of oil equivalent (MMBoe) have been produced from the underlying properties and sold (which amount is the equivalent of 11.5 MMBoe with respect to the Trust’s 80% net profits interest), and the Trust will soon thereafter wind up its affairs and terminate. As of December 31, 2021, cumulatively, since inception, the Trust has received payment for 80% of the net proceeds attributable to MV Partners’ interest from the sale of 12.9 MMBoe of production from the underlying properties (which amount is the equivalent of 10.3 MMBoe with respect to the Trust’s net profits interest). The trust will dissolve prior to its termination if: (a) the trust sells the net profits interest; ​ (b) annual cash proceeds received by the trust are less than $1.0 million for each of two consecutive years; ​ (c) the holders of a majority of the outstanding trust units vote in favor of dissolution; or ​ (d) there is a judicial dissolution of the trust. ​ The Trustee can authorize the Trust to borrow money to pay Trust administrative or incidental expenses that exceed cash held by the Trust. The Trustee may authorize the Trust to borrow from the Trustee or the Delaware Trustee as a lender provided the terms of the loan are similar to the terms it would grant to a similarly situated commercial customer with whom it did not have a fiduciary relationship. The Trustee may also deposit funds awaiting distribution in an account with itself and make other short-term investments with the funds distributed to the Trust. NOTE B — TRUST ACCOUNTING POLICIES A summary of the significant accounting policies of the Trust follows. 1. Basis of accounting The Trust uses the modified cash basis of accounting to report receipts by the Trust of the net profits interest and payments of expenses incurred. The net profits interest represents the right to receive revenues (oil, gas and natural gas liquid sales) less direct operating expenses (lease operating, maintenance and overhead expenses and production and property taxes) and an adjustment for lease equipment cost and lease development expenses (which are capitalized in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”)) of the underlying properties times 80% (term net profits interest percentage). Actual cash receipts may vary due to timing delays of actual cash receipts from the property operators or purchasers and due to wellhead and pipeline volume 49 TABLE OF CONTENTS balancing agreements or practices. The actual cash distributions of the Trust will be made based on the terms of the conveyance creating the Trust’s net profits interest. The financial statements of the Trust, as prepared on a modified cash basis, reflect the Trust’s assets, Trust corpus, and distributable income as follows: (a) Income from net profits interest is recorded when distributions are received by the Trust; ​ (b) Distributions to Trust unitholders are recorded when paid by the Trust; ​ (c) Trust general and administrative expenses (which include the Trustee’s fees as well as accounting, engineering, legal and other professional fees) are recorded when paid; ​ (d) Cash reserves for Trust expenses may be established by the Trustee for certain expenditures that would not be recorded as contingent liabilities under U.S. GAAP; ​ (e) Amortization of the investment in Net Profits Interest, calculated using the units-of-production method based upon total estimated proved reserves, is charged directly to trust corpus and does not affect distributable income; and ​ (f) The Trust evaluates its investment in the net profits interest periodically to determine whether its aggregate value has been impaired below its total capitalized cost based on the underlying properties. The Trust will provide a write-down to its investment in the net profits interest if and when total capitalized costs, less accumulated amortization, exceed undiscounted net future cash flows attributable to the Trust’s interests in the proved oil and gas reserves of the underlying properties. ​ While these statements differ from financial statements prepared in accordance with U.S. GAAP, the modified cash basis of reporting income and distributions is considered most meaningful because quarterly distributions to the Trust unitholders are based on net cash receipts. This comprehensive basis of accounting other than generally accepted accounting principles corresponds to the accounting permitted for royalty trusts by the U.S. Securities and Exchange Commission (the “SEC”) as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts. No new accounting pronouncements have been adopted or issued during the year ended December 31, 2021 that would impact the financial statements of the Trust. 2. Cash equivalents For purposes of these statements, the Trust considers all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. 3. Use of estimates The preparation of financial statements requires estimates and assumptions that affect reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of income and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates affecting these financial statements include estimates of proved oil and gas reserves, which are used to compute the Trust’s amortization of net profits interest. 50 TABLE OF CONTENTS NOTE C — NET PROFITS INTEREST The net profits interest was recorded at the historical cost of MV Partners on January 24, 2007, the date of conveyance, and is calculated as follows: ​ Oil and gas properties ​ ​ ​ $ 96,210,819 ​ ​ ​ Accumulated depreciation and depletion ​ ​ ​ ​ (40,468,762 ) ​ ​ ​ Hedge asset ​ ​ ​ ​ 7,237,537 ​ ​ ​ Net property value to be conveyed ​ ​ ​ ​ 62,979,594 ​ ​ ​ Times 80% net profits interest to Trust ​ ​ ​ $ 50,383,675 ​ ​ NOTE D — INCOME FROM NET PROFITS INTEREST ​ ​ ​ Year ended December 31, ​ ​ ​ ​ 2019 ​ ​ 2020 ​ ​ 2021 ​ Excess of revenues over direct operating expenses and lease equipment and development costs (1) ​ ​ ​ $ 16,242,566 ​ ​ ​ ​ $ 8,488,053 ​ ​ ​ ​ $ 15,098,607 ​ ​ Times net profits interest over the term of the Trust ​ ​ ​ ​ 80 % ​ ​ ​ ​ ​ 80 % ​ ​ ​ ​ ​ 80 % ​ ​ Income from net profits interest before reserve adjustments ​ ​ ​ ​ 12,994,052 ​ ​ ​ ​ ​ 6,790,443 ​ ​ ​ ​ ​ 12,078,886 ​ ​ MV Partners reserve for future capital expenditures (2) ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ Income from net profits interest (3) ​ ​ ​ $ 12,994,052 ​ ​ ​ ​ $ 6,790,443 ​ ​ ​ ​ $ 12,078,886 ​ ​ ​ (1) Pursuant to the conveyance of the net profits interest, direct operating expenses, lease equipment and development costs are deducted when calculating the distributable income to the Trust. ​ (2) Pursuant to the conveyance of the net profits interest, MV Partners can reserve up to $1,000,000 for future exploration, development, maintenance or operating expenditures at any time. The reserve balance was $1,000,000 at December 31, 2019, 2020 and 2021, respectively. ​ (3) The income from net profits interest is based upon the cash receipts from MV Partners for the oil and gas production. The revenues from oil production are typically received one month after production; thus, the cash received by the Trust during the year ended December 31, 2019 substantially represents the production by MV Partners from September 2018 through August 2019 and the cash received by the Trust during the year ended December 31, 2020 substantially represents the production by MV Partners from September 2019 through August 2020 and the cash received by the Trust during the year ended December 31, 2021 substantially represents the production by MV Partners from September 2020 through August 2021. ​ For the years ended December 31, 2019, 2020 and 2021, MV Purchasing, LLC, which we refer to herein as “MV Purchasing,” purchased 75%, 73% and 73%, respectively, of the production sold from the underlying properties. MV Purchasing is majority owned by the indirect equity owners of MV Partners. Sales to MV Purchasing are under short-term arrangements, ranging from one to six months, using market sensitive pricing. NOTE E — INCOME TAXES Tax counsel to the Trust advised the Trust at the time of formation that, under then current tax laws, in its opinion the net profits interest should be treated as a debt instrument for federal income tax purposes, and the Trust should be required to treat a portion of each payment it receives with respect to the net profits interest as interest income in accordance with the “noncontingent bond method” under the original issue discount rules contained in the Internal Revenue Code of 1986, as amended, and the corresponding regulations. Tax counsel to the Trust also advised the Trust at the time of formation that in its opinion the Trust will be treated as a grantor trust for federal income tax purposes. On the basis of this advice, Trust 51 TABLE OF CONTENTS unitholders will be considered to own and receive the Trust’s assets and income and will be directly taxable thereon as if no trust were in existence. No provision for federal or state income taxes has been made in the accompanying statements. NOTE F — DISTRIBUTIONS TO UNITHOLDERS The Trustee determines for each quarter the amount available for distribution to the Trust unitholders. This distribution is expected to be made on or before the 25th day of the month following the end of each quarter to the Trust unitholders of record on the 15th day of the month following the end of each quarter (or the next succeeding business day). Such amounts will be equal to the excess, if any, of the cash received by the Trust relating to such preceding quarter, over the expenses of the Trust for such quarter, subject to adjustments for changes made by the Trustee during such quarter in any cash reserves established for future expenses of the Trust. In November 2021, the Trustee notified MV Partners that the Trustee intends to build a reserve for the payment of future known, anticipated or contingent expenses or liabilities, commencing with the distribution payable in the first quarter of 2022. The Trustee may increase or decrease the targeted amount at any time, and may increase or decrease the rate at which it is withholding funds to build the cash reserve at any time, without advance notice to the unitholders. Any cash reserved in excess of the amount necessary to pay or provide for the payment of future known, anticipated or contingent expenses or liabilities eventually will be distributed to unitholders, together with interest earned on the funds. Date paid ​ ​ Period covered ​ ​ Distribution per unit ​ ​ Reserve released (established) (1) ​ January 25, 2019 ​ ​ October 1, 2018 through December 31, 2018 ​ ​ ​ $ 0.315 ​ ​ ​ ​ $ — ​ ​ April 25, 2019 ​ ​ January 1, 2019 through March 31, 2019 ​ ​ ​ $ 0.215 ​ ​ ​ ​ ​ — ​ ​ July 25, 2019 ​ ​ April 1, 2019 through June 30, 2019 ​ ​ ​ $ 0.305 ​ ​ ​ ​ ​ — ​ ​ October 25, 2019 ​ ​ July 1, 2019 through September 30, 2019 ​ ​ ​ $ 0.215 ​ ​ ​ ​ ​ — ​ ​ January 24, 2020 ​ ​ October 1, 2019 through December 31, 2019 ​ ​ ​ $ 0.190 ​ ​ ​ ​ $ — ​ ​ April 24, 2020 ​ ​ January 1, 2020 through March 31, 2020 ​ ​ ​ $ 0.205 ​ ​ ​ ​ ​ — ​ ​ July 24, 2020 ​ ​ April 1, 2020 through June 30, 2020 ​ ​ ​ $ 0.000 (2) ​ ​ ​ ​ ​ 440,532 ​ ​ October 23, 2020 ​ ​ July 1, 2020 through September 30, 2020 ​ ​ ​ $ 0.095 ​ ​ ​ ​ ​ (440,532 ) ​ ​ January 25, 2021 ​ ​ October 1, 2020 through December 31, 2020 ​ ​ ​ $ 0.110 ​ ​ ​ ​ $ — ​ ​ April 23, 2021 ​ ​ January 1, 2021 through March 31, 2021 ​ ​ ​ $ 0.210 ​ ​ ​ ​ ​ — ​ ​ July 15, 2021 ​ ​ April 1, 2021 through June 30, 2021 ​ ​ ​ $ 0.300 ​ ​ ​ ​ ​ — ​ ​ October 25, 2021 ​ ​ July 1, 2021 through September 30, 2021 ​ ​ ​ $ 0.365 ​ ​ ​ ​ ​ — ​ ​ ​ (1) Pursuant to the conveyance of the net profits interest, MV Partners can reserve up to $1,000,000 for future exploration, development, maintenance or operating expenditures at any time. ​ (2) There was no quarterly distribution during the third quarter of 2020 to Trust unitholders, as the revenue collected by MV Partners from April 1, 2020 through June 30, 2020 was not sufficient to cover the costs paid during the period. MV Partners released $440,532 from the reserve for future expenditures to cover the deficit. The reserve was reestablished during the fourth quarter of 2020. ​ NOTE G — RELATED PARTY TRANSACTIONS The Trust has entered into an administrative services agreement with MV Partners that obligates the Trust, throughout the term of the Trust, to pay to MV Partners each quarter an administrative services fee for accounting, bookkeeping and informational services performed by MV Partners on behalf of the Trust relating to the net profits interest. The annual fee was a total of $99,904, $103,901 and $108,057 for 2019, 2020 and 2021, respectively, which will increase by 4% each year. The administrative services agreement will terminate upon the termination of the net profits interest unless earlier terminated by mutual agreement of the Trustee and MV Partners. 52 TABLE OF CONTENTS The Trust has entered into a Trust Agreement with the Trustee that obligates the Trust, throughout the term of the Trust, to pay to the Trustee a quarterly fee. The annual fee was a total of $150,000 for each of 2019, 2020 and 2021. In addition, the Trustee pays an annual fee of $2,500 to the Delaware trustee. The Trust Agreement will terminate upon the termination of the net profits interest unless earlier terminated by mutual agreement of a majority of the Trust unitholders. NOTE H — ADVANCE FOR TRUST EXPENSES Under the terms of the Trust Agreement, the Trustee is allowed to borrow money to pay Trust expenses. During 2019, 2020 and 2021, the Trust did not borrow any money, and there were no prior borrowings that had not been repaid. Since the Trust uses the modified cash basis of accounting, a liability has not been recorded for any advances from MV Partners. The net advance is shown as an addition to Trust Corpus when the borrowing is made and is shown as a reduction to Trust Corpus when it is repaid. MV Partners provided a letter of credit in the amount of $1.8 million to the Trustee to protect the Trust against the risk that it does not have sufficient cash to pay future expenses. In November 2021, the Trustee notified MV Partners that the Trustee intends to build a reserve for the payment of future known, anticipated or contingent expenses or liabilities, commencing with the distribution payable in the first quarter of 2022. The Trustee intends to withhold a portion of the proceeds otherwise available for distribution each quarter to gradually build a cash reserve to approximately $1.265 million. This amount is in addition to the letter of credit in the amount of $1.8 million provided to the Trustee by MV Partners to protect the Trust against the risk that it does not have sufficient cash to pay future expenses. The Trustee may increase or decrease the targeted amount at any time, without advance notice to the unitholders. Cash held in reserve will be invested as required by the Trust Agreement. NOTE I — OTHER EVENTS Subsequent event The first quarterly distribution for 2022 was $4,715,000, or $0.410 per Trust unit, and was made on January 25, 2022 to Trust unitholders owning Trust units as of January 14, 2022. Such distribution included the net proceeds of production collected by MV Partners from October 1, 2021 through December 31, 2021. The Trustee withheld $105,417 for future expenses from the distribution towards the building of its $1.265 million cash reserve. NOTE J — DISCLOSURES ABOUT OIL AND GAS ACTIVITIES (UNAUDITED) The Trust is required to disclose proved reserves in accordance with the SEC’s reporting rules, which require that the average, first-day-of-the-month price during the 12-month period before the end of the year be used when estimating whether reserve quantities are economical to produce. This same 12-month average price is also used in calculating the aggregate amount of (and changes in) future cash inflows related to the standardized measure of discounted future net cash flows. The rules also allow for the use of reliable technology to estimate proved oil and gas reserves if those technologies have been demonstrated to result in reliable conclusions about reserve volumes. The unaudited supplemental information on oil and gas exploration and production activities for 2019, 2020 and 2021 has been presented in accordance with these rules. Estimates of the proved oil and gas reserves attributable to the Trust as of December 31, 2019, 2020 and 2021 are based on reports of Cawley, Gillespie & Associates, Inc., independent petroleum and geological engineers, and the contract property management engineering staff of the managers of MV Partners who operate the underlying properties, in accordance with the SEC’s rules and definitions. Users of this information should be aware that the process of estimating quantities of “proved” and “proved developed” and “proved undeveloped” crude oil, natural gas, and natural gas liquids reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and continual reassessment 53 TABLE OF CONTENTS of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates occur from time to time. The reserve data below represent estimates only and should not be construed as being exact. Moreover, the discounted values should not be construed as representative of the current market value of the Net Profits Interest. A market value determination would include many additional factors, including: (i) anticipated future oil and gas prices; (ii) the effect of federal income taxes, if any, on the Trust; (iii) an allowance for return on investment; (iv) the effect of governmental legislation; (v) the value of additional potential reserves, not considered proved at present, which may be recovered as a result of further exploration and development activities; and (vi) other business risks. The following tables set forth (i) the estimated net quantities of proved, proved developed and proved undeveloped oil, natural gas and natural gas liquids reserves attributable to the Trust, and (ii) the standardized measure of the discounted future net profits interest income attributable to the Trust and the nature of changes in such standardized measure between years. These tables are prepared on the accrual basis, which is the basis on which MV Partners maintains its production records and is different from the basis on which the Trust is reporting. ESTIMATED QUANTITIES OF OIL AND GAS RESERVES ​ ​ ​ Oil (Bbls) ​ ​ Gas (Mcf) ​ ​ NGL (Bbls) ​ ​ Total (Boe) ​ Proved reserves ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Balance at December 31, 2018 ​ ​ ​ ​ 3,660,804 ​ ​ ​ ​ ​ 163,233 ​ ​ ​ ​ ​ 4,784 ​ ​ ​ ​ ​ 3,691,119 ​ ​ Revisions of previous estimates ​ ​ ​ ​ (92,603 ) ​ ​ ​ ​ ​ (53,659 ) ​ ​ ​ ​ ​ (2,519 ) ​ ​ ​ ​ ​ (103,183 ) ​ ​ Production ​ ​ ​ ​ (572,582 ) ​ ​ ​ ​ ​ (26,336 ) ​ ​ ​ ​ ​ (295 ) ​ ​ ​ ​ ​ (577,163 ) ​ ​ Balance at December 31, 2019 ​ ​ ​ ​ 2,995,619 ​ ​ ​ ​ ​ 83,238 ​ ​ ​ ​ ​ 1,970 ​ ​ ​ ​ ​ 3,010,773 ​ ​ Revisions of previous estimates ​ ​ ​ ​ (675,943 ) ​ ​ ​ ​ ​ (39,480 ) ​ ​ ​ ​ ​ (1,207 ) ​ ​ ​ ​ ​ (683,308 ) ​ ​ Production ​ ​ ​ ​ (518,734 ) ​ ​ ​ ​ ​ (25,362 ) ​ ​ ​ ​ ​ (109 ) ​ ​ ​ ​ ​ (523,031 ) ​ ​ Balance at December 31, 2020 ​ ​ ​ ​ 1,800,942 ​ ​ ​ ​ ​ 18,396 ​ ​ ​ ​ ​ 654 ​ ​ ​ ​ ​ 1,804,434 ​ ​ Revisions of previous estimates ​ ​ ​ ​ 661,281 ​ ​ ​ ​ ​ 101,055 ​ ​ ​ ​ ​ (247 ) ​ ​ ​ ​ ​ 677,963 ​ ​ Production ​ ​ ​ ​ (514,745 ) ​ ​ ​ ​ ​ (32,916 ) ​ ​ ​ ​ ​ (88 ) ​ ​ ​ ​ ​ (520,289 ) ​ ​ Balance at December 31, 2021 ​ ​ ​ ​ 1,947,478 ​ ​ ​ ​ ​ 86,535 ​ ​ ​ ​ ​ 319 ​ ​ ​ ​ ​ 1,962,108 ​ ​ Proved developed reserves ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ ​ ​ ​ 3,202,010 ​ ​ ​ ​ ​ 163,233 ​ ​ ​ ​ ​ 4,784 ​ ​ ​ ​ ​ 3,232,325 ​ ​ December 31, 2019 ​ ​ ​ ​ 2,687,298 ​ ​ ​ ​ ​ 83,238 ​ ​ ​ ​ ​ 1,970 ​ ​ ​ ​ ​ 2,702,451 ​ ​ December 31, 2020 ​ ​ ​ ​ 1,641,394 ​ ​ ​ ​ ​ 18,396 ​ ​ ​ ​ ​ 654 ​ ​ ​ ​ ​ 1,644,886 ​ ​ December 31, 2021 ​ ​ ​ ​ 1,860,861 ​ ​ ​ ​ ​ 86,535 ​ ​ ​ ​ ​ 319 ​ ​ ​ ​ ​ 1,875,491 ​ ​ Proved undeveloped reserves ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2018 ​ ​ ​ ​ 458,794 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 458,794 ​ ​ Proved undeveloped reserves converted to proved developed reserves by drilling ​ ​ ​ ​ (177,697 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (177,697 ) ​ ​ Additional proved undeveloped reserves added during 2019 ​ ​ ​ ​ 27,366 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 27,366 ​ ​ Proved undeveloped reserves removed from drilling plan ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ Revisions of previous estimates ​ ​ ​ ​ (142 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (142 ) ​ ​ December 31, 2019 ​ ​ ​ ​ 308,322 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 308,322 ​ ​ Proved undeveloped reserves converted to proved developed reserves by drilling ​ ​ ​ ​ (27,049 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (27,049 ) ​ ​ 54 TABLE OF CONTENTS ​ ​ ​ Oil (Bbls) ​ ​ Gas (Mcf) ​ ​ NGL (Bbls) ​ ​ Total (Boe) ​ Additional proved undeveloped reserves added during 2020 ​ ​ ​ ​ 8,186 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 8,186 ​ ​ Proved undeveloped reserves removed from drilling plan ​ ​ ​ ​ (120,650 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (120,650 ) ​ ​ Revisions of previous estimates ​ ​ ​ ​ (9,260 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (9,260 ) ​ ​ December 31, 2020 ​ ​ ​ ​ 159,548 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 159,548 ​ ​ Proved undeveloped reserves converted to proved developed reserves by drilling ​ ​ ​ ​ (68,621 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (68,621 ) ​ ​ Additional proved undeveloped reserves added during 2021 ​ ​ ​ ​ 9,981 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 9,981 ​ ​ Proved undeveloped reserves removed from drilling plan ​ ​ ​ ​ (14,294 ) ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ (14,294 ) ​ ​ Revisions of previous estimates ​ ​ ​ ​ 3 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 3 ​ ​ December 31, 2021 ​ ​ ​ ​ 86,617 ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ — ​ ​ ​ ​ ​ 86,617 ​ ​ ​ The Trust recognized net reductions to reserves for its share of MV Partners’ total during 2019 associated with the production of properties of 577,163 Boe. The Trust recognized net increases to reserves of 27,366 Boe as a result of changes in the development plan. Additional reductions to reserves of 130,549 Boe were a result of negative revisions due to lower commodity prices during 2019. The Trust recognized net reductions to reserves for its share of MV Partners’ total during 2020 associated with the production of properties of 523,031 Boe. The Trust recognized net decreases to reserves of 112,464 Boe as a result of changes in the development plan. Additional reductions to reserves of 570,844 Boe were a result of negative revisions due to lower commodity prices during 2020. The Trust recognized net reductions to reserves for its share of MV Partners’ total during 2021 associated with the production of properties of 520,289 Boe. The Trust recognized net decreases to reserves of (4,313) Boe as a result of changes in the development plan. Additional increases to reserves of 682,276 Boe were a result of positive revisions due to higher commodity prices during 2021. 55 TABLE OF CONTENTS ​ ​ STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS FROM PROVED OIL AND GAS RESERVES Estimates of future net cash flows from proved reserves of crude oil, natural gas, and natural gas liquids are computed using the average, first-day-of-the-month price during the 12-month period for 2019, 2020 and 2021. ​ ​ ​ 2019 ​ ​ 2020 ​ ​ 2021 ​ Future cash inflows ​ ​ ​ $ 153,422,338 ​ ​ ​ ​ $ 63,107,344 ​ ​ ​ ​ $ 121,119,425 ​ ​ Future costs ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Production ​ ​ ​ ​ (86,214,240 ) ​ ​ ​ ​ ​ (44,907,531 ) ​ ​ ​ ​ ​ (65,037,972 ) ​ ​ Development ​ ​ ​ ​ (4,195,800 ) ​ ​ ​ ​ ​ (2,237,200 ) ​ ​ ​ ​ ​ (1,442,500 ) ​ ​ Future net cash flows ​ ​ ​ ​ 63,012,298 ​ ​ ​ ​ ​ 15,962,613 ​ ​ ​ ​ ​ 54,638,953 ​ ​ Less 10% discount factor ​ ​ ​ ​ (14,613,176 ) ​ ​ ​ ​ ​ (3,141,451 ) ​ ​ ​ ​ ​ (9,376,987 ) ​ ​ Standardized measure of discounted future net cash flows ​ ​ ​ $ 48,399,122 ​ ​ ​ ​ $ 12,821,162 ​ ​ ​ ​ $ 45,261,966 ​ ​ CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS FROM PROVED OIL AND GAS RESERVES ​ ​ ​ 2019 ​ ​ 2020 ​ ​ 2021 ​ Standardized measure at beginning of year ​ ​ ​ $ 79,924,544 ​ ​ ​ ​ $ 48,399,122 ​ ​ ​ ​ $ 12,821,162 ​ ​ Net proceeds to the Trust ​ ​ ​ ​ (12,994,052 ) ​ ​ ​ ​ ​ (6,790,443 ) ​ ​ ​ ​ ​ (12,078,886 ) ​ ​ Net changes in price and production costs ​ ​ ​ ​ (24,930,850 ) ​ ​ ​ ​ ​ (29,767,790 ) ​ ​ ​ ​ ​ 28,017,592 ​ ​ Changes in estimated future development costs ​ ​ ​ ​ (491,282 ) ​ ​ ​ ​ ​ 1,385,798 ​ ​ ​ ​ ​ (289,926 ) ​ ​ Development costs incurred during the year ​ ​ ​ ​ 2,022,434 ​ ​ ​ ​ ​ 284,000 ​ ​ ​ ​ ​ 1,002,600 ​ ​ Revisions of quantity estimates ​ ​ ​ ​ (1,517,858 ) ​ ​ ​ ​ ​ (5,317,854 ) ​ ​ ​ ​ ​ 15,737,944 ​ ​ Accretion of discount ​ ​ ​ ​ 7,992,454 ​ ​ ​ ​ ​ 4,839,912 ​ ​ ​ ​ ​ 1,282,116 ​ ​ Changes in production rates, timing and other (1) ​ ​ ​ ​ (1,606,434 ) ​ ​ ​ ​ ​ (211,583 ) ​ ​ ​ ​ ​ (1,230,636 ) ​ ​ Standardized measure at end of year ​ ​ ​ $ 48,399,122 ​ ​ ​ ​ $ 12,821,162 ​ ​ ​ ​ $ 45,261,966 ​ ​ ​ (1) The Trust’s changes in standardized measure of discounted future net cash flows attributable to production rates, timing and other primarily represents changes in the Trust’s estimates of when proved reserve quantities will be realized. During the years ended December 31, 2019, 2020 and 2021, the operator changed its development drilling capital plans, which had the effect of altering the estimated timing of development and then the ultimate realization of undeveloped proved reserves. ​ The average, first-day-of-the-month price during the 12-month period for 2019, 2020 and 2021 used in determining future net revenues related to the standardized measure calculation are as follows: ​ ​ ​ 2019 ​ ​ 2020 ​ ​ 2021 ​ Oil (per Bbl) ​ ​ ​ $ 51.14 ​ ​ ​ ​ $ 35.02 ​ ​ ​ ​ $ 62.06 ​ ​ Gas (per Mcf) ​ ​ ​ $ 2.12 ​ ​ ​ ​ $ 1.64 ​ ​ ​ ​ $ 2.91 ​ ​ NGL (per Bbl) ​ ​ ​ $ 25.51 ​ ​ ​ ​ $ 12.62 ​ ​ ​ ​ $ 21.23 ​ ​ Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure. None.