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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-K

(Mark One)

☒

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

For the fiscal year ended December 31, 2021

☐

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

For the transition period from to

Commission file number 001-35160

VOC ENERGY TRUST

(Exact name of registrant as specified in its charter)

	Delaware			80-6183103
	(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)
	The Bank of New York Mellon Trust Company, N.A., Trustee Global Corporate Trust 601 Travis Street, Floor 16 Houston, Texas			77002
	(Address of principal executive offices)			(Zip Code)

Registrant’s telephone number, including area code: (713) 483-6020

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

	Title of each class			Trading Symbol(s)			Name of each exchange on which registered
	Units of Beneficial Interest			VOC			New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☐ No ☒

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐ No ☒

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

Indicate by checkmark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☐ No ☐

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

Large accelerated filer

☐

Accelerated filer

☐

Non-accelerated filer

☒

Smaller reporting company ☒

Emerging growth company ☐

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

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐

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

The aggregate market value of the 12,747,750 Units of Beneficial Interest in VOC Energy Trust held by non-affiliates of the registrant, computed using the closing sales price of $4.73 on June 30, 2021, was approximately $60,296,858.

As of March 17, 2022, 17,000,000 Units of Beneficial Interest in VOC Energy Trust were outstanding.

DOCUMENTS INCORPORATED BY REFERENCE: None

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			Page
FORWARD LOOKING STATEMENTS			1
GLOSSARY OF CERTAIN OIL AND NATURAL GAS TERMS			2
PART I			6
Item 1. Business			6
Item 1A. Risk Factors			29
Item 1B. Unresolved Staff Comments			43
Item 2. Properties			43
Item 3. Legal Proceedings			43
Item 4. Mine Safety Disclosures			43
PART II			44
Item 5. Market for Registrant’s Common Equity, Related Unitholder Matters and Issuer Purchases of Equity Securities			44
Item 6. [Reserved]			44
Item 7. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations			44
Item 7A. Quantitative and Qualitative Disclosures About Market Risk			50
Item 8. Financial Statements and Supplementary Data			51
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure			63
Item 9A. Controls and Procedures			63
Item 9B. Other Information			64
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections			64
PART III			65
Item 10. Directors, Executive Officers and Corporate Governance			65
Item 11. Executive Compensation			65
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters			65
Item 13. Certain Relationships and Related Transactions, and Director Independence			66
Item 14. Principal Accountant Fees and Services			67
PART IV			68
Item 15. Exhibit and Financial Statement Schedules			68
Item 16. Form 10-K Summary			69
SIGNATURES			70

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FORWARD LOOKING STATEMENTS

This Annual Report on Form 10-K, which we refer to as this “Form 10-K,” contains forward looking statements about VOC Brazos Energy Partners, L.P., a Texas limited partnership, which we refer to as “VOC Brazos,” and VOC Energy Trust, which we refer to herein as the “trust,” that are subject to risks and uncertainties and that are intended to qualify for the safe harbors from liability established by the Private Securities Litigation Reform Act of 1995 and Section 21E of the Securities Exchange Act of 1934, as amended, which we refer to as the “Exchange Act”. All statements other than statements of historical fact included in this document, including, without limitation, statements under “Business” and “Risk Factors” regarding the financial position, business strategy, production and reserve growth, and other plans and objectives for the future operations of VOC Brazos and the trust, are forward-looking statements. Such statements may be influenced by factors that could cause actual outcomes and results to differ materially from those projected. Forward-looking statements are subject to risks and uncertainties and include statements pertaining to future development activities and costs and other statements in this Form 10-K that are prospective and constitute forward-looking statements.

When used in this document, the words “believes,” “expects,” “anticipates,” “intends” or similar expressions are intended to identify such forward-looking statements. The following important factors, in addition to those discussed elsewhere in this Form 10-K, could affect the future results of the energy industry in general, and VOC Brazos and the trust in particular, and could cause actual results to differ materially from those expressed in such forward looking statements:

•

risks incident to the drilling and operation of oil and natural gas wells;

•

future production and development costs and plans;

•

the effect, impact, potential duration or other implications of the novel strain of coronavirus (“COVID-19”) pandemic;

•

the actions of the Organization of Petroleum Exporting Countries (“OPEC”);

•

the effect of existing and future laws and regulatory actions;

•

the effect of changes in commodity prices and conditions in the capital markets;

•

competition from others in the energy industry;

•

economic uncertainty and the credit markets generally;

•

ability of commodity purchasers to make payment;

•

weather conditions or force majeure events;

•

uncertainty of estimates of oil and natural gas reserves and production; and

•

inflation.

This Form 10-K describes other important factors that could cause actual results to differ materially from expectations of VOC Brazos and the trust, including under the heading “Risk Factors.” All written and oral forward-looking statements attributable to VOC Brazos or the trust or persons acting on behalf of VOC Brazos or the trust are expressly qualified in their entirety by such factors.

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GLOSSARY OF CERTAIN OIL AND NATURAL GAS TERMS

In this Form 10-K the following terms have the meanings specified below.

Bbl — One stock tank barrel, or 42 U.S. gallons liquid volume, of crude oil or other liquid hydrocarbons.

Boe — One stock tank barrel of oil equivalent, computed on an approximate energy equivalent basis that one Bbl of crude oil equals six Mcf of natural gas and one Bbl of crude oil equals 1.54 Bbls of natural gas liquids.

Btu or British Thermal Unit — The quantity of heat required to raise the temperature of one pound of water one degree Fahrenheit.

Completion — The installation of permanent equipment for the production of oil or natural gas, or, in the case of a dry well, the reporting to the appropriate authority that the well has been abandoned.

Developed Acreage — The number of acres that are allocated or assignable to productive wells or wells capable of production.

Development Well — A well drilled within the proved area of an oil or natural gas reservoir to the depth of a stratigraphic horizon known to be productive.

DUCs — Drilled but uncompleted. A well that has been drilled but has not undergone the final steps of perforating/acidizing or hydraulic fracturing and procedures necessary to place the well on production.

Estimated Future Net Revenues — Also referred to as “estimated future net cash flows.” The result of applying current prices of oil and natural gas to estimated future production from oil and natural gas proved reserves, reduced by estimated future expenditures, based on current costs to be incurred, in developing and producing the proved reserves.

Field — An area consisting of a single reservoir or multiple reservoirs all grouped on or related to the same individual geological structural feature and/or stratigraphic condition. There may be two or more reservoirs in a field that are separated vertically by intervening impervious, strata, or laterally by local geologic barriers, or by both. Reservoirs that are associated by being in overlapping or adjacent fields may be treated as a single or common operational field. The geological terms structural feature and stratigraphic condition are intended to identify localized geological features as opposed to the broader terms of basins, trends, provinces, plays, areas-of-interest, etc.

Gross Acres or Gross Wells — The total acres or wells, as the case may be, in which a working interest is owned.

Henry Hub — A distribution hub on the natural gas pipeline system in Erath, Louisiana. It is the pricing point for natural gas futures contracts traded on the New York Mercantile Exchange and the over the counter swaps traded on the Intercontinental Exchange, Spot and future natural gas prices set at Henry Hub are denominated in USD per MMBtu.

MBbl — One thousand barrels of crude oil or other liquid hydrocarbons.

MBoe — One thousand barrels of oil equivalent.

Mcf — One thousand standard cubic feet of natural gas. For purposes of this Form 10-K, references to Mcf include an insignificant amount of natural gas liquid measurement.

MMBbls — One million barrels of crude oil or other liquid hydrocarbons.

MMBoe — One million barrels of oil equivalent.

MMBtu — One million British Thermal Units.

MMcf — One million standard cubic feet of natural gas. For purposes of this Form 10-K, references to MMcf include an insignificant amount of natural gas liquid measurement.

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Net Acres or Net Wells — The sum of the fractional working interests owned in gross acres or wells, respectively.

Net Profits Interest — A nonoperating interest that creates a share in gross production from an operating or working interest in oil and natural gas properties. The share is measured by net profits from the sale of production after deducting costs associated with that production.

Net Revenue Interest — An interest in all oil and natural gas produced and saved from, or attributable to, a particular property, net of all royalties, overriding royalties, net profits interests, carried interests, reversionary interests and any other burdens to which the person’s interest is subject.

NYMEX — New York Mercantile Exchange.

Plugging and Abandonment — Activities to remove production equipment and seal off a well at the end of a well’s economic life.

Proved Developed Non-Producing Reserves — Proved developed reserves expected to be recovered from zones behind casing in existing wells.

Proved Developed Oil and Gas Reserves — Proved Oil and Gas Reserves that can be expected to be recovered:

(A)

through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and

(B)

through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well.

Proved Developed Producing Reserves — Proved developed reserves that are expected to be recovered from completion intervals currently open in existing wells and capable of production to market.

Proved Oil and Gas Reserves — Those quantities of oil and gas that, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible — from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations — prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

(A)

The area of a reservoir considered as proved includes: (i) the area identified by drilling and limited by fluid contacts, if any, and (ii) adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data.

(B)

In the absence of data on fluid contacts, proved quantities in the reservoir are limited by the lowest known hydrocarbons, as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty.

(C)

Where direct observation from well penetrations has defined a highest known oil elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty.

(D)

Reserves that can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when (i) successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based and (ii) the project has been approved for development by all necessary parties and entities, including governmental entities.

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(E)

Existing economic conditions include prices and costs at which economic producibility from a reservoir is determined. The price is the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

Proved Undeveloped Oil and Gas Reserves — Proved Oil and Gas Reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion.

(A)

Reserves on undrilled acreage are limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances.

(B)

Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time.

(C)

Under no circumstances are estimates for undeveloped reserves to be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir or by other evidence using reliable technology establishing reasonable certainty.

PV-10 — The present value of estimated future net revenues using a discount rate of 10% per annum.

Recompletion — The process of re-entering an existing wellbore that is either producing or not producing and completing new reservoirs in an attempt to establish or increase existing production.

Reservoir — A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.

Standardized Measure of Discounted Future Net Cash Flows — Also referred to herein as “standardized measure.” It is the present value of estimated future net revenues computed by discounting estimated future net revenues at a rate of 10% annually.

The Financial Accounting Standards Board requires disclosure of standardized measure of discounted future net cash flows relating to proved oil and gas reserve quantities per accounting literature for extractive activities — oil and gas, as follows: A standardized measure of discounted future net cash flows relating to an enterprise’s interests in (a) proved oil and gas reserves and (b) oil and gas subject to purchase under long-term supply, purchase, or similar agreements and contracts in which the enterprise participates in the operation of the properties on which the oil or gas is located or otherwise serves as the producer of those reserves shall be disclosed as of the end of the year. The standardized measure of discounted future net cash flows relating to those two types of interests in reserves may be combined for reporting purposes. The following information shall be disclosed in the aggregate and for each geographic area for which reserve quantities are disclosed:

Future cash inflows. These shall be computed by the average of the first-day-of-the-month prices during the 12-month period preceding the end of the year for 2019, 2020 and 2021 of oil and gas relating to the enterprise’s proved reserves to the year-end quantities of those reserves. Future price changes shall be considered only to the extent provided by contractual arrangements in existence at year-end.

Future development and production costs. These costs shall be computed by estimating the expenditures to be incurred in developing and producing the proved oil and gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions. If estimated development expenditures are significant, they shall be presented separately from estimated production costs.

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Future income tax expenses. These expenses shall be computed by applying the appropriate year-end statutory tax rates, with consideration of future tax rates already legislated, to the future pretax net cash flows relating to the enterprise’s proved oil and gas reserves, less the tax basis of the properties involved. The future income tax expenses shall give effect to tax deductions, tax credits and allowances relating to the enterprise’s proved oil and gas reserves.

Future net cash flows. These amounts are the result of subtracting future development and production costs and future income tax expenses from future cash inflows.

Discount. This amount shall be derived from using a discount rate of 10 percent a year to reflect the timing of the future net cash flows relating to proved oil and gas reserves.

Standardized measure of discounted future net cash flows. This amount is the future net cash flows less the computed discount.

Working Interest — Also called an operating interest. The right granted to the lessee of a property to explore for and to produce and own oil, gas or other minerals. The working interest owner bears the exploration, development and operating costs on either a cash, penalty or carried basis.

Workover — Operations on a producing well to restore or increase production.

WTI Cushing — West Texas Intermediate, a type of crude oil used as a benchmark in oil pricing and the underlying commodity of the New York Mercantile Exchange’s oil future contracts for delivery at Cushing, Oklahoma.

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PART I

Item 1. Business.

General

VOC Energy Trust, which we refer to as the “trust,” was formed in November 2010 by VOC Brazos Energy Partners, L.P., which we refer to as “VOC Brazos.” Much of the information disclosed herein has been provided to the trust by VOC Brazos, including information associated with the underlying properties such as production and well counts, major producing areas, customer relationships, competition, marketing and post-production services, and certain information on which reserve data is based.

The trust is a statutory trust created under the Delaware Statutory Trust Act. The business and affairs of the trust are managed by The Bank of New York Mellon Trust Company, N.A., as trustee. The trust maintains its offices at the office of the trustee, at 601 Travis Street, Floor 16, Houston, Texas 77002. The telephone number of the trustee is 1-855-802-1094. In addition, Wilmington Trust Company acts as the Delaware trustee of the trust. The Delaware trustee has only minimal rights and duties as are necessary to satisfy the requirements of the Delaware Statutory Trust Act. The trust does not have any employees, and the business and affairs of the trust are managed by the trustee.

The trustee does not maintain a website for filings by the trust with the Securities and Exchange Commission, which we refer to as the “SEC.” Electronic filings by the trust with the SEC are available free of charge through the SEC’s website at www.sec.gov and at http://voc.q4web.com/home/default.aspx.

On May 10, 2011, VOC Brazos and the trust completed an initial public offering of units of beneficial interest in the trust, which are referred to herein as the “trust units.” In connection with the closing of the initial public offering, on May 10, 2011, VOC Brazos conveyed a net profits interest to the trust, which entitles the trust to receive 80% of the net proceeds (calculated as described below) from the sale and production of substantially all of the interests in oil and natural gas properties in the states of Kansas and Texas held by VOC Brazos as of May 10, 2011, which is referred herein as the “net profits interest.” VOC Brazos’ net interests in such properties, after deduction of all royalties and other burdens on production thereon as of May 10, 2011, is referred to herein as the “underlying properties.” As of December 31, 2021, the underlying properties included interests in 743 gross (452.5 net) producing wells and included 82,615 gross (51,147.2 net) acres. The net profits interest will terminate on the later to occur of (1) December 31, 2030, or (2) the time from and after January 1, 2011 when 10.6 MMBoe have been produced from the underlying properties and sold (which amount is the equivalent of 8.5 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), 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 approximately 6.0 MMBoe of the trust’s 8.5 MMBoe interest.

The trust will make quarterly cash distributions of substantially all of its quarterly cash receipts, after deducting the trust’s administrative expenses, on or about 45 days following the completion of each quarter through (and including) the quarter ending December 31, 2030. Because payments to the trust will be generated by depleting assets and the trust has a finite life with the production from the underlying properties diminishing over time, a portion of each distribution will represent a return of the original investment in the trust units.

The amount of trust revenues and cash distributions to trust unitholders will depend on, among other things:

•

oil sales prices and, to a lesser extent, natural gas sales prices;

•

volumes of oil and natural gas produced and sold attributable to the underlying properties;

•

property and production taxes;

•

development expenses;

•

lease operating expenses; and

•

administrative expenses of the trust.

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The trust was created to acquire and hold the net profits interest for the benefit of the trust unitholders. The net profits interest is passive in nature and neither the trust nor the trustee has any control over or responsibility for costs relating to the operation of the underlying properties. The business and affairs of the trust are managed by the trustee, and neither VOC Brazos nor any of its affiliates has the ability to manage or influence the operations of the trust. Vess Oil Corporation, which we refer to as “Vess Oil,” L.D. Drilling, Inc. and Davis Petroleum, Inc., which are collectively referred to herein as the “VOC Operators,” are currently the operator or contract operator of substantially all of the underlying properties. VOC Brazos does not, as a matter of course, make public projections as to future sales, earnings or other results relating to the underlying properties.

Description of the Trust Units

Each trust unit is a unit of beneficial interest in the trust and is entitled to receive cash distributions from the trust on a pro rata basis. Each trust unitholder has the same rights regarding each of his trust units as every other trust unitholder has regarding his units. The trust units are in book-entry form only and are not represented by certificates. The trust had 17,000,000 trust units outstanding as of March 17, 2022.

Distributions and Income Computations

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) in that quarter, over the trust’s expenses for that quarter. Available funds are reduced by any cash 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 45th day following the end of each quarter to the trust unitholders of record on the 30th day following the end of each quarter (or the next succeeding business day).

Unless otherwise advised by counsel or the Internal Revenue Service, which we refer to herein as the “IRS,” the trustee will treat the income and expenses of the trust for each quarter as belonging to the trust unitholders of record on the quarterly record date. For federal income tax purposes, trust unitholders must take into account items of income, gain, loss, deduction and credit consistent with their methods of accounting and without regard to the taxable year or accounting method employed by the trust and without regard to the quarter in which the trust makes distributions related to those items to the trust unitholders. Variances between taxable income and cash distributions may occur. For example, the trustee could establish a reserve in one quarter using funds that would be included in income in the quarter in which the reserve is created but may not result in a tax deduction or a distribution until a later quarter or possibly in a later taxable year. Similarly, the trustee could also make a payment in one quarter that would be amortized for income tax purposes over several quarters. See “— Federal Income Tax Matters.”

Periodic Reports

The trustee files all required trust federal and state income tax and information returns. The trustee prepares and provides the tax information that trust unitholders need to correctly report their share of the income and deductions of the trust. The trustee also causes to be prepared and filed reports required to be filed under the Exchange Act and by the rules of any securities exchange or quotation system on which the trust units are listed or admitted to trading, and also causes the trust to comply with the provisions of the Sarbanes-Oxley Act of 2002, including but not limited to, by establishing, evaluating and maintaining a system of internal control over financial reporting in compliance with the requirements of Section 404 thereof.

Each trust unitholder and his or her representatives may examine, for any proper purpose, during reasonable business hours, the records of the trust and the trustee.

Liability of Trust Unitholders

Under the Delaware Statutory Trust Act, trust unitholders are entitled to the same limitation of personal liability extended to stockholders of private corporations for profit under the General Corporation Law of the State of Delaware. Courts in jurisdictions outside of Delaware, however, may not give effect to such limitation.

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Voting Rights of Trust Unitholders

The trustee or trust unitholders owning at least 10% of the outstanding trust units may call meetings of trust unitholders. The trust is responsible for all costs associated with calling a meeting of trust unitholders unless such meeting is called by the trust unitholders, in which case the trust unitholders are responsible for all costs associated with calling such meeting of trust unitholders. Meetings must be held in such location as is designated by the trustee in the notice of such meeting. The trustee must send written notice of the time and place of the meeting and the matters to be acted upon to all of the trust unitholders at least 20 days and not more than 60 days before the meeting. Trust unitholders representing a majority of trust units outstanding must be present or represented by proxy to have a quorum. Each trust unitholder is entitled to one vote for each trust unit owned.

Unless otherwise required by the trust agreement, a matter may be approved or disapproved by the vote of a majority of the trust units held by the trust unitholders at a meeting where there is a quorum. This is true even if a majority of the total trust units did not approve it. The affirmative vote of the holders of a majority of the outstanding trust units is required to:

•

dissolve the trust;

•

remove the trustee or the Delaware trustee;

•

amend the trust agreement (except with respect to certain matters that do not adversely affect the rights of trust unitholders in any material respect);

•

merge or consolidate the trust with or into another entity; or

•

approve the sale of all or any material part of the assets of the trust.

In addition, certain amendments to the trust agreement may be made by the trustee without approval of the trust unitholders. The trustee must consent before all or any part of the trust assets can be sold except in connection with the dissolution of the trust or limited sales directed by VOC Brazos in conjunction with its sale of underlying properties.

Duration of the Trust; Sale of the Net Profits Interest

The trust will remain in existence until the later to occur of (1) December 31, 2030 or (2) the time when 10.6 MMBoe (which is the equivalent of 8.5 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) have been produced and sold. The trust will dissolve prior to its termination if:

•

the trust sells the net profits interest;

•

annual cash proceeds attributable to the net profits interest are less than $1 million for each of two consecutive years;

•

the holders of a majority of the outstanding trust units vote in favor of dissolution; or

•

there is a judicial dissolution of the trust.

Upon dissolution, the trustee would sell all of the trust’s assets, either by private sale or public auction, and distribute the net proceeds of the sale to the trust unitholders.

Computation of Net Proceeds

The provisions of the conveyance governing the computation of the net proceeds are detailed and extensive. The following information summarizes the material information contained in the conveyance related to the computation of the net proceeds. For more detailed provisions concerning the net profits interest, please see the conveyance, which is referenced as an exhibit to this Form 10-K.

Net Profits Interest

The net profits interest was conveyed to the trust by VOC Brazos on May 10, 2011 by means of a conveyance instrument that has been recorded in the appropriate real property records in each county in

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Kansas and Texas where the oil and natural gas properties to which the underlying properties relate are located. The net profits interest burdens the net interest owned by VOC Brazos in the underlying properties in existence as of May 10, 2011.

The amounts paid to the trust for the net profits interest are based on the definitions of “gross proceeds” and “net proceeds” contained in the conveyance and described below. Under the conveyance, net proceeds are computed quarterly, and 80% of the aggregate net proceeds attributable to a computation period will be paid to the trust on or before the 30th day of the month following the computation period. VOC Brazos will not pay to the trust any interest on the net proceeds held by VOC Brazos prior to payment to the trust. The trustee will make distributions to trust unitholders quarterly, if sufficient funds are available. See “— Description of the Trust Units — Distributions and Income Computations.”

“Gross proceeds” means the aggregate amount received by VOC Brazos from sales of oil and natural gas produced from the underlying properties (other than amounts received for certain future non-consent operations). However, gross proceeds does not include consideration for the transfer or sale of any underlying property by VOC Brazos or any subsequent owner to any new owner. Gross proceeds also does not include any amount for oil or natural gas lost in production or marketing or used by the owner of the underlying properties in drilling, production and plant operations. Gross proceeds includes payments for future production if they are not subject to repayment in the event of insufficient subsequent production.

“Net proceeds” means gross proceeds less the following:

•

all payments to mineral owners or landowners, such as royalties, overriding royalties or other burdens against production, delay rentals, shut-in oil and natural gas payments, minimum royalty or other payments for drilling or deferring drilling;

•

any taxes paid by the owner of an underlying property to the extent not deducted in calculating gross proceeds, including estimated and accrued general property (ad valorem), production, severance, sales, gathering, excise and other taxes;

•

any extraordinary taxes or windfall profits taxes that may be assessed in the future that are based on profits realized or prices received for production from the underlying properties;

•

costs paid by an owner of a property comprising the underlying properties under any joint operating agreement pursuant to the terms of the conveyance;

•

all other costs and expenses, development costs and liabilities of drilling, recompleting, workovers, operating and producing oil and natural gas, including allocated expenses such as labor, vehicle and travel costs and materials and any plugging and abandonment liabilities (net of any capital costs for which a reserve had already been made to the extent such development costs are incurred during the computation period) other than costs and expenses for certain future non-consent operations;

•

costs or charges associated with gathering, treating and processing oil and natural gas (provided, however, that any proceeds attributable to treatment or processing will offset such costs or changes, if any);

•

any overhead charge incurred pursuant to any operating agreement relating to an underlying property;

•

costs for recording the conveyance and costs estimated to record the termination and for the release of the conveyance;

•

amounts previously included in gross proceeds but subsequently paid as a refund, interest or penalty;

•

costs and expenses for renewals or extensions of leases; and

•

at the option of VOC Brazos (or any subsequent owner of the underlying properties), amounts reserved for approved development, maintenance or operating expenditures, including well drilling, recompletion and workover costs, which amounts will at no time exceed $1.0 million in the aggregate, and will be subject to the limitations described below (provided that such costs shall not be debited from gross proceeds when actually incurred).

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Certain non-production revenues, including salvage value for equipment related to plugged and abandoned wells, as detailed in the conveyance, offset the costs outlined above in calculating the net proceeds. If any excess amounts have not been used to offset costs at the time when the later to occur of (1) December 31, 2030 or (2) the time when 10.6 MMBoe (which is the equivalent of 8.5 MMBoe in respect of the net profits interest) have been produced from the underlying properties and sold, then trust unitholders will not be entitled to receive the benefit of such excess amounts.

During each twelve-month period beginning on the later to occur of (1) December 31, 2027 and (2) the time when 9.8 MMBoe have been produced from the underlying properties and sold (which is the equivalent of 7.8 MMBoe in respect of the net profits interest), which we refer to, in either case, as the “Capital Expenditure Limitation Date,” the sum of the development expenditures and amounts reserved for approved development expenditure projects for such twelve-month period may not exceed the Average Annual Capital Expenditure Amount. The “Average Annual Capital Expenditure Amount” means the quotient of (x) the sum of the development expenditures and amounts reserved for approved development expenditure projects with respect to the three twelve-month periods ending on the Capital Expenditure Limitation Date, divided by (y) three. Commencing on the Capital Expenditure Limitation Date, and each anniversary of the Capital Expenditure Limitation Date thereafter, the Average Annual Capital Expenditure Amount will be increased by 2.5% to account for expected increased costs due to inflation.

As is customary in the oil and natural gas industry, VOC Brazos pays an overhead fee to the VOC Operators to operate the underlying properties on behalf of VOC Brazos. The operating activities include various engineering, accounting and administrative functions. The fee is based on a monthly charge per active operated well, which totaled $1.8 million paid to the VOC Operators in 2019, $1.7 million paid in 2020, and $1.8 million paid in 2021 for all of the underlying properties for which VOC Brazos was designated as the operator. The fee is adjusted annually and will increase or decrease each year based on changes in the Overhead Adjustment Index (“OAI”) published by the Council of Petroleum Accountants Society (“COPAS”) for that year.

In the event that the net proceeds for any computation period is a negative amount, the trust will receive no payment for that period, and any such negative amount plus accrued interest at the prime rate will be deducted from gross proceeds in the following computation period for purposes of determining the net proceeds for that following computation period.

Gross proceeds and net proceeds are calculated on a cash receipts and cash disbursements basis except that certain costs, primarily ad valorem taxes and expenditures of a material amount, may be determined on an accrual basis.

Additional Provisions

If a controversy arises as to the sales price of any production, then for purposes of determining gross proceeds:

•

amounts withheld or placed in escrow by a purchaser are not considered to be received by the owner of the underlying property until actually collected;

•

amounts received by the owner of the underlying property and promptly deposited with a nonaffiliated escrow agent will not be considered to have been received until disbursed to it by the escrow agent; and

•

amounts received by the owner of the underlying property and not deposited with an escrow agent will be considered to have been received.

The trustee is not obligated to return any cash received from the net profits interest. Any overpayments that VOC Brazos makes to the trust due to adjustments to prior calculations of net proceeds or otherwise will reduce future amounts payable to the trust until VOC Brazos recovers the overpayments plus interest at the prime rate.

The conveyance generally permits VOC Brazos to transfer without the consent or approval of the trust unitholders all or any part of its interest in the underlying properties, subject to the net profits interest. The trust unitholders are not entitled to any proceeds of a sale or transfer of VOC Brazos’ interest unless

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certain conditions set forth in the following paragraph are satisfied. Except in certain cases where the net profits interest is released, following a sale or transfer, the underlying properties will continue to be subject to the net profits interest, 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.

In addition, VOC Brazos may, without the consent of the trust unitholders, require the trust to release the net profits interest associated with any lease that accounts for less than or equal to 0.25% of the total production from the underlying properties in the prior 12 months and provided that the net profits interest covered by such releases cannot exceed, during any 12-month period, an aggregate fair market value to the trust of $500,000. These releases will be made only in connection with a sale by VOC Brazos to a non-affiliate of the relevant underlying properties and are conditioned upon the trust receiving an amount equal to the fair value to the trust of such net profits interest. Any net sales proceeds paid to the trust are distributable to trust unitholders for the quarter in which they are received.

As the designated operator of a property comprising the underlying properties, VOC Brazos may enter into farm-out, operating, participation and other similar agreements to develop the property. VOC Brazos may enter into any of these agreements without the consent or approval of the trustee or any trust unitholder.

VOC Brazos and any transferee of an underlying property will have the right to abandon its interest in any well or property if it reasonably believes the well or property ceases to produce or is not capable of producing in commercially paying quantities. In making such decisions, VOC Brazos or any transferee of an underlying property is required under the applicable conveyance to operate, or to use commercially reasonable efforts to cause the operators of the underlying properties to operate these properties as would a reasonably prudent operator in the State of Kansas or Texas 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. Upon termination of the lease, the portion of the net profits interest relating to the abandoned property will be extinguished.

VOC Brazos must maintain books and records sufficient to determine the amounts payable for the net profits interest to the trust. Quarterly and annually, VOC Brazos must deliver to the trustee a statement of the computation of the net proceeds for each computation period. The trustee has the right to inspect and copy the books and records maintained by VOC Brazos during normal business hours and upon reasonable notice.

Federal Income Tax Matters

The following is a summary of certain U.S. federal income tax matters that may be relevant to trust unitholders. This summary is based upon current provisions of the Internal Revenue Code of 1986, as amended, which we refer to as the “Code,” existing and proposed Treasury regulations thereunder and current administrative rulings and court decisions, all of which are subject to changes that may or may not be retroactively applied. No attempt has been made in the following summary to comment on all U.S. federal income tax matters affecting the trust or the trust unitholders.

The summary is limited to trust unitholders who are individual citizens or residents of the United States. Accordingly, the following summary has limited application to domestic corporations and persons subject to specialized federal income tax treatment. Each trust unitholder should consult his or her own tax advisor with respect to his or her particular circumstances.

Classification and Taxation of the Trust

Tax counsel to the trust advised the trust at the time of formation that, for federal income tax purposes, in its opinion the trust will be treated as a grantor trust and not as an unincorporated business entity. No ruling has been or will be requested from the IRS with respect to the federal income tax treatment of the trust, including as to the status of the trust as a grantor trust for such purposes. Thus, no assurance can be provided that the tax treatment of the trust would be sustained by a court if contested by the IRS or another taxing authority. The remainder of the discussion below is based on tax counsel’s opinion, at the time of formation, that the trust will be classified as a grantor trust for federal income tax purposes. As a grantor trust, the trust will not be subject to federal income tax at the trust level. Rather, each trust unitholder will be

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considered for federal income tax purposes to own its proportionate share of the trust’s assets directly as though no trust were in existence. The income of the trust is deemed to be received or accrued by the trust unitholder at the time such income is received or accrued by the trust, rather than when distributed by the trust. Each trust unitholder will be subject to tax on its proportionate share of the income and gain attributable to the assets of the trust and will be entitled to claim its proportionate share of the deductions and expenses attributable to the assets of the trust, subject to applicable limitations, in accordance with the trust unitholder’s tax method of accounting and without regard to the taxable year or accounting method employed by the trust.

The trust will allocate items of income, gain, loss, deductions and credits to trust unitholders based on record ownership at each quarterly record date. It is possible that the IRS or another taxing authority could disagree with this allocation method and could assert that income and deductions of the trust should be determined and allocated on a daily, prorated or other basis, which could require adjustments to the tax returns of the trust unitholders affected by this issue and result in an increase in the administrative expense of the trust in subsequent periods.

Classification of the Net Profits Interest

Tax counsel to the trust also advised the trust at the time of formation that, for federal income tax purposes, based upon representations made by VOC Brazos 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. On the basis of that advice, the trust will treat the net profits interest as indebtedness subject to Treasury regulations applicable to contingent payment debt instruments, and by purchasing trust units, a trust unitholder will agree to be bound by the trust’s application of those regulations, including the trust’s determination of the rate at which interest will be deemed to accrue on the net profits interest. No assurance can be given that the IRS or another taxing authority will not assert that the net profits interest should be treated differently. Any such different treatment could affect the amount, timing and character of income, gain or loss in respect of an investment in trust units and could require a trust unitholder to accrue income at a rate different than that determined by the trust.

Widely Held Fixed Investment Trust Reporting Information

The trustee assumes that some trust units are held by middlemen, as such term is broadly defined in Treasury regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a custodian in street name). Therefore, the trustee considers the trust to be a non-mortgage widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. The Bank of New York Mellon Trust Company, N.A., 601 Travis Street, Floor 16, Houston, Texas 77002, telephone number 1-855-802-1094, is the representative of the trust that will provide tax information in accordance with applicable Treasury regulations governing the information reporting requirements of the trust as a WHFIT. Notwithstanding the foregoing, the middlemen holding trust units on behalf of trust unitholders, and not the trustee of the trust, are solely responsible for complying with the information reporting requirements under the Treasury regulations with respect to such trust units, including the issuance of IRS Forms 1099 and certain written tax statements. Trust unitholders whose trust units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the trust units. Any generic tax information provided by the trustee of the trust is intended to be used only to assist trust unitholders in the preparation of their federal and state income tax returns.

Available Trust Tax Information

In compliance with the reporting requirements for WHFITs and the dissemination of trust tax reporting information, the trustee provides a generic tax information reporting booklet that is intended to be used only to assist unitholders in the preparation of their 2021 federal and state income tax returns. The projected payment schedule for the net profits interest is included with the tax information booklet. This tax information booklet can be obtained at https://voc.q4web.com/home/default.aspx.

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Description of the Underlying Properties

The underlying properties consist of VOC Brazos’ net interests in substantially all of its oil and natural gas properties after deduction of all royalties and other burdens on production thereon as of May 10, 2011, which properties are located in the states of Kansas and Texas. The VOC Operators are currently the operators or contract operators of substantially all of the underlying properties.

VOC Brazos’ interests in the properties comprising the underlying properties require VOC Brazos to bear its proportionate share along with the other working interest owners of the costs of development and operation of such properties. The underlying properties are burdened by non-working interests owned by third parties consisting primarily of overriding royalty and royalty interests retained by the owners of the land subject to the working interests. These landowners’ royalty interests typically entitle the landowner to receive 12.5% of the revenue derived from oil and natural gas production resulting from wells drilled on the landowner’s land, without any deduction for drilling costs or other costs related to production of oil and natural gas. A working interest percentage represents a working interest owner’s proportionate ownership interest in a property in relation to all other working interest owners in that property, whereas a net revenue interest percentage is a working interest owner’s percentage of production after reducing such percentage by the percentage of burdens on such production such as royalties and overriding royalties.

Based on the reserve report, the net profits interest would entitle the trust to receive net proceeds from the sale of production of not less than 10.6 MMBoe of proved reserves attributable to the underlying properties expected to be produced over the term of the trust. The trust is entitled to receive 80% of the net proceeds from the sale of production of oil and natural gas attributable to the underlying properties that are produced during the term of the trust, whereas total reserves as reflected on the summary reserve reports and attributable to the underlying properties include all reserves expected to be economically produced during the economic life of the underlying properties.

In general, the producing wells included in the underlying properties have stable production profiles and their production is long-lived. Based on the reserve report, annual production from the underlying properties is expected to decline at an average annual rate of 6.8% over the next 20 years assuming no additional development drilling or other development expenditures are made on the underlying properties after 2026. VOC Brazos expects total development expenditures for the underlying properties through December 31, 2026 will be approximately $30.7 million, which it expects will partially offset the natural decline in production otherwise expected to occur with respect to the underlying properties as described in more detail below.

Reserves

The engineering department of Vess Oil Corporation, who serves as contract operator for VOC Brazos, maintains oversight and compliance responsibility for the internal reserve estimate process and, in accordance with internal policies and procedures, provides appropriate data to independent third party engineers for the annual estimation of year-end reserves. This engineering department accumulates historical production data for the underlying properties, calculates historical lease operating expenses and differentials, updates working interests and net revenue interests, and obtains logs, 3-D seismic and other geological and geophysical information. This data is forwarded to Cawley, Gillespie & Associates, Inc., which we refer to as “CG&A”, thereby allowing CG&A to prepare estimated proved reserves in their entirety based on such data.

Estimates of the proved oil and gas reserves attributable to the trust as of December 31, 2019, 2020 and 2021 are based on reports prepared by CG&A. CG&A has been in business since 1961 and serves many organizations and individuals in the petroleum industry, including owners and operators of oil and gas properties, exploration groups, planners, and professionals in investment and finance. One of the principal businesses of CG&A is providing detailed assessment of producing reservoirs. CG&A is an independent firm of petroleum engineers, geologists, geophysicists and petrophysicists and does not own an interest in the underlying properties and is not employed on a contingent basis. Mr. W. Todd Brooker, President, is the technical person at CG&A who is primarily responsible for overseeing CG&A’s preparation of the reserve estimates. Mr. Brooker is a graduate of the University of Texas at Austin with a Bachelor of Science degree in

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Petroleum Engineering and has 30 years of experience in petroleum engineering. He is a licensed professional engineer in the State of Texas (License #83462).

Oil and gas proved reserves are disclosed by significant geographic area, using the 12-month average beginning-of-month price for the year, based on the use of reliable technologies to estimate proved oil and gas reserves, if those technologies have been demonstrated to result in reliable conclusions about reserves volumes. Reserve and related information for 2019, 2020 and 2021 is presented consistent with these requirements.

Proved Reserves of VOC Energy Trust. The following table sets forth, as of December 31, 2021, estimated proved reserves attributable to the trust derived from the reserve report. A summary of the reserve report is included below.

	Oil (MBbls)		Natural gas (MMcf)		Oil equivalents (MBoe)
Proved Developed		2,421		1,429		2,658
Proved Undeveloped		828		770		956
Total Proved		3,249		2,199		3,614

Information concerning historical changes in net proved reserves attributable to the trust, and the calculation of the standardized measure of discounted future net revenues related thereto, is contained in Note J to the financial statements of the trust included in this Form 10-K. VOC Brazos has not filed reserve estimates covering the underlying properties with any other federal authority or agency.

The following table summarizes the changes in estimated proved reserves of the trust for the periods indicated.

	VOC Energy Trust
	Oil (MBbl)		Natural Gas (MMcf)		Oil Equivalents (MBoe)
Proved Reserves:
Balance, December 31, 2018		4,389		2,278		4,769
Revisions of previous estimates		263		(40)		256
Production(1)		(489)		(287)		(537)
Balance, December 31, 2019		4,163		1,951		4,488
Revisions of previous estimates		(1,310)		364		(1,250)
Production(1)		(434)		(290)		(482)
Balance, December 31, 2020		2,419		2,025		2,756
Revisions of previous estimates		1,253		440		1,326
Production(1)		(423)		(266)		(468)
Balance, December 31, 2021		3,249		2,199		3,614
Proved Developed Reserves:
Balance, December 31, 2018		3,417		1,574		3,680
Balance, December 31, 2019		3,178		1,561		3,438
Balance, December 31, 2020		1,949		1,557		2,208
Balance, December 31, 2021		2,421		1,429		2,658

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	VOC Energy Trust
	Oil (MBbl)		Natural Gas (MMcf)		Oil Equivalents (MBoe)
Proved Undeveloped Reserves:
Balance, December 31, 2018		972		704		1,089
Proved undeveloped reserves converted to proved developed by drilling		(165)		0		(165)
Additional proved undeveloped reserves added		401		0		401
Revisions of previous estimates		(223)		(314)		(275)
Balance, December 31, 2019		985		390		1,050
Proved undeveloped reserves converted to proved developed by drilling		0		0		0
Additional proved undeveloped reserves added		0		0		0
Revisions of previous estimates		(515)		78		(502)
Balance, December 31, 2020		470		468		548
Proved undeveloped reserves converted to proved developed by drilling		0		0		0
Additional proved undeveloped reserves added		143		68		154
Revisions of previous estimates		215		234		254
Balance, December 31, 2021		828		770		956

(1)

Reflects sales volumes produced during the noted year regardless whether royalty payments thereon have been remitted to the Trust by VOC Brazos.

None of the proved undeveloped reserves have remained undeveloped for five years or more after they were initially disclosed as proved undeveloped reserves.

The reserves above represent the trust’s 80% net profits interest in the underlying properties for the remainder of the term of the trust.

The following table sets forth the estimates of total proved reserves and forecasts of economics attributable to the underlying properties as of December 31, 2021 for the remainder of the term of the trust, as presented in the summary prepared by CG&A of its reserve report as of December 31, 2021 for the trust. The estimates of proved reserves have not been filed with or included in reports to any federal authority or agency. The discounted cash flow value shown in the table is not intended to represent the current market value of the trust’s estimated oil and natural gas reserves.

	Proved Developed Producing			Proved Developed Non-Producing			Proved Undeveloped			Total Proved
	(dollars in thousands)
Net Reserves
Oil (MBbl)			3,016.4			9.9			1,034.5			4,060.7
Gas (MMcf)			1,563.8			0.0			597.3			2,161.1
NGL (MBbl)			56.7			0.0			93.8			150.5
Revenue
Oil		$	189,899.8		$	611.5		$	66,593.2		$	257,104.5
Gas			4,279.0			0.0			1,253.1			5,532.1
NGL			1,132.4			0.0			1,872.8			3,005.2
Severance Taxes			4,847.0			25.8			3,120.2			7,993.0
Ad Valorem Taxes			5,213.0			34.8			2,260.9			7,508.7
Operating Expenses			91,670.8			0.0			4,314.8			95,985.6

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	Proved Developed Producing			Proved Developed Non-Producing			Proved Undeveloped			Total Proved
	(dollars in thousands)
Future Development Costs			364.9			116.0			30,205.1			30,685.9
80% Net Profits Interest Net Operating Income (NPI)(1)		$	74,572.4		$	348.0		$	23,854.5		$	98,774.9
80% NPI(2)		$	54,126.6		$	231.8		$	13,259.8		$	67,618.2

(1)

Before interest and taxes.

(2)

Discounted at 10%.

The net profits interest entitles the trust to receive 80% of the net proceeds attributable to the underlying properties. The net profits interest will terminate on the later to occur of (1) December 31, 2030, or (2) the time when 10.6 MMBoe have been produced from the underlying properties and sold, and the trust will soon thereafter wind up its affairs and terminate. Based on the reserve report for the year ended December 31, 2021, CG&A estimated that the trust would terminate on December 31, 2030 based on the calculation that 10.6 MMBoe would have been produced from the underlying properties and sold (which amount is the equivalent of 8.5 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) prior to this date.

Oil and gas prices were adjusted to a WTI Cushing oil price of $66.56 per Bbl and a Henry Hub natural gas price of $3.598 per MMBtu. As specified by the SEC, these prices are 12-month averages based upon the price on the first day of each month during 2021. The price adjustments were based on oil price differentials forecast at −$4.50 per Bbl for the Kansas underlying properties, −$2.00 per Bbl for the Kurten (Woodbine) Field wells in Texas, −$3.75 per Bbl for the Sand Flat Unit and Hitts Lake North Field wells in Texas and −$2.00 per Bbl for all other Texas underlying properties. Oil price differentials were not escalated. Gas price differentials varied by property as provided by VOC Brazos and were also not escalated. NGL price differentials were applied at 30% of the WTI oil price and not escalated. The base price differentials may include local basis differentials, transportation, gas shrinkage, gas heating value (BTU content) and/or crude quality and gravity corrections. Operating expenses, workover expenses, COPAS overhead charges and investments were forecast on a per property basis as furnished by VOC Brazos. Expenses and investments were held constant in accordance with SEC rules and guidelines. For Kansas properties, severance taxes were applied at 4.33 percent of revenue until exemption levels were forecasted to be reached. The severance tax rate was dropped to zero when a rate of 6 Bbl/day per well was reached or when gross gas production value reached $87/day per gas well. Severance taxes were forecasted at 4.6 percent of oil revenue and 7.5 percent of gas revenue for properties in Texas. Ad valorem taxes for Kansas properties were applied at 6.0 percent of revenue but dropped to 2.0 percent as properties qualified for the tax exemption. Kansas oil and gas conservation taxes were included within the severance tax estimates. Ad valorem taxes were applied at 3.29 percent of revenue (after severance taxes) for the Texas properties.

The estimates of proved oil and natural gas reserves attributable to the underlying properties are based on estimates prepared by CG&A. Rules and guidelines established by the SEC regarding the present value of future net revenues were used to prepare these reserve estimates. Oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact manner, and estimates of other engineers might differ materially from those included in the report. The accuracy of any reserve estimate is a function of the quality of available data and engineering, and estimates may justify revisions based on the results of drilling, testing, and production activities. Accordingly, reserve estimates are inherently imprecise and should not be construed as representing the actual quantities of future production or cash flows to be realized from oil and natural gas properties or the fair market value of such properties.

Producing Acreage and Well Counts

For the following data, “gross” refers to the total wells or acres in which VOC Brazos owns a working interest and “net” refers to gross wells or acres multiplied by the percentage working interest owned by VOC

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Brazos. Although many of VOC Brazos’ wells produce both oil and natural gas, a well is categorized as an oil well or a natural gas well based upon the ratio of oil to natural gas production.

The underlying properties are interests in developed properties located in oil and natural gas producing regions of Kansas and Texas. The following is a summary of the approximate acreage of the underlying properties at December 31, 2021.

	Gross		Net
	(acres)
Developed Acreage:
Kansas		58,922		34,305.9
Texas		23,693		16,841.3
Total		82,615		51,147.2
Undeveloped Acreage:		—		—

The following is a summary of the producing wells on the underlying properties as of December 31, 2021:

	Operated Wells				Non-Operated Wells				Total
	Gross		Net		Gross		Net		Gross		Net
Oil		700		439.5		30		7.3		730		446.8
Natural gas		10		5.0		3		0.7		13		5.7
Total		710		444.5		33		8.0		743		452.5

The following is a summary of the number of developmental wells drilled by VOC Brazos on the underlying properties during the last three years. VOC Brazos did not drill any exploratory wells during the periods presented.

	Year Ended December 31,
	2019				2020				2021
	Gross		Net		Gross		Net		Gross		Net
Completed:
Oil wells		9		3.6		—		—		1		0.7
Natural gas wells		—		—		—		—		—		—
Non-productive		—		—		—		—		1		0.2
Total		9		3.6		—		—		2		0.9

In 2019, the remaining two Hawkwood Earning Wells (as defined below) were drilled and completed at no cost to VOC Brazos. An additional four Hawkwood Development Wells were drilled and completed under the joint venture agreement. The one MD Earning Well (as defined below) was still waiting on completion. In addition, two non-joint venture agreement wells were drilled and completed and the well awaiting completion at December 31, 2018 was completed. Total capital expenditures for 2019 for these wells was $6,429,767.

In 2020, no wells were drilled or completed. The former MD Earning Well was still awaiting completion at December 31, 2020.

In 2021, the former MD Earning Well was completed and one other well was drilled, deemed non-productive and plugged. Total capital expenditures in 2021 for the former MD Earning Well was $1,695,593. VOC Brazos continues to develop further proved undeveloped reserves pursuant to its planned development and workover program. See “Item 7. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations — Planned Development and Workover Program” for more information regarding

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VOC Brazos’ joint venture agreement with Hawkwood Energy East Texas, LLC, the Hawkwood Earning Wells, and the Hawkwood Development Wells (each as defined therein).

The following table shows the average sales prices per Bbl of oil and Mcf of natural gas produced and the production costs and production and property taxes per Boe received by the trust from the underlying properties.

	Year Ended December 31,
	2019			2020			2021
Sales prices:
Oil (per Bbl)		$	56.11		$	43.22		$	53.09
Natural gas (per Mcf)		$	2.90		$	1.80		$	2.98
Lease operating expense (per Boe)		$	20.29		$	17.40		$	19.84
Production and property taxes (per Boe)		$	2.81		$	2.78		$	2.99

Major Producing Areas

The following table summarizes the estimated proved reserves by operating area attributable to the underlying properties according to the reserve report and the corresponding pre-tax PV-10 value as of December 31, 2021.

	Proved Reserves(1)
Operating Area	Oil (MBbls)		Natural Gas (MMcf)		Total (MBoe)		% of Total Reserves		Pre-Tax PV-10% Value(2)			% of Pre-Tax PV-10% Value
	(In Thousands)
Kansas (153 Fields)
Fairport		578		0		578		6.9%		$	8,783		8.4%
Chase-Silica		187		0		187		2.2			2,859		2.7
Marcotte		191		0		191		2.3			2,783		2.7
Bindley		158		0		158		1.9			2,197		2.1
Codell		104		0		104		1.2			1,971		1.9
Mueller		106		0		106		1.3			1,758

SEC Form 10-K filed by VOC Energy Trust