CoJax Oil & Gas Corp 10-K for FY2024
CoJax Oil & Gas Corp (CJAX)
About this 10-K
CoJax Oil & Gas Corp filed this 10-K on March 31, 2025, covering the fiscal year ended December 31, 2024 (FY2024).
Headline figures
Fiscal year ended December 31, 2024, as reported in this filing, compared with the same period a year earlier where the filing states it.
- Revenue
- $971.69K
- up 4.7% from $927.98K a year earlier
- Net loss
- $1.61M
- compared with a net loss of $1.63M a year earlier
- Diluted EPS
- -$0.13
- compared with -$0.18 a year earlier
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM
(Mark One)
1934
For
the Fiscal Year Ended
or
For the transition period from __________________________ to __________________________
Commission
File Number
(Exact name of Registrant as specified in its charter)
| (State or other jurisdiction | (I.R.S. Employer |
| of incorporation or organization) | Identification No.) |
| (Address of Principal Executive Offices) | (Zip Code) |
(
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
| None | N/A | N/A |
Securities registered pursuant to Section 12(g) of the Act: Common Stock, $0.01 par value per share
Indicate
by check mark if the Registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☐
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 ☐
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.
Indicate
by check mark whether the Registrant has submitted electronically every Interactive Data File required to be submitted pursuant
to Rule 405 of Regulation S-T (§ 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 ☐
Indicate by check mark whether the Registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a small reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” or an “emerging growth company” in Rule 12b-2 of the Exchange Act.
| Large accelerated filer | ☐ | 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
☐
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. Yes ☐ No ☐
Indicate
by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation
received by any of the registrant’s executive owners during the relevant reporting period pursuant to §240.10D-1(b).
Yes ☐ No
The
aggregate market value of the voting and non-voting common equity held by non-affiliates computed as of the last business day
of the Registrant’s most recently completed fiscal quarter (based on the average bid and asked price of common stock) was
$
On March 31, 2025, there were outstanding shares of common stock of the Company .
DOCUMENTS INCORPORATED BY REFERENCE
None.
CoJax Oil and Gas Corporation
Form 10-K
For the Fiscal Year Ended December 31, 2024
TABLE OF CONTENTS
2
FORWARD-LOOKING STATEMENTS
This Annual Report contains forward-looking statements. Forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause changes in our actual results and reflect the current view about future events and are based on our current expectations and assumptions regarding our business, potential target businesses, the economy, and other future conditions. Such statements are generally accompanied by words such as “may,” “should,” “expect,” “believe,” “plan,” “anticipate,” “could,” “intend,” “target,” “goal,” “project,” “contemplate,” “believe,” “estimate,” “predict,” “potential,” “will,” or “continue” or the negative of these terms or other similar expressions. Any forward-looking statements contained or incorporated by reference in this Annual Report speak only as of the date on which we make them and are based upon our historical performance and on current plans, estimates, and expectations. Forward-looking statements contained or incorporated by reference herein include or may include, but are not limited to, statements about:
| ● | our business strategy; |
| ● | our plans, objectives, expectations, and intentions; |
| ● | our future operating results and future operating results of Barrister as a wholly-owned subsidiary of CoJax; |
| ● | the competitive nature of the industry in which we will conduct our business; |
| ● | crude oil and natural gas commodity prices; |
| ● | demand for oil; |
| ● | the impact of adverse weather conditions and unexpected events like the COVID-19 pandemic and other pandemics or epidemics; |
| ● | the effects of government regulation and changes in that regulation; |
| ● | legal proceedings, liability claims, and effect of external investigations; |
| ● | the effect of a loss of, or the financial distress of, one or more key customers of our future, proposed oil production; |
| ● | our ability to obtain or renew customer or supply contracts; |
| ● | the effect of a loss of, or interruption in operations of, one or more key vendors, suppliers or contractors; |
| ● | our ability to maintain the right level of commitments under any future oil supply agreements; |
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| ● | the market price and availability of materials or equipment; |
| ● | the impact of new technology on oil exploration and production and our ability to acquire and use that technology; |
| ● | our ability to employ or engage as contractors a sufficient number of skilled and qualified workers and to retain key management; |
| ● | our ability to obtain permits, approvals, and authorizations from governmental and third parties; |
| ● | our ability to consummate planned acquisitions and future capital expenditures; |
| ● | our ability to maintain effective information technology systems and guard against cyber-attacks or hacking; |
| ● | our ability to maintain an effective system of internal controls over financial reporting; |
| ● | financial strategy, liquidity or capital required for our ongoing operations and acquisitions, and our ability to raise additional capital to acquire and expand oil drilling and production and to fund overhead and our ability to service our debt obligations; and |
| ● | the market volatility of our stock. |
We caution you that the foregoing list may not contain all of the forward-looking statements made or incorporated by reference in this Annual Report. You should not rely upon forward-looking statements as predictions of future events. We have based the forward-looking statements contained in this Annual Report primarily on our current expectations and projections about future events and trends that we believe may affect our business, financial condition, results of operations, and prospects. The outcome of the events described in these forward-looking statements is subject to risks, uncertainties, and other factors described in Item 1A. “Risk Factors” and elsewhere in this Form 10-K. This Annual Report may include market data and certain industry data and forecasts, which we may obtain from internal company surveys, market research, consultant surveys, publicly available information, reports of governmental agencies and industry publications, articles and surveys. Industry surveys, publications, consultant surveys and forecasts generally state that the information contained therein has been obtained from sources believed to be reliable, but the accuracy and completeness of such information is not guaranteed.
Moreover, it is not possible for us to predict all risks and uncertainties that could have an impact on the forward-looking statements contained or incorporated by reference herein. We cannot assure you that the results, events, and circumstances reflected in the forward-looking statements will be achieved or occur, and actual results, events, or circumstances could differ materially from those described in the forward-looking statements.
The forward-looking statements made or incorporated by reference in this Annual Report relate only to events as of the date on which the statements are made. We undertake no obligation to update any forward-looking statements made or incorporated by reference in this Annual Report to reflect events or circumstances after the date hereof, respectively, or to reflect new information or the occurrence of unanticipated events, except as required by law.
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COMMONLY USED ABBREVIATIONS AND DEFINED TERMS
Unless otherwise indicated or the context requires otherwise, the terms “Company,” “we,” “us,” and “our,” refer to CoJax Oil and Gas Corporation, a Virginia corporation, and its wholly-owned subsidiary, Barrister Energy, L.L.C., a Mississippi limited liability company (“Barrister”). In addition, below are abbreviations and definitions of certain terms used in this Annual Report commonly used in the oil and natural gas industry:
| ● | “ARO” means asset retirement obligation; |
| ● | “Bbl” means one stock tank barrel, of 42 U.S. gallons liquid volume; |
| ● | “Btu” means one British thermal unit, the quantity of heat required to raise the temperature of a one-pound mass of water by one degree of Fahrenheit; |
| ● | “Basin” means a large natural depression on the earth’s surface in which sediments generally brought by water accumulate; |
| ● | “Commission” or “S.E.C.” means the U.S. Securities and Exchange Commission; | |
| ● | “Company Oil Rights” means the crude oil and natural gas exploration and production leases and rights owned or controlled by the Company (as more fully described under “Business – Company Oil Rights” below). |
| ● | “Completion” means the process of treating a drilled well followed by the installation of permanent equipment for the production of natural gas or oil, or in the case of a dry hole, the reporting of abandonment to the appropriate agency; |
| ● | “COP” means Central Operating, L.L.C., a Mississippi limited liability company |
| ● | “Deep drill well” or “deep drilling rig” means a drilled oil well approximately 10,000’ deep or a drilling rig capable of drilling to depths of approximately 10,000 feet or more; |
| ● | “Developed acreage” means the number of acres that are allocated or assignable to productive wells or wells capable of production; |
| ● | “Development well” means a well drilled within the proved area of a crude oil, NGL, or natural gas reservoir to the depth of a stratigraphic horizon (rock layer or formation) known to be productive for the purpose of extracting proved crude oil, NGL, or natural gas reserves. |
| ● | “Differential” means the difference between a benchmark price of crude oil and natural gas and the wellhead price received. |
| ● | “Exchange Act” means the Securities Exchange Act of 1934, as amended. |
| ● | “Field” means an area consisting of a single reservoir or multiple reservoirs all grouped on, or related to, the same individual geological structural feature or stratigraphic condition. The field name refers to the surface area, although it may refer to both the surface and the underground productive formations; |
| ● | “Formation” means a layer of rock that has distinct characteristics that differ from nearby rock; |
| ● | “Gas” means natural gas; |
| ● | “Gulf States Drill Region” means the geographic area(s) where oil and gas leases, drilling, and production rights, are located.. The Gulf States Drill Region extends from Texas to the Florida Panhandle along the Gulf Coast Region – both onshore and offshore. Prolific oil and natural gas production from variable formations and depths exists within this geographic boundary. |
| ● | “Hydraulic fracturing” means the technique of improving a well’s production by pumping a mixture of fluids into the formation and rupturing the rock, creating an artificial channel. As part of this technique, sand or other material may also be injected into the formation to keep the channel open, so that fluids or natural gases may more easily flow through the formation; |
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| ● | “Mcf” means one thousand cubic feet of natural gas; |
| ● | “MMBtu” means one million Btu; |
| ● | “MMcf” means one million cubic feet of natural gas; |
| ● | “NGL” means natural gas liquids; |
| ● | “NYMEX” means the New York Mercantile Exchange; |
| ● | “Oil” means crude oil that has not been refined or processed; |
| ● | “OPEC” means the Organization of Petroleum Exporting Countries; |
| ● | “Possible reserves” means the additional reserves which analysis of geoscience and engineering data suggest are less likely to be recoverable than probable reserves; |
| ● | “Probable reserves” means the additional reserves which analysis of geoscience and engineering data indicate are less likely to be recovered than proved reserves but which together with proved reserves, are as likely as not to be recovered; |
| ● | “Productive well” means a well that is found to be capable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of the production exceed production expenses and taxes; |
| ● | “Proved reserves” means the quantities of crude oil, NGLs and natural gas, which by analysis of geosciences 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; |
| ● | “Prospect” means a specific geographic area which, based on supporting geological, geophysical, or other data and also preliminary economic analysis using reasonably anticipated prices and costs, is deemed to have the potential for the discovery of commercial hydrocarbons; |
| ● | “Recompletion” means 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” means 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 separate from other reservoirs; |
| ● | “Resources” means quantities of oil and gas estimated to exist in naturally occurring accumulations. A portion of the resources may be estimated to be recoverable, and another portion may be considered to be unrecoverable. Resources include both discovered and undiscovered accumulations; |
| ● | “Securities Act” means the Securities Act of 1933, as amended; |
| ● | “Smackover Trend” means a regional boundary where the Smackover formation exists below the surface of the ground. |
| ● | “Spacing” means the distance between wells producing from the same reservoir. Spacing is often expressed in terms of acres, e.g., 40-acre spacing, and is often established by regulatory agencies; |
| ● | “Undeveloped acreage” means acreage on which wells have not been drilled or completed to a point that would permit the production of economic quantities of crude oil, NGLs, and natural gas, regardless of whether such acreage contains proved reserves. Undeveloped acreage includes net acres held by operations until a productive well is established in the spacing unit; |
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| ● | “Unit” means the joining of all or substantially all interests in a reservoir or field, rather than a single tract, to provide for development and operation without regard to separate property interests. Also, the area covered by a unitization agreement; |
| ● | “Working interest” means the right granted to the lessee of a property to explore for and to produce and own natural gas or other minerals. The working interest owners bear the exploration, development, and operating costs on either a cash, penalty or carried basis; |
| ● | “WTI” means West Texas Intermediate, a light, sweet blend of oil produced from the fields in West Texas. |
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PART I
ITEM 1. BUSINESS
Overview
We are an early-stage development oil and gas company seeking to become an independent energy company. Our assets and principal properties are located in the Gulf States Drill Region, where we target acquisition and subsequent exploitation and development of crude oil, including acquisitions of hydrocarbon revenues and underlying oil and gas exploration and production rights. We believe that we can establish a profitable niche in crude oil production due to the quality of the light sweet crude oil produced from the Gulf States Drill Region, which is cheaper to refine than crude oil from other regions of the U.S. and Canada.
The Company was incorporated in the Commonwealth of Virginia on November 13, 2017, and started its operations on November 17, 2020, upon an acquisition (the “Barrister Acquisition”) of all outstanding capital of Barrister, including all of Barrister’s crude oil and natural gas exploration and production leases and rights owned or controlled by Barrister. In consideration for the Barrister Acquisition, the Company issued 3,650,000 shares of the Company’s common stock, $0.01 par value per share (the “Common Stock”) to the members of Barrister and assumed Barrister’s debt obligations to Central Operating, LLC (“COP”) in principal amount of $2,700,000, which was discharged on November 16, 2021 pursuant to a debt exchange agreement between the Company and COP in exchange for the issuance of 1,350,000 shares of the Company’s Common Stock to COP. Currently we are producing very limited crude oil production from limited oil drilling operations as a result of the Barrister Acquisition. It is insufficient to fund new acquisitions or drilling without additional funding or equity transactions.
On November 8, 2022, the Company, through Barrister, its wholly-owned subsidiary, acquired from Taxodium Energy, LLC, a Mississippi limited liability company (“Taxodium”), 100% ownership, right, title and interest in certain properties located in Mississippi and Alabama, including all oil and gas leases, interests, royalties, overriding royalties, subleases, fee estates, net profit interest, and carried interests (collectively, “NONOP Assets”) pursuant to the Assignment, Bill of Sale and Conveyance, dated October 31, 2022, executed by Taxodium. This transaction became effective on October 1, 2022, for accounting purposes, based on when the Company obtained control of the acquired assets.
On December 2, 2022, the Company, through Barrister, acquired from Taxodium a 100% ownership, right, title and interests in additional properties located in Mississippi, including certain wells, facilities, the oil gas and mineral leases, together with all surface and subsurface and all operating rights, working interest, and net revenue interest arising out of such leases and rights (collectively, “Buckley Assets”) pursuant to the Assignment, Bill of Sale and Conveyance, dated December 2, 2022, executed by Taxodium and Barrister.
While the Company acquired these new properties, including drilling wells, currently, these wells have very limited productions, not sufficient for the Company to become profitable.
On May 31, 2024, the Company, through Barrister, its wholly-owned subsidiary, completed the acquisition of certain various mineral and oil and gas properties, lands and leases located in Mississippi and related assets from Liberty Operating Company, LLC (“Liberty”) pursuant to the Assignment and Bill of Sale, entered into and executed by Barrister and Liberty on May 31, 2024. The Acquisition has an effective date of May 1, 2024, for accounting purposes.
On August 29, 2024, the Company, through Barrister, its wholly-owned subsidiary, completed the acquisition of certain various mineral and oil and gas properties, lands and leases located in Mississippi and related assets from Liberty pursuant to the Assignment and Bill of Sale, entered into and executed by Barrister and Liberty on August 29, 2024. The Acquisition has an effective date of July 1, 2024, for accounting purposes.
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Our Growth Strategy
The Company is seeking to acquire existing underexploited conventional oil and natural gas producing properties and rights in the Gulf States Drill Region. These properties typically contain upside potential through operational efficiencies and recompletions to behind pipe zones and infill drilling. Our long-term goal is to create shareholder value by identifying and assembling a portfolio of low-risk assets with attractive economic profiles. Our ability to implement our business plan is subject, in part, on our ability to timely raise adequate and affordable funding from investors or lenders for establishing acquisitions. Our first acquisition was Barrister, followed by the acquisition of NONOP Assets and Buckley Assets in the fourth quarter of 2022. In 2024, we acquired the non-operated interests of Liberty Operating Company, LLC in two separate fields located within Mississippi. Our efforts now involve raising sufficient working capital to perform planned well work on existing properties in order to increase gross production and cash flow.
The Company will continue to seek acquisitions that can be obtained in exchange for the Company’s stock or under an earn-out arrangement. Preference is given to existing producing properties or companies wishing to divest all their assets. The acquisition of a company that holds oil and leases rights has the perceived advantages of acquiring several oil leases and rights and existing drilling operations with in-place management in a single transaction.
Our teaming approach is also designed to facilitate rapid growth by bringing necessary expertise into operations from available contractors. Our ability to realize profitability from oil and gas production may also depend upon the success of drill wells, engaging necessary operations expertise, and market price for crude oil and natural gas remaining at attractive levels. If we have adequate funding and/or sufficient cash flow, then we may seek to drill for oil in other assignee or leasehold interests or, alternatively, in oil and gas assignee or leasehold interests or properties owned by our potential affiliates or teaming partners. The Company currently allows the purchasers to market its crude oil and natural gas production, whether current or future, on a month-to-month basis.
If the production of oil increases from the properties in which the Company obtains its oil rights, the Company will have to expand the marketing efforts by engaging a person or firm to seek out new customers for the oil production in case the current customer base is unable or unwilling to purchase increased oil production. The cost means and extent of any enhanced future marketing effort will depend on the amount of increased oil production, the then-current market for oil, and the potential customer base for the oil production. If the existing customer base will not purchase increased oil production, then the engagement of a dedicated marketing person who engages in direct marketing, by telephone and internet, of potential customers for oil production may be required for the sale of any future increase of oil production.
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Competitive Strengths
Use of Contractors
Our strategy is to develop our assets in a manner that generates sustainable cash flow and improves margins and operating efficiencies while improving our environmental, social and governance and safety performance. The Company relies on the extensive experience of William R. Downs, our Chief Executive Officer, who has more than 42 years of experience in the oil and gas industry. In addition, the Company utilizes experienced contractors, including former members of Barrister, who have significant oil and gas production experience in the Gulf States Drill Region. This approach is particularly valuable during the initial phases of implementing our business plan. We believe this contractor model is the most efficient and cost-effective way to operate as a small independent oil and gas producer, enabling us to leverage expert drilling and production personnel without incurring the high overhead of full-time employees. Currently, we engage COP and Taxodium as our contractors to manage drilling storage and production operations for our oil rights. These contractors bring extensive experience with operational and administrative expertise and provide the skilled personnel necessary to handle daily crude oil production. With adequate funding, we plan to expand this teaming model to attract and retain experienced oil industry engineers and production specialists. Their role will be to identify acquisitions and drill sites and operate wells efficiently to achieve industry-leading production rates.
Seasonality
Our drill sites in the Gulf States Drill Region allow for year-round drilling. However, adverse weather conditions can affect drilling, completion, and field operations, as well as third-party midstream and downstream pipeline operations, thereby influencing overall production volumes. which can impact overall production volumes. Variations in seasonal weather patterns can either lessen or intensify these impacts, and extreme weather events may temporarily constrain our operations.
Title to Oil and Natural Gas Properties
In the oil and gas industry, it is customary to conduct only a preliminary review of title to undeveloped oil and natural gas leases at acquisition. More extensive title examinations are typically performed when we prepare to develop the leases or acquire producing properties. In future acquisitions, we will conduct title examinations on material portions of such properties in a manner generally consistent with industry practice. The properties we have acquired may be subject to certain imperfections in title, encumbrances, easements, servitudes or other restrictions, none of which, in management’s opinion, will materially restrict our operations.
Competition
The Company competes with many companies of all sizes in the Gulf States Drill Region and adjacent areas. Many of these competitors have extensive operational histories, seasoned management, established market share, and profitable operations. They also possess significant oil and gas fields or leases to exploit and the funding to explore new fields or acquire mature ones. There is also an established oil and gas production industry in northern Alaska and in North Dakota and western Canada. Many of our competitors not only explore for and produce oil and natural gas, but also have midstream and further downstream operations and market a variety of hydrocarbon products on a regional, national or worldwide basis. In addition, oil and natural gas compete with other forms of energy available to customers, primarily based on price. Oil and natural gas compete with alternative energy sources—such as wind, solar, coal, and fuel oils—primarily on price. Changes in energy availability, pricing, market conditions, and regulatory factors may affect demand.
The Company has a limited operating history of its business operation and lacks the financial, technical, and manpower resources, proven crude oil reserves, and distribution channels of its competitors. The Company’s current production levels are modest enough that they do not attract significant attention from competitors, which allows it to operate as a small producer of oil and gas without competitive pressures. If oil production increase significantly, we may face stiffer competition from other small independent oil producers. Any increase in competitive pressure would likely necessitate a dedicated, full-time marketing effort.
Company Oil Rights
Description of Oil Properties and Oil Production Operations. The Company’s current oil and gas assets primarily consist of non-operating interests. Nevertheless, production from these assets has significantly enhanced our operational capability.
As shown in the tables below, production has significantly improved following the asset acquisitions in the fourth quarter of 2022. However, the Company will not be able to increase production until sufficient financial resources are secured through debt and equity financing. Additionally, if production levels cannot be restored to previous benchmarks, the Company may need to write down some of these assets.
The Smackover Trend. The Smackover trend is a belt of Late Jurassic carbonate, evaporite, and clastic rocks that rims the Gulf Coast of the United States. It spans from Texas to Arkansas and extends through Louisiana, Mississippi, Southwest Alabama, and the Florida panhandle. Stratigraphic and geochemical data indicate that the oil and gas were generated from algae-rich lime mudstones. The trend was named after the Smackover oil field, which was discovered in Union County, Arkansas, in 1937.
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Current Barrister Energy Properties. As of the date of this Annual Report, we have interests in 55 wells. In the fourth quarter of 2022, we acquired interest in 29 of those wells. In the second and third quarters of 2024, we acquired interest in 15 and 9 of those wells, respectively.
The table below summarizes production, average production prices, and average production costs by final product sold for the last three years. All production during the three years presented occurred in the United States.
| For the Year Ended December 31, | ||||||||||||
| 2024 | 2023 | 2022 | ||||||||||
| Net Production: | ||||||||||||
| Oil (Bbl) | 14,220 | 12,664 | 4,132 | |||||||||
| Natural Gas (Mcf) | 225 | 4,940 | 4,106 | |||||||||
| Total (BOE) | 14,257 | 13,488 | 4,816 | |||||||||
| Average Production Prices: | ||||||||||||
| Oil (Bbl) | $ | 71.38 | $ | 79.61 | $ | 88.85 | ||||||
| Natural Gas (Mcf) | $ | 4.54 | $ | 2.88 | 7.60 | |||||||
| Average Production Costs | ||||||||||||
| Production Costs (per BOE) (1) | $ | 25.05 | $ | 18.43 | $ | 66.67 | ||||||
Average production prices have been calculated by using sales quantities from Barrister’s production as the divisor. Average production costs have been computed by using net production quantities for the divisor. The volumes of crude oil and natural gas liquids (“NGL”) production used for this computation are shown in the oil and gas production table. The volumes of natural gas used in the calculation are the production volumes of natural gas available for sale and are also shown. Gas is converted to an oil-equivalent basis at six million cubic feet per one thousand barrels.
| (1) | The production cost (per BOE) for the year ended December 31, 2022 was updated to reflect certain lease operating expenses not previously included in the calculation. |
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Oil and Gas Properties, Wells, Operations, and Acreage
Gross and Net Productive Wells
| Year-End 2024 | Year-End 2023 | Year-End 2022 | |||||||||||||||||||||||
| Oil | Gas | Oil | Gas | Oil | Gas | ||||||||||||||||||||
| Gross | Net | Gross | Net | Gross | Net | Gross | Net | Gross | Net | Gross | Net | ||||||||||||||
| Gross and Net Productive Wells | |||||||||||||||||||||||||
| Consolidated Subsidiaries | |||||||||||||||||||||||||
| United States | 55 | 28 | — | — | 30 | 6 | — | — | 32 | 7 | — | — | |||||||||||||
| Total Consolidated Subsidiaries | 55 | 28 | — | — | 30 | 6 | — | — | 32 | 7 | — | — | |||||||||||||
| Total gross and net productive wells | 55 | 28 | — | — | 30 | 6 | — | — | 32 | 7 | — | — | |||||||||||||
Gross and Net Developed Acreage
| Year-End 2024 | Year-End 2023 | Year-End 2022 | |||||||||||
| Gross | Net | Gross | Net | Gross | Net | ||||||||
| (acres) | |||||||||||||
| Gross and Net Developed Acreage | |||||||||||||
| Consolidated Subsidiaries | |||||||||||||
| United States | 8,004 | 3,437 | 5,208 | 782 | 6,208 | 901 | |||||||
| Total Consolidated Subsidiaries | 8,004 | 3,473 | 5,208 | 782 | 6,208 | 901 | |||||||
| Total gross and net developed acreage | 8,004 | 3,437 | 5,208 | 782 | 6,208 | 901 | |||||||
Separate acreage data for oil and gas are not maintained because, in many instances, both are produced from the same acreage.
Gross and Net Undeveloped Acreage
| Year-End 2024 | Year-End 2023 | Year-End 2022 | |||||||||||
| Gross | Net | Gross | Net | Gross | Net | ||||||||
| (acres) | |||||||||||||
| Gross and Net Undeveloped Acreage | |||||||||||||
| Consolidated Subsidiaries | |||||||||||||
| United States | 3,244 | 612 | 2,600 | 26 | 2,600 | 26 | |||||||
| Total Consolidated Subsidiaries | 3,244 | 612 | 2,600 | 26 | 2,600 | 26 | |||||||
| Total gross and net undeveloped acreage | 3,244 | 612 | 2,600 | 26 | 2,600 | 26 | |||||||
Separate acreage data for oil and gas are not maintained because, in many instances, both are produced from the same acreage.
Our investment in developed and undeveloped acreage comprises numerous leases. The List of Leases is included as Exhibit 99.1 to this Annual Report. The terms and conditions under which the Company maintains exploration and production rights to the acreage are property-specific, contractually defined, and vary significantly by property. Work programs are designed to ensure that the exploration potential of any property is thoroughly evaluated before expiration. In some instances, we may elect to relinquish acreage in advance of the contractual expiration date if the evaluation process is complete and there is not a business justification for an extension. In cases where additional time may be required to evaluate acreage fully, the Company has generally been successful in obtaining extensions. The scheduled expiration of leases and concessions for undeveloped acreage over the next three years is not expected to have a material adverse effect on the Company.
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Government Regulation
Oil and natural gas operations such as ours are subject to various types of legislation, regulation, and other legal requirements enacted by governmental authorities. This legislation and regulation affecting the oil and natural gas industry are under constant review for amendment or expansion. Some of these requirements carry substantial penalties for failure to comply. The regulatory burden on the oil and natural gas industry increases our cost of doing business and, consequently, can affect our profitability. Because these laws, rules and regulations are frequently amended or reinterpreted and new laws, rules and regulations are promulgated, we are unable to predict the future cost or impact of complying with the laws, rules and regulations to which we are, or will be required to comply.
Regulation of Drilling and Production
The production of oil and natural gas is subject to regulation under a wide range of local, state, and federal statutes, rules, orders, and regulations. Federal, state, and local statutes and regulations require permits for drilling operations, drilling bonds, and reports concerning operations. The trend in oil and natural gas regulation has been to increase regulatory restrictions and limitations on such activities. Any changes in, or more stringent enforcement of, these laws and regulations may result in delays or restrictions in permitting or development of projects or more stringent or costly construction, drilling, water management or completion activities or waste handling, storage, transport, remediation, or disposal emission or discharge requirements which could have a material adverse effect on the Company. In January 2021, the Biden administration issued: (1) an order signed by the acting Secretary of the Interior providing for a 60-day pause (ii) an executive order signed by President Biden instruction the Department of the Interior to pause new oil and natural gas leases on public lands pending completion of a comprehensive review and consideration of federal oil and natural gas permitting and leasing practices (together, the “Biden Administration Federal Lease Orders”). The U.S. District Court for the District of Louisiana enjoined the pause within 13 states, including Texas, in August 2022. The Department of the Interior has recently resumed lease sales in several states. On January 20, 2021, the Biden Administration issued (i) an order providing for a 60-day moratorium on new oil and gas leasing and drilling permits on federal land, limiting the authority of local offices of the BLM to issue new leases and grant federal drilling permits and certain extensions, sundries, rights-of-way and other necessary approvals for the development of federal oil and natural gas leases; and (ii) and executive order signed by President Biden instructing the Department of the Interior to pause new oil and natural gas leases on public lands, pending a full review of the federal leasing and permitting program. While we do not have a significant federal land acreage position at 240 net acres, these actions could have a material adverse effect on the Company and our industry.
Currently, all our properties and operations are in Alabama and Mississippi, which have regulations governing conservation matters, such as the unitization or pooling of oil and natural gas properties, the establishment of maximum allowable rates of production from oil and natural gas wells, the regulation of well spacing, and plugging and abandonment of wells. The effect of these regulations is to limit the amount of oil and natural gas that we can produce from our wells and to limit the number of wells or the locations at which we can drill, although we can apply for exceptions to such regulations or to have reductions in well spacing. Moreover, Alabama and Mississippi impose a production or severance tax with respect to the production and sale of oil, natural gas, and natural gas liquids within their jurisdictions. Failure to comply with these rules and regulations can result in substantial penalties. Our competitors in the oil and natural gas industry are subject to the same regulatory requirements and restrictions that affect our operations.
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Regulation of Transportation of Oil
Sales of crude oil, condensate, and natural gas liquids are not currently regulated and are made at negotiated prices; however, Congress could reenact price controls in the future.
Our sales of crude oil are affected by the availability, terms, and cost of transportation. The transportation of oil in common carrier pipelines is also subject to rate regulation. The Federal Energy Regulatory Commission, or the FERC, regulates interstate oil pipeline transportation rates under the Interstate Commerce Act. Intrastate oil pipeline transportation rates are subject to regulation by state regulatory commissions. The basis for intrastate oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate oil pipeline rates, varies from state to state. Insofar as effective interstate and intrastate rates are equally applicable to all comparable shippers, we believe that the regulation of oil transportation rates will not affect our operations in any way that is of material difference from those of our competitors. Further, interstate and intrastate common carrier oil pipelines must provide service on a non-discriminatory basis. Under this open access standard, common carriers must offer service to all shippers requesting service on the same terms and under the same rates. When oil pipelines operate at full capacity, access is governed by pro-rationing provisions set forth in the pipelines’ published tariffs. Accordingly, we believe that access to oil pipeline transportation services generally will be available to us to the same extent as to our competitors.
Regulation of Transportation and Sale of Natural Gas
Historically, the transportation and sale for resale of natural gas in interstate commerce have been regulated pursuant to the Natural Gas Act of 1938, the Natural Gas Policy Act of 1978, and regulations issued under those Acts by the FERC. In the past, the federal government has regulated the prices at which natural gas could be sold. While sales by producers of natural gas can currently be made at uncontrolled market prices, Congress could reenact price controls in the future.
Since 1985, the FERC has endeavored to make natural gas transportation more accessible to natural gas buyers and sellers on an open and non-discriminatory basis. The FERC has stated that open access policies are necessary to improve the competitive structure of the interstate natural gas pipeline industry and to create a regulatory framework that will put natural gas sellers into more direct contractual relations with natural gas buyers by, among other things, unbundling the sale of natural gas from the sale of transportation and storage services. Although the FERC’s orders do not directly regulate natural gas producers, they are intended to foster increased competition within all phases of the natural gas industry. We cannot accurately predict whether the FERC’s actions will achieve the goal of increasing competition in markets in which our natural gas is sold. Therefore, we cannot provide any assurance that the less stringent regulatory approach established by the FERC will continue. However, we do not believe that any action taken will affect us in a way that materially differs from the way it affects other natural gas producers.
Intrastate natural gas transportation is subject to regulation by state regulatory agencies. The basis for intrastate regulation of natural gas transportation and the degree of regulatory oversight and scrutiny given to intrastate natural gas pipeline rates and services varies from state to state. Insofar as such regulation within a particular state will generally affect all intrastate natural gas shippers within the state on a comparable basis, we believe that the regulation of similarly situated intrastate natural gas transportation in any states in which we operate and ship natural gas on an intrastate basis will not affect our operations in any way that is of material difference from those of our competitors.
Environmental, Health and Safety Regulations
The exploration, development, production, gathering and processing of oil and natural gas are subject to various federal, state and local environmental laws and regulations. These laws and regulations can increase the costs of planning, designing, drilling, completing and operating oil and natural gas wells, midstream facilities and produced water injection and disposal wells. Our activities are subject to a variety of environmental laws and regulations, including, but not limited to: the Oil Pollution Act of 1990 (the “OPA 90”), the Clean Water Act (the “CWA”), the Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), the Resource Conservation and Recovery Act (“RCRA”), the Clean Air Act (the “CAA”) and the Occupational Safety and Health Act (“OSHA”), as well as comparable state statutes and regulations. We also may be subject to regulations governing the handling, transportation, storage and disposal of wastes generated by our activities and naturally occurring radioactive materials (“NORM”) that may result from our oil and natural gas operations. Administrative, civil and criminal fines and penalties may be imposed for noncompliance with these environmental laws and regulations, and violations and liability with respect to these laws and regulations could also result in remedial clean-ups, natural resource damages, permit modifications or revocations, operational interruptions or shutdowns and other liabilities. Additionally, these laws and regulations require the acquisition of permits or other governmental authorizations before undertaking some activities, may limit or prohibit other activities because of protected wetlands, areas or species and require investigation and cleanup of pollution. These laws, rules and regulations may also restrict the production rate of oil and natural gas or limit the injection of produced water into disposal wells below the rates that would otherwise be possible. We expect to remain in compliance in all material respects with currently applicable environmental laws and regulations and do not expect that these laws and regulations will have a material adverse impact on the Company.
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The OPA 90 and its regulations impose requirements on “responsible parties” related to the prevention of crude oil spills and liability for damages resulting from oil spills into or upon navigable waters, adjoining shorelines or on the exclusive economic zone of the United States. A “responsible party” under the OPA 90 may include the owner or operator of an onshore facility. The OPA 90 subjects responsible parties to strict, joint and several financial liability for removal and remediation costs and other damages, including natural resource damages, caused by an oil spill that is covered by the statue. Failure to comply with the OPA 90 may subject a responsible party to civil or criminal enforcement action.
The CWA and comparable state laws impose restrictions and strict controls regarding the discharge of produced waters, fill materials and other materials into navigable waters. These controls have become more stringent over the years, and it is possible that additional restrictions will be imposed in the future. Permits are required to discharge pollutants into certain state and federal waters and to conduct construction activities in those waters and wetlands. The CWA and comparable state statutes provide for civil, criminal and administrative penalties for any unauthorized discharges of oil and other pollutants and impose liability for the costs of removal or remediation of contamination resulting from such discharges. In September 2015, a rule issued by the EPA and U.S. Army Corp of Engineers (the “Corps”) to revise the definition of “waters of the United States” (“WOTUS”) for all CWA programs, thereby defining the scope of the EPA’s and the Corp’s jurisdiction, became effective. The EPA rescinded this rule in 2019 and promulgated the Navigable Waters Protection Rule (the “NWPR”) in 2020. The NWPR was viewed as narrowing the scope of WOTUS as compared to the 2015 rule. In August 2021, the U.S. District Court for the District of Arizona vacated and remanded the NWPR. On January 18, 2023, the EPA and the Corps jointly issued a final rule revising the definition of WOTUS that largely returned to the pre-2015 regulatory regime. On September 8, 2023, the U.S. Supreme Court issued a decision limiting the scope of federal jurisdiction over wetlands only to those that have a continuous surface connection to water bodies. On August 29, 2023, the EPA and the Corps jointly issued a final rule, effective immediately, aligning the regulatory definition of WOTUS with the Supreme Court’s ruling.
CERCLA, also known as the “Superfund” law, imposes liability, without regard to fault or the legality of the original conduct, on various classes of persons that are considered to have contributed to the release of a “hazardous substance” in the environment. These persons include the owner or operator of the site where the release occurred and companies that disposed of, or arranged for the disposal of, the hazardous substances found at the site. Persons who are responsible for releases of hazardous substances under CERCLA may be subject to joint and several liability for the costs of cleaning up the hazardous substances and for damages to natural resources. In addition, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by hazardous substances released into the environment. Although CERCLA generally exempts petroleum from the definition of hazardous substances, our operations may in the future, involve the use or handling of materials that are classified as hazardous substances under CERCLA. Each state also has environmental cleanup laws analogous to CERCLA. RCRA and comparable state and local statues govern the management, including treatment, storage and disposal, of both hazardous and nonhazardous solid wastes. Hazardous wastes are subject to more stringent and costly disposal requirements than nonhazardous wastes.
The CAA, as amended, restricts the emission of air pollutants from many sources, including oil and natural gas production. In addition, certain states have comparable legislation, which may be more restrictive than the CAA. These laws and any implementing regulations impose stringent air permit requirements and require us to obtain pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions, or to use specific equipment or technologies to control emissions. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with air permits or other requirements of the CAA and associated state laws and regulations. On August 16, 2022, the Inflation Reduction Act created the Methane Emissions Reduction Program to incentivize methane emission reductions and impose a fee on greenhouse gas emissions from certain facilities that exceed specified emissions levels.
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Internationally, in 2015, the United States participated in the United Nations Conference on Climate Change, which led to the creation of the Paris Agreement. The Paris Agreement, which was signed by the United States in April 2016, requires countries to review and “represent a progression” in their intended nationally determined contributions (“NDC”), which set greenhouse gas emission reduction goals, every five years beginning in 2020. The United States exited the Paris Agreement in November 2020, but rejoined the agreement effective February 19, 2021. In April 2021, the United States made its NDC submittal, setting an emissions reduction goal of a 50 to 52% reduction from 2005 levels in economy-wide net greenhouse gas pollution in 2030. Further, in November 2021, the United States and other countries entered into the Glasgow Climate Pact, which includes a range of measures designed to address climate change, including but not limited to the phase-out of fossil fuel subsidies, reducing methane emissions 30% by 2030 and cooperating toward the advancement of the development of alternative sources of energy.
Any changes that result in more stringent and costly waste handling, storage, transport, disposal, cleanup or operating requirements could materially adversely affect our operations and financial condition, as well as those of the oil and natural gas industry in general. For instance, in January 2021, President Biden issued Executive Order which directed a government-wide effort to address climate change by reducing greenhouse gas emissions and achieving net-zero global carbon emissions by 2050 or before. That effort is designed to infuse climate policy in all aspects of federal decision-making, including specific directives that touch on foreign policy, national security, financial regulation, federal procurement, infrastructure, and environmental justice among other things. Based on this Executive Order and other findings, the EPA has begun adopting and implementing a comprehensive suite of regulations to restrict emissions of greenhouse gases under existing provisions of the CAA. On December 2, 2023, the EPA issued a prepublication version of a final rule to regulate emissions from oil and natural gas sources that includes NSPS to limit greenhouse gas and volatile organic compound emissions for new, modified or reconstructed sources, as well as emissions guidelines for states to follow when establishing plans to limit methane emissions from existing sources. Additionally, on November 17, 2023, the EPA issued a final rule that enables states to implement more stringent methane emissions standards than the federal guidelines require. As another example, in January 2023, the EPA announced a proposed consent decree that, if finalized as proposed, would establish a December 10, 2024 deadline for the EPA to review and propose revisions to the National Emission Standards for Hazardous Air Pollutants (“NESHAP”) for oil and natural gas production facilities and natural gas transmission and storage facilities, which may require us to make additional changes to our operations. Legislative and regulatory initiatives related to climate change and greenhouse gas emissions could, and likely would, require us to incur increased operating costs adversely affecting our profits and could adversely affect demand for the oil and natural gas we produce, depressing the prices we receive for oil and natural gas.
In the course of our routine oil and natural gas operations, surface spills and leaks, including casing leaks, of oil, produced water or other materials may occur, and we may incur costs for waste handling and environmental compliance. It is also possible that our oil and natural gas operations may require us to manage NORM. NORM is present in varying concentrations in sub-surface formations, including hydrocarbon reservoirs, and may become concentrated in scale, film and sludge in equipment that comes in contact with crude oil and natural gas production and processing streams. Some states, including Texas and Louisiana, have enacted regulations governing the handling, treatment, storage and disposal of NORM.
We are subject to the requirements of OSHA and comparable state statutes. The OSHA Hazard Communication Standard, the “community right-to-know” regulations under Title III of the federal Superfund Amendments and Reauthorization Act and similar state statutes require us to organize information about hazardous materials used, released or produced in our operations. Certain of this information must be provided to employees, state and local governmental authorities and local citizens. We are also subject to the requirements and reporting set forth in OSHA workplace standards.
We have not in the past been, and do not anticipate in the near future to be, required to expend amounts that are material in relation to our total capital expenditures as a result of environmental laws and regulations, but since these laws and regulations are periodically amended, we are unable to predict the ultimate cost of compliance. We have no assurance that more stringent laws and regulations protecting the environment will not be adopted or that we will not otherwise incur material expenses in connection with environmental laws and regulations in the future. We may be unable to pass on such increased compliance costs to our customers.
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Principal Executive Offices
Our principal executive office is located at 4830 Line Avenue, Suite 152, Shreveport, Louisiana, 71106, and our telephone number is (703) 479-8538. We rent our principal executive offices under a month-to-month lease for a monthly rental of $26. The Company website is www.cojaxoilandgas.com.
Employees
We currently have two full-time employees: William Downs, our Chief Executive Officer, and Jeffrey J. Guzy, our Chief Financial Officer. The officers devote the number of hours necessary to perform their duties, and each officer, in his sole discretion, determines the extent of the time commitment.
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ITEM 1A. RISK FACTORS
RISK FACTORS
An investment in our common stock involves a high degree of risk. You should carefully consider the risks and uncertainties described below before making a decision to invest in our common stock. The risks and uncertainties discussed below are not the only ones we face. Risks could also harm our business, operating results, financial condition, or prospects, and uncertainties not currently known to us or that we currently do not believe are material, and these risks and uncertainties could result in a complete loss of your investment. Prior to the Barrister Acquisition, we did not have revenue-generating operations that will fund our operating overhead. While we began to generate revenue following the Barrister Acquisition, our business, operating results, financial condition, or prospects could be materially and adversely affected by any of these risks and uncertainties. In assessing the risks and uncertainties described below, you should also refer to the other information contained herein, including our consolidated financial statements, pro forma financial statements, and the related notes thereto.
RISKS RELATED TO OUR BUSINESS
Risks Related to the Oil & Natural Gas Industry
Oil and natural gas prices are volatile, and any sustained decline in oil market prices could adversely affect the Company’s business, financial condition, results of operations, and its ability to meet capital expenditure obligations and financial commitments.
Our success is highly dependent on prices for oil and natural gas, which have in recent years been, and we expect will continue to be, extremely volatile. Oil is a commodity, and its price may fluctuate widely in response to relatively minor changes in the supply of and demand for oil and market uncertainty. Historically, oil prices have been volatile due to sensitivity to political and economic developments or crises. The prices we receive for oil production, and the levels of oil production, depend on numerous factors beyond our control, which include worldwide and regional economic conditions affecting the global supply and demand for oil, such as:
| ● | levels of production, domestic and worldwide inventories; |
| ● | the capacity of U.S. and international refiners to use U.S. supplies of oil, natural gas and NGLs |
| ● | the price and quantity of foreign imports of oil and their effect on U.S. oil producers; |
| ● | relative price and availability of alternative forms of energy; |
| ● | political and economic conditions in or affecting other oil-producing regions or countries, including the Middle East, Africa, South America, current invasion of Ukraine by Russia, which significantly affects global oil market price |
| ● | actions of the OPEC, its members, and other state-controlled oil companies relating to oil price and production controls, especially production disputes between Saudi Arabia and Russia, who often have different goals |
| ● | the level of global exploration, development, and production of oil |
| ● | the proximity, capacity, cost, and availability of oil gathering and transportation facilities; · |
| ● | localized and global oil supply and demand fundamentals and transportation availability |
| ● | the cost of exploring for, developing, producing, and transporting oil which cost may go up due to oil storage surpluses created by COVID-19 pandemic |
| ● | weather conditions and other natural disasters, and storms in the Gulf States Drilling Region appear to increase in intensity in the past five years |
| ● | technological advances affecting oil consumption, especially the growing production of electric-powered cars, trucks, and buses |
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| ● | the price and availability and consumer demand for alternative fuels to oil and reduction in the use of products that are made from oil, especially certain plastics, which demand is fueled by environmental concerns |
| ● | climate control legislation that increases the cost and lowers the demand for oil by providing incentives and tax benefits for use of non-oil fuels, and |
| ● | effect of existing U.S. federal, state, and local, and non-U.S. governmental regulation and taxes. |
These factors make it extremely difficult to predict future oil, natural gas and NGLs price movements with any certainty. During the three years ended December 31, 2024, NYMEX WTI prices ranged from a high of $123.64 per barrel on March 8, 2022, to a low of $65.75 per barrel on September 10, 2024, and NYMEX Henry Hub prices ranged from a high of $9.51 per MMBtu on August 17, 2022, to a low of $1.21 per MMBtu on November 11, 2024. We make price assumptions that are used for planning purposes, and a significant portion of our cash outlays, are largely fixed in nature. Accordingly, if commodity prices are below the expectations on which these commitments were based, our financial results are likely to be adversely and disproportionately affected because these cash outlays are not variable in the short term and cannot be quickly reduced to respond to unanticipated decreases in commodity prices. Specifically, prices of oil, and NGLs may adversely affect our revenues, cash flows, earnings and returns; our ability to attract capital to finance our operations and the cost of the capital; the profit or loss we incur in exploring for and developing our reserves; and the value of our oil and natural gas properties.
A substantial or extended decline in commodity prices may also reduce the amount of oil and natural gas that we can produce economically and cause a significant portion of our development projects to become uneconomic. This may result in our having to make significant downward adjustments to our estimated proved reserves. A reduction in production could also result in a shortfall in expected cash flows and require us to reduce capital spending, which could negatively affect our ability to replace our production and our future rate of growth, or require us to borrow funds to cover any such shortfall, which we may be unable to obtain at such time on satisfactory terms. Additionally, if we are required to curtail our drilling program, we may be unable to continue to hold leases that are scheduled to expire, which may further reduce our reserves. As a result, if oil and/or NGL prices experience a sustained period of weakness, our future business, financial condition, results of operations, liquidity, and ability to finance planned capital expenditures may be materially and adversely affected.
Our business is subject to climate-related transition risks, including evolving climate change legislation, fuel conservation measures, technological advances and negative shift in market perception towards the oil and natural gas industry, which could result in increased operating expenses and capital costs, financial risks and potential reduction in demand for oil and natural gas.
The governmental and regulatory bodies, as well as investors, consumers, industry and other stakeholders increasingly focus on combating climate change. This attention resulted in the enactment of climate change-related regulations, policies and initiatives, including alternative energy requirements, new fuel consumption standards, energy conservation and emissions reductions measures and responsible energy development; technological advances with respect to the generation, transmission, storage and consumption of energy, increased availability of, and increased demand from consumers and industry for, energy sources other than oil and natural gas (including wind, solar, nuclear, and geothermal sources as well as electric vehicles); and development of, and increased demand from consumers and industry for, lower-emission products and services (including electric vehicles and renewable residential and commercial power supplies) as well as more efficient products and services.
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These developments may in the future adversely affect the demand for products manufactured with, or powered by, petroleum products, as well as the demand for, and in turn the prices of, oil and natural gas products. Such developments may also adversely impact, among other things, our stock price and access to capital markets, and the availability to us of necessary third-party services and facilities that we rely on, which may increase our operational costs and adversely affect our ability to successfully carry out our business strategy. Climate change-related developments may also impact the market prices of or our access to raw materials such as energy and water and therefore result in increased costs to our business.
More broadly, the enactment of climate change-related regulations, policies and initiatives across the market at the government, corporate, and/or investor community levels may in the future result in increases in our compliance costs and other operating costs and have other adverse effects (e.g., greater potential for governmental investigations or litigation).
Seismic studies do not guarantee that oil or hydrocarbons are present or, if present, will produce in economic quantities.
Oil exploration and production companies, like we are, rely on seismic studies to assist in assessing prospective drilling opportunities on oil and gas properties, as well as on properties that a company may acquire. Such seismic studies are merely an interpretive tool and do not necessarily guarantee that hydrocarbons are present or, if present, will produce in economic or profitable quantities.
Restrictions on our ability to obtain, recycle and dispose of water may impact our ability to execute our drilling and development plans in a timely or cost-effective manner.
Water is an essential component of both the drilling and hydraulic fracturing processes. If drought conditions were to occur or demand for water were to outpace supply, our ability to obtain water could be impacted and in turn, our ability to perform hydraulic fracturing operations could be restricted or made more costly. If we are unable to obtain water to use in our operations from local sources, we may be unable to economically produce oil and natural gas, which could have an adverse effect on our financial condition, results of operations and cash flows. In addition, significant amounts of water are produced in our operations. Inadequate access to or availability of water recycling or water disposal facilities could adversely affect our production volumes or significantly increase the cost of our operations.
Participants in the oil and gas industry are subject to numerous laws that can affect the cost, manner, or feasibility of doing business.
Exploration and production activities in the oil and gas industry are subject to various laws and regulations. Any oil and gas exploration and production operated by the Company are or may become subject to numerous environmental and occupational health and safety laws and regulations that may be imposed domestically at the federal, regional, state, and local levels. The more significant of these environmental and occupational health and safety laws and regulations include the following:
| ● | The U.S. Clean Air Act, which restricts the emission of air pollutants from many sources and imposes various pre-construction, operational, monitoring, and reporting requirements, and the Environmental Protection Agency or “EPA” has relied upon as authority for adopting climate change regulatory initiatives relating to Green House Gases or “GHG” emissions. |
| ● | The U.S. Federal Water Pollution Control Act, also known as the Federal Clean Water Act, which regulates discharges of pollutants from facilities to state and federal waters and establishes the extent to which waterways are subject to federal jurisdiction and rulemaking as protected waters of the United States |
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| ● | The U.S. Oil Pollution Act of 1990, which subjects owners and operators of vessels, onshore facilities, and pipelines, as well as lessees or permittees of areas in which offshore facilities are located, to liability for removal costs and damages arising from an oil spill in waters of the United States |
| ● | The U.S. Comprehensive Environmental Response, Compensation and Liability Act of 1980, which imposes liability on generators, transporters, and arrangers of hazardous substances at sites where hazardous substance releases have occurred or are threatening to occur |
| ● | The U.S. Resource Conservation and Recovery Act, which governs the generation, treatment, storage, transport, and disposal of solid wastes, including hazardous wastes |
| ● | The U.S. Safe Drinking Water Act (“SDWA”), which ensures the quality of the nation’s public drinking water through the adoption of drinking water standards and control over the injection of waste fluids into below-ground formations that may adversely affect drinking water sources |
| ● | The U.S. Emergency Planning and Community Right-to-Know Act, requires facilities to implement a safety hazard communication program and disseminate information to employees, local emergency planning committees, and response departments on toxic chemical uses and inventories |
| ● | The U.S. Occupational Safety and Health Act, which establishes workplace standards for the protection of the health and safety of employees, including the implementation of hazard communications programs designed to inform employees about hazardous substances in the workplace, potentially harmful effects of these substances, and appropriate control measures |
| ● | The U.S. Endangered Species Act, restricts activities that may affect federally identified endangered and threatened species or their habitats through the implementation of operating restrictions or a temporary, seasonal, or permanent ban in affected areas |
| ● | The U.S. National Environmental Policy Act, requires federal agencies, including the Department of the Interior, to evaluate significant agency actions having the potential to affect the environment and that may require the preparation of environmental assessments and more detailed environmental impact statements that may be made available for public review and comment |
| ● | U.S. Department of Transportation regulations, which relate to advancing the safe transportation of energy and hazardous materials and emergency response preparedness. |
These environmental and occupational health and safety laws and regulations, including new or amended legal requirements, are expected to have a considerable effect on any expanded Company’s operations in terms of compliance costs.
In addition, regional, state, and local jurisdictions in the United States where the Company operates or may operate also have, or are developing or considering developing, similar environmental and occupational health and safety laws and regulations governing many of these same types of activities. The State of Alabama has extensive operation and licensing laws for oil drilling. The State Oil and Gas Boards of Mississippi and Alabama are regulatory agencies of the States of Mississippi and Alabama with the statutory charge of regulating oil exploration and production, including preventing waste and promoting the conservation of oil and gas while ensuring the protection of both the environment and the correlative rights of owners. These boards are granted broad authority in state oil and gas conservation statutes to promulgate and enforce rules and regulations to ensure the conservation and proper development of the state’s’ petroleum resources. Specific regulations may vary from state to state across the Gulf States Drill Region. We will rely on consultants and local legal counsel for compliance with the state regulatory regime.
Failure to comply with these laws and regulations may result in the suspension or termination of our operations and subject us to administrative, civil, and criminal penalties. Moreover, new laws and regulations may be enacted, and current laws and regulations could change, or their interpretations could change, in ways that could substantially increase our costs. The occurrence of any of these factors, or the continuation thereof, could have a material adverse effect on our business, financial position, or future results of operations.
Our operations are subject to operating hazards inherent to our industry that may adversely impact our ability to conduct business, and we may not be fully insured against all such operating risks.
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The operating hazards in exploring for and producing oil and natural gas include: encountering unexpected subsurface conditions that cause damage to equipment or personal injury, including loss of life; equipment failures that curtail or stop production or cause severe damage to or destruction of property, natural resources or other equipment; blowouts or other damages to the productive formations of our reserves that require a well to be re-drilled or other corrective action to be taken; and storms and other extreme weather conditions that cause damages to our production facilities or wells. Because of these or other events, we could experience environmental hazards, including release of oil and natural gas from spills, natural gas leaks, accidental leakage of toxic or hazardous materials, such as petroleum liquids, drilling fluids or fracturing fluids, including chemical additives, underground migration, and ruptures. If we experience any of these problems, we could incur substantial losses in excess of our insurance coverage. The occurrence of a significant event or claim, not fully insured or indemnified against, could have a material adverse effect on our financial condition and operations. In accordance with industry practice, we maintain insurance against some of the operating risks to which our business is exposed. Also, no assurance can be given that we will be able to maintain insurance in the future at rates we consider reasonable to cover our possible losses from operating hazards and we may elect no or minimal insurance coverage. However, we do not have insurance covering environmental and occupational health and safety risks, and even if we had such insurance, it may not cover penalties or fines that may be issued by a governmental authority.
Negative public perception of the oil and gas industry could have a material and adverse effect on us.
Oil and natural gas drilling and development activities are subject to growing negative public perception globally, and particularly, in the United States resulting from, among other things, concerns raised by advocacy groups about climate change may lead to increased reputational and litigation risk and regulatory, legislative and judicial scrutiny, which may, in turn, lead to new state and federal safety and environmental laws, regulations, guidelines and enforcement interpretations. Companies in the oil and natural gas industry are often the target of activist efforts from both individuals and non-governmental organizations regarding safety, human rights, climate change, environmental matters, sustainability, and business practices. The foregoing factors may cause operational delays or restrictions, increased operating costs, additional regulatory burdens and increased risk of litigation. Negative perceptions regarding our industry and reputational risks may also in the future adversely affect our ability to successfully carry out our business strategy by adversely affecting our access to capital. Certain segments of the investor community have developed negative sentiments towards investing in our industry.
Further, certain investment banks and asset managers based both domestically and internationally have announced that they are adopting climate change guidelines for their banking and investing activities. Certain other stakeholders have also pressured commercial and investment banks to stop financing oil and gas production and related infrastructure projects. Institutional lenders who provide financing to companies in the energy sector have also become more attentive to sustainable lending practices, and some may elect not to provide traditional energy producers or companies that support such producers with funding. Such developments aimed at limiting climate change and reducing air pollution, could result in downward pressure on the stock prices of oil and gas companies, including ours. This may also potentially result in a reduction of available capital funding for potential development projects, impacting our future financial results.
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Terrorist attacks aimed at energy operations could adversely affect our future oil exploration and production business.
The continued threat of terrorism and the effect of military and other government action have led and may lead to further increased volatility in prices for oil and natural gas and could affect these commodity markets or the financial markets. The U.S. government has issued warnings that energy assets may be a future target of terrorist organizations. These developments have subjected our oil and natural gas operations to increased risks. Any future terrorist attack on facilities used by Barrister or other future oil exploration and production operations, those of such operations’ customers, the infrastructure used for transportation of oil, and, in some cases, those of other energy companies, could have a material adverse effect on the Company.
Operational Risks
We have a limited history of owning and operating oil and gas exploration and production operations.
Prior to the Barrister Acquisition in November 2020, we had not generated any revenue. Although we acquired Barrister’s business pursuant to the Barrister Acquisition, these production operations are minimal and commenced less than three years ago. In addition, the history of obtaining oil rights by Barrister was minimal in terms of production and does not reveal the potential oil production and profitability of the Company Oil Rights. Subsequently, in the fourth quarter of 2022, we acquired additional oil rights and interests by purchasing NONOP Assets and Buckley Assets. In the third and fourth quarters of 2024, respectively, we acquired the non-operated interests of Liberty Operating Company, LLC in the Liberty and Pine Grove Fields of Mississippi. Now we need to obtain sufficient funds to develop reserves related to these properties. However, the lack of a more extensive operating history may discourage lenders or funding sources from providing working capital to the Company. There is no assurance that the oil rights acquired by the Company to date will produce oil or natural gas on a profitable basis. Investors should carefully consider the lack of operating history of the Company and the lack of any significant oil production from the Company Oil Rights prior to making an investment decision to invest in the Company. If the Company is unable to obtain needed capital or financing on satisfactory terms, its ability to develop future reserves will be adversely affected. If production or drilling operations are curtailed, then the Company may be unable to continue to hold leases and drilling rights that are scheduled to expire, which may further reduce oil reserves, which will materially and adversely affect future business, financial condition, results of operations, liquidity, and ability to finance planned capital expenditures.
We have entered a highly competitive and highly capital-intensive industry, and any oil production may be insufficient to fund, sustain, or expand revenue-generating operations.
The oil drilling exploration and production business are capital intensive due to the cost of experienced personnel; equipment and other assets required to drill, produce and store oil; regulatory compliance costs; potential liability exposures and financial effects; and the risk of unpredictable volatility in oil market prices and predatory pricing by competitors. Drilling requires an upfront payment of operational costs with no guarantee that actual oil production will cover such expenses. “Dry” holes for the first and/or second oil wells could deplete any available funding raised by the Company and render the Company insolvent. The actual amount and timing of our future capital expenditures may differ materially from our estimates as a result of, among other things, market oil prices, actual drilling results, the availability of drilling rigs and other services and equipment, and regulatory, technological, and competitive developments. The Company does not have cash flow or cash reserves sufficient to fund more extensive and deep drilling on Company Oil Rights. While we will seek such funding, there are no assurances that we can obtain funding that will be sufficient to fund deep drill wells or new property acquisitions, which are needed to produce any significant levels of oil production. Future cash flow from our operations and access to capital are subject to a number of variables, including, but not limited to: (i) the market prices at which our oil production is sold; (ii) our proved reserves; (iii) the level of hydrocarbons we can produce from any future oil wells; (iv) our ability to acquire, locate and produce new oil reserves; (v) the levels of our operating expenses; (vi) reduction in the U.S. and global demand for oil.
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Our acquisitions of oil and gas properties and subsequent exploration and development drilling efforts and the operation of our wells may not be profitable or achieve our targeted returns.
Exploration, development, drilling and production activities are subject to many risks. Acquiring oil and natural gas exploration and production rights and leases requires us to assess reservoir and infrastructure characteristics, including recoverable reserves, development and operating costs, and potential environmental and other liabilities. We may invest in property, including undeveloped leasehold acreage, which we believe will result in projects that will add value over time. However, we cannot guarantee that any leasehold acreage acquired will be profitably developed, that new wells drilled will be productive or that we will recover all or any portion of our investment in such leasehold acreage or wells. Drilling for oil and natural gas may involve unprofitable efforts, including wells that are productive but do not produce sufficient net reserves to return a profit after deducting operating and other costs.
In addition, we may not be successful in controlling our drilling and production costs to improve our overall return and wells that are profitable may not achieve our targeted rate of return. Wells may have production decline rates that are greater than anticipated. Future drilling and completion efforts may impact production from existing wells, and parent-child effects may impact future well productivity as a result of timing, spacing proximity or other factors. Acquiring oil and natural gas properties requires us to assess reservoir and infrastructure characteristics, including recoverable reserves, development and operating costs and potential environmental and other liabilities. Such assessments are inexact and inherently uncertain. In connection with the assessments, we perform a review of the subject properties, but such a review will not necessarily reveal all existing or potential problems. In the course of our due diligence, we may not inspect ever well or pipeline. We cannot necessarily observe structural and environmental problems, such as pipe corrosion, when an inspection is made. We may not be able to obtain contractual indemnities from the seller for liabilities created prior to our purchase of the property. We may be required to assume the risk of the physical condition of the properties in addition to the risk that the properties may not perform in accordance with our expectations. These risks could render unprofitable our drilling operations and significantly affect the overall financial performance and condition of the Company. Failure to conduct our oil and gas operations in a profitable manner may result in impairments of our proved reserves quantities, impairment of our oil and gas properties, and a write-down in the carrying value of our unproved properties, and over time may adversely affect our growth, revenues and cash flows.
Due to our contractor model of operations, we will be vulnerable to any inability to engage or retain qualified operational personnel for new or existing drilling operations.
Our operation plan depends on a teaming/contractor approach to operate oil rigs. We may be unable to locate or retain a sufficient number of qualified independent contractors to operate new or existing oil rigs. Finding and engaging qualified independent contractors will be essential to commencing, expanding, and sustaining drilling operations. Since we will, in all likelihood, depend on one or two new oil rigs at the start of operations after raising sufficient working capital, any inability to engage or retain qualified independent contractors would be potentially fatal to our efforts to establish increased revenue-generating operations. The use of independent contractors also poses the risk of such personnel leaving for more lucrative opportunities with competitors or other oil producers. Many of our competitors can afford more lucrative compensation packages for qualified personnel. We lack the resources to effectively compete against larger competitors for operational personnel, especially against competitors with liquid public markets for their capital stock and the ability to offer attractive stock-based incentive compensation.
Loss of key operational personnel could cause the suspension of any expanded drilling operations.
The Company does not have key-man insurance or the available cash to easily employ or engage experienced, full-time outside senior management personnel. The loss of key personnel, including our Chief Executive Officer and operational personnel of COP and our other operators that manage the Company’s oil drilling and production could undermine the Company’s ability to manage operations and implement the Company’s business plan.
With any expanded oil exploration and drilling, we will need to replace existing oil reserves with new oil reserves and develop those oil reserves. If we are unable to do so, oil reserves and production will decline, which would adversely affect future cash flows and results of operations.
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Once we increase oil production, then producing oil reservoirs generally will be characterized by declining production rates that vary depending upon oil reservoir characteristics and other factors. Unless the Company conducts successful ongoing exploration and development activities or continually acquires properties containing proved reserves, proved reserves would decline as those reserves are produced. Future reserves and production, and therefore future cash flow and results of operations, are highly dependent on the success in efficiently developing current reserves and economically finding or acquiring additional recoverable oil reserves. We may not be able to develop, find, or acquire sufficient additional reserves to replace our current and future production. If we are unable to replace current and future oil production, the value of existing reserves will decrease, and business, financial condition, and results of operations would be materially and adversely affected.
The oil and gas development, exploration and production industry is very competitive, and some of our competitors have greater financial and other resources than we do.
We face competition in every aspect of our business, including buying and selling reserves and leases, obtaining goods and services needed to operate our business and marketing natural gas and oil. Competitors include multinational oil companies, independent production companies and individual producers and operators. Many of our competitors have greater financial and other resources than we do and may have greater access to the capital and credit markets. Many of these companies not only explore for and produce oil and natural gas, but also carry on midstream and refining operations and market petroleum and other products on a regional, national or worldwide basis. As a result, these competitors may be able to address the competitive factors of the industry more effectively or weather industry downturns more easily than we can. We also face indirect competition from alternative energy sources, including wind, solar and electric power.
The potential lack of availability of, or cost of, drilling rigs, equipment, supplies, personnel, and crude oil field services could adversely affect our ability to execute on a timely basis exploration and development plans within any budget.
We may encounter an increase in the cost of securing needed drilling rigs, equipment, and supplies. Larger producers may be more likely to secure access to such equipment by offering more lucrative terms. If we are unable to acquire access to such resources or can obtain access only at higher prices, its ability to convert oil reserves into cash flow could be delayed, and the cost of producing from those oil reserves could increase significantly, which would adversely affect results of operations and financial condition. Our current drilling operations are limited, and the availability of essential drilling assets may not become a risk factor until such time as we increase drilling operations.
We have a limited customer base for its oil production due to its limited oil production and operating history. The cost of and difficulty in expanding the customer base for increased production from the Company Oil Rights is unknown.
We can only determine the cost and difficulty of expanding our customer base based on actual oil production and then-current market conditions and demand for oil. As such, we cannot predict the cost and ease or difficulty of selling increased oil production from the Company Oil Rights. This unknown factor in commercially exploiting any increased oil production from the Company Oil Rights increases the risk of investing in the shares of the Company because it renders uncertain a key factor in future profitability of the Company.
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Cyber-attacks targeting systems and infrastructure used by the oil and gas industry and related regulations may adversely impact our operations and, if we are unable to obtain and maintain adequate protection for our data, our business may be adversely affected.
Our business has become increasingly dependent on digital technologies to conduct certain exploration, development and production activities. We depend on digital technology to estimate quantities of oil, natural gas and NGL reserves, process and record financial and operating data, analyze seismic and drilling information, and communicate with our customers, employees and third-party partners. The U.S. government has issued public warnings that indicate that energy assets might be specific targets of cyber security threats. Our technologies, systems, networks, and those of our vendors, suppliers and other business partners, may become the target of cyberattacks or information security breaches that could result in the unauthorized access to our seismic data, reserves information, customer or employee data or other proprietary or commercially sensitive information could lead to data corruption, communication interruption, or other disruptions in our exploration or production operations or planned business transactions, any of which could have a material adverse impact on our results of operations. If our information technology systems cease to function properly or our cybersecurity is breached, we could suffer disruptions to our normal operations, which may include drilling, completion, production and corporate functions. A cyber-attack involving our information systems and related infrastructure, or that of our business associates, could result in supply chain disruptions that delay or prevent the transportation and marketing of our production, non-compliance leading to regulatory fines or penalties, loss or disclosure of, or damage to, our customer’s, supplier’s or royalty owners’ data or confidential information that could harm our business by damaging our reputation, subjecting us to potential financial or legal liability, and requiring us to incur significant costs, including costs to repair or restore our systems and data or to take other remedial steps.
In addition, certain cyber incidents, such as surveillance, may remain undetected for an extended period. Our systems for protecting against cyber security risks may not be sufficient. While we have not been subject to cybersecurity challenges that have materially impaired our operations or financial standing, we recognize the importance of developing, implementing and maintaining cybersecurity measures to better safeguard our information systems and protect the confidentiality, integrity and availability of our data. Our risk management team will work with our IT department to evaluate and address cybersecurity risks in alignment with our business objectives and operational needs. In the future, the Company will require the Board and employees to complete cybersecurity training related to the physical security of assets, data privacy and other information security policies and procedures. However, these actions may require us to expend significant additional resources to continue to modify or enhance our protective measures or to investigate and remediate any vulnerabilities to cyberattacks.
Risk related to the Third-Party Transportation of Oil Production.
The marketability of oil production will depend upon the availability, proximity, and capacity of transportation facilities owned by third parties. Any oil production will be transported from the wellhead to gathering systems. The oil is then transported by the purchaser by truck or other means to a transportation facility. We will not be able to control most of these third-party transportation means and facilities, and access to them may be limited or denied. If in the future, the Company is unable, for any sustained period, to implement acceptable delivery or transportation arrangements or encounter production-related difficulties, it may be required to shut in or curtail production. Any such shut-in or curtailment, or an inability to obtain favorable terms for delivery of the oil produced, would materially and adversely affect our efforts to attain or sustain revenues from operations and improved future financial condition and results of operations.
Risks Related to Our Financial Condition and Capital Requirements
Our independent registered public accounting firm has included an explanatory paragraph relating to our ability to continue as a going concern in its report on our audited financial statements.
On a consolidated basis, the Company has incurred significant operating losses since inception and has a working capital deficit. The Company’s financial statements do not include any adjustments that might result from the outcome of this uncertainty. Because the Company does not expect that existing operational cash flow will be sufficient to fund presently anticipated operations, this raises substantial doubt about the Company’s ability to continue as a going concern. Therefore, the Company will need to raise additional funds and is currently exploring alternative sources of financing. Historically, the Company has raised capital through an officer loan as an interim measure to finance working capital needs and will continue to raise additional capital through the sale of common stock or other securities. The Company will be required to continue to do so until its consolidated operations become profitable. Our past efforts to raise working capital have been unsuccessful.
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Although our initial registration statement on Form S-1 was declared effective by the Commission in August 2019, we were unable to sell any shares and terminated said initial public offering. Our initial public offering commenced after October 9, 2020, following the effectiveness of the Form S-1 registration statement; however, we only raised $53,000 in that initial public offering, which was not sufficient, and closed in on May 31, 2021. The impact of COVID-19 pandemic and volatility of market price for oil in 2020 and 2021 further hampered efforts to raise additional working capital by creating economic uncertainty and heightened risks in lending or investing in oil production. These factors, among others, raise substantial doubt about the Company’s ability to continue as a going concern. If we are unable to obtain sufficient funding, our business, prospects, financial condition, and results of operations will be materially and adversely affected, and we may be unable to continue as a going concern. If we cannot continue as a viable entity, you would lose all or most of your investment in the Company.
We do not have directors’ and officers’ liability insurance due to the high cost.
The lack of directors’ and officers’ liability insurance hinders our ability to attract directors and officers. We intend to seek to purchase directors’ and officers’ liability insurance if we have sufficient cash reserves from the net proceeds of this Offering or future funding efforts. Typically, such insurance costs $100,000 or more per annum, if available. Further, directors’ and officers’ insurance require that the insured company cover the first $300,000 or more of costs prior to insurance coverage occurring. This high deductible can be beyond the financial means of a small company and effectively denies the insured company of the benefits of the insurance. If we do not have sufficient cash to purchase directors’ and officers’ liability insurance, our ability to attract and retain qualified officers and directors will suffer, especially considering the lack of a public market for the common stock and resulting inability to offer incentive compensation to directors and officers. We may be unable to find an insurer willing to provide directors’ and officers’ liability insurance since we are an early-stage development company with limited operating history and no revenue-generating operations.
Risks Relating to Our Common Stock
Our common stock is currently quoted on Pink Marketplace of OTC Markets; however, because our common stock was downgraded to Expert Market, we need to submit a new application for Proprietary Quotations. We do not have an active, liquid trading market for our common stock and may never develop it.
In October 2021, our Common Stock became eligible for quotations on OTC Markets. Between October 2021 and July 2023, our stock was quoted on the OTC Pink marketplace, which publishes brokerage quotations; however, because we were delinquent with our reporting obligations and did not file our 2022 annual report and 2023 quarterly reports timely, our stock was downgraded to Expert Market marketplace until we filed all required reports. While our common stock is currently trading again on the OTC Pink Marketplace, because our stock was downgraded to Expert Market, our stock is not eligible for proprietary broker-dealer quotations, and all quotes of our common stock reflect unsolicited customer orders. These unsolicited-only stocks have a higher risk of wider spread, increased volatility, and price dislocations. To be eligible for public brokerage quotations and to provide continuous market making, a market maker needs to submit a new application under SEC Rule15c2-11 which needs to be approved by FINRA. Even if our stock becomes eligible for proprietary quotations, the trading on the OTC Pink marketplace is often thin and characterized by wide fluctuations in trading prices, due to many factors that may have little to do with our operations or business prospects. The securities market has from time-to-time experienced significant price and volume fluctuations that are not related to the operating performance of particular companies. These market fluctuations may also materially and adversely affect the market price of shares of our common stock.
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In the absence of an active trading market investors may have difficulty buying and selling or obtaining market quotations, market visibility for shares of our common stock may be limited, and a lack of visibility for shares of our common stock may have a depressive effect on the market price for shares of our common stock. The lack of an active market impairs the ability of our stockholders to sell their shares at a price that they consider reasonable and may also reduce the fair market value of the shares. Moreover, OTC Markets is not a securities exchange, and trading of securities is often more sporadic than the trading of securities listed on a quotation system like Nasdaq or any other national stock exchange. Accordingly, stockholders may have difficulty reselling any shares of common stock.
Future capital raises may dilute our existing shareholders’ ownership, the value of their equity securities and/or have other adverse effects on our operations.
If we raise additional capital by issuing equity securities by acquisition or by equity financing, our existing shareholders may experience substantial dilution. If we raise additional funds by issuing debt instruments, these debt instruments could impose significant restrictions on our operations, including liens on our assets. If we raise additional funds through collaborations and licensing arrangements, we may be required to relinquish some rights to our technologies or products, or to grant licenses on terms that are not favorable to us or could diminish the rights of our shareholders. Furthermore, if we offer to sell our shares of common stock in subsequent offerings for a purchase price that is less than the purchase price of shares of common stock we offered to our shareholders in the past, it may impact the value of equity securities of the shareholders that purchased it in the past. In addition, the issuance of such additional shares may impact the ability of any investor to sell their shares once such shares are eligible for sale.
There is no assurance that we will be able to pay dividends to our stockholders, which means that you could receive little or no return on your investment.
Payment of dividends from our earnings and profits may be made at the sole discretion of our board of directors. There is no assurance that we will generate any distributable cash from operations. Our board may elect to retain cash for operating purposes, debt retirement, or some other purpose. Consequently, you may receive little or no return on your investment.
“Penny Stock” rules may make buying or selling our Common Stock difficult. Limitations upon Broker-Dealers Effecting Transactions in “Penny Stocks”
Trading in our Common Stock is subject to material limitations as a consequence of regulations that limit the activities of broker-dealers effecting transactions in “penny stocks.” Pursuant to Rule 3a51-1 under the Exchange Act, our Common Stock is a “penny stock” because it (i) is not listed on any national securities exchange (ii) has a market price of less than $5.00 per share, and (iii) its issuer (the Company) has net tangible assets less than $2,000,000 (if the issuer has been in business for at least three (3) years) or $5,000,000 (if the issuer has been in business for less than three (3) years). Rule 15g-9 promulgated under the Exchange Act imposes limitations upon trading activities on “penny stocks”, which makes selling our Common Stock more difficult compared to selling securities that are not “penny stocks.” Rule 15a-9 restricts the solicitation of sales of “penny stocks” by broker-dealers unless the broker first (i) obtains from the purchaser information concerning his financial situation, investment experience, and investment objectives, (ii) reasonably determines that the purchaser has sufficient knowledge and experience in financial matters that the person is capable of evaluating the risks of investing in “penny stocks”, and (iii) delivers and receives back from the purchaser a manually signed written statement acknowledging the purchaser’s investment experience and financial sophistication.
Rules 15g-2 through 15g-6 promulgated under the Exchange Act require broker-dealers who engage in transactions in “penny stocks” first to provide their customers with a series of disclosures and documents, including (i) a standardized risk disclosure document identifying the risks inherent in investing in “penny stocks”, (ii) all compensation received by the broker-dealer in connection with the transaction, (iii) current quotation prices and other relevant market data, and (iv) monthly account statements reflecting the fair market value of the securities.
There can be no assurance that any broker-dealer which initiates quotations for the Common Stock will continue to do so, and the loss of any such broker-dealer likely would have a material adverse effect on the market price of our Common Stock.
FINRA sales practice requirements may also limit a stockholder’s ability to buy and sell our stock.
In addition to the “penny stock” rules described below, FINRA has adopted rules that require that in recommending an investment to a customer, a broker-dealer must have reasonable grounds for believing that the investment is suitable for that customer. Prior to recommending speculative low-priced securities to their non-institutional customers, broker-dealers must make reasonable efforts to obtain information about the customer’s financial status, tax status, investment objectives, and other information. Under interpretations of these rules, FINRA believes that there is a high probability that speculative low-priced securities will not be suitable for at least some customers. The FINRA requirements make it more difficult for broker-dealers to recommend that their customers buy our Common Stock, which may limit your ability to buy and sell our stock and have an adverse effect on the market for our shares.
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Because our Common Stock is deemed a low-priced “penny stock,” it will be cumbersome for brokers and dealers to trade in our Common Stock, making the market for our Common Stock less liquid and negatively affecting the price of our stock. We will be subject to certain provisions of the Exchange Act, commonly referred to as the “penny stock” rules as defined in Rule 3a51-1. A penny stock is generally defined to be any equity security that has a market price less than $5.00 per share, subject to certain exceptions. Since our stock is deemed to be a penny stock, trading is subject to additional sales practice requirements of broker-dealers. These require a broker-dealer to:
| ● | Deliver to the customer, and obtain a written receipt for, a disclosure document; |
| ● | Disclose certain price information about the stock; |
| ● | Disclose the amount of compensation received by the broker-dealer or any associated person of the broker-dealer; |
| ● | Send monthly statements to customers with market and price information about the penny stock; and |
| ● | In some circumstances, approve the purchaser’s account under certain standards and deliver written statements to the customer with the information specified in the rules. |
Consequently, penny stock rules and FINRA rules may restrict the ability or willingness of broker-dealers to trade and/or maintain a market in our Common Stock. Also, prospective investors may not want to get involved with the additional administrative requirements, which may have a material adverse effect on the trading of our shares.
We are an “emerging growth company” under the JOBS Act of 2012 and a “smaller reporting company” and, as a result of the reduced disclosure and governance requirements applicable to emerging growth companies and smaller reporting companies, our Common Stock may be less attractive to investors.
We are an “emerging growth company”, as defined in the JOBS Act, and we may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not “emerging growth companies” including, but not limited to, not being required to comply with the auditor attestation requirements of section 404 of the Sarbanes-Oxley Act, reduced disclosure obligations regarding executive compensation in our periodic reports and proxy statements, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and shareholder approval of any golden parachute payments not previously approved. We cannot predict if investors will find our Common Stock less attractive because we may rely on these exemptions. If some investors find our Common Stock less attractive as a result, there may be a less active trading market for our Common Stock and our stock price may be more volatile.
In addition, Section 107 of the JOBS Act also provides that an “emerging growth company” can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, an “emerging growth company” can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We are choosing to take advantage of the extended transition period for complying with new or revised accounting standards.
We will remain an “emerging growth company” until the earlier of (i) the last day of the year following the fifth anniversary of the date of the completion of our initial public offering, (ii) the last day of the year in which we have total annual gross revenue of at least $1.235 billion, (iii) the last day of the year in which we are deemed to be a “large accelerated filer” as defined in Rule 12b-2 under the Exchange Act, which would occur if the market value of our Common Stock held by non-affiliates exceeded $700.0 million as of the last business day of the second fiscal quarter of such year, or (iv) the date on which we have issued more than $1.0 billion in non-convertible debt securities during the prior three-year period.
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Even after we no longer qualify as an “emerging growth company,” we may still qualify as a “smaller reporting company,” which would allow us to continue to take advantage of many of the same exemptions from disclosure requirements, including, among other things, not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act, presenting only the two most recent fiscal years of audited financial statements in our Annual Report on Form 10-K and reduced disclosure obligations regarding executive compensation in this Report and our periodic reports and proxy statements.
Our status as an “emerging growth company” under the JOBS Act may make it more difficult to raise capital as and when we need it.
Because of the exemptions from various reporting requirements provided to us as an “emerging growth company” and because we will have an extended transition period for complying with new or revised financial accounting standards, we may be less attractive to investors and it may be difficult for us to raise additional capital as and when we need it. Investors may be unable to compare our business with other companies in our industry if they believe that our financial accounting is not as transparent as other companies in our industry. If we are unable to raise additional capital as and when we need it, our financial condition and results of operations may be materially and adversely affected.
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.
ITEM 1C. CYBERSECURITY
Recognizing the critical importance of robust cybersecurity measures, the Company is committed to developing, implementing and maintaining measures to better safeguard our information systems and protect the confidentiality, integrity and availability of our data. Our management team actively evaluates and addresses cybersecurity risks in alignment with our business objectives and operational needs. To date, our operations or financial standing have not been materially impaired by any cybersecurity challenges. Looking ahead, the Company will mandate comprehensive cybersecurity training for both the Board and employees, covering key areas such as physical security of assets, data privacy and other information security policies and procedures.
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ITEM 2. PROPERTIES
See “Business” for descriptions of our properties. We rent our principal executive offices at 4830 Line Avenue, Suite 152, Shreveport, Louisiana, 71106, under a month-to-month lease and for a monthly rental of $26. This office space is deemed adequate for the current needs of our executive management and corporate headquarters. We have no other offices. We believe that this property is sufficient for our current and proposed business.
ITEM 3. LEGAL PROCEEDINGS
As of the date of this report, the Company is not a party to any pending legal proceedings, nor is any of its property subject to litigation. Furthermore, no director, officer or affiliate and no owner, whether of record or beneficially holding more than 5% of any class of our voting securities, or any other security holder, is involved in any legal action adverse to the Company or that presents a material adverse interest.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
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PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES
Our Common Stock is currently quoted on the Pink marketplace of OTC Markets Group, Inc., an inter-dealer quotation system, under the symbol “CJAX.” However, because our common stock was temporarily downgraded to Expert Market, it is not currently eligible for proprietary broker-dealer quotations, and all quotes of our common stock reflect unsolicited customer orders. We need a market maker to submit a new application under SEC Rule15c2-11 which needs to be approved by FINRA to become eligible again for proprietary quotations. Currently only a very limited trading market for our Common Stock and there is no assurance that a regular trading market will ever develop.
As of March 31, 2025, there were 67 stockholders of record of our Common Stock.
Dividends
We have never declared or paid any cash dividends on our common stock. We currently intend to retain future earnings, if any, for working capital purposes and do not anticipate paying any cash dividends in the foreseeable future.
Recent Issuances of Unregistered Securities
None.
Securities Authorized for Issuance Under Equity Compensation Plan
The Company adopted the 2018 Equity Incentive Plan on December 31, 2018. No awards were granted under the 2018 Equity Incentive Plan as of December 31, 2024.
ITEM 6. [Reserved]
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Forward-Looking Statements
The following discussion and analysis should be read in conjunction with our financial statements and the related notes thereto. The management's discussion and analysis contain forward-looking statements, such as statements of our plans, objectives, expectations, and intentions. Any statements that are not statements of historical fact are forward-looking statements. When used, the words “believe,” “plan,” “intend,” “anticipate,” “target,” “estimate,” “expect,” and the like, and/or future tense or conditional constructions (“will,” “may,” “could,” “should,” etc.), or similar expressions, identify certain of these forward-looking statements. These statements are only predictions and involve known and unknown risks, uncertainties, and other factors that may cause our or our industry’s actual results, levels of activity, or performance to be materially different from any future results, levels of activity, or performance expressed or implied by these forward-looking statements.
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Although we believe that the expectations reflected in the forward-looking statements are reasonable, we cannot guarantee future results, levels of activity, or performance. You should not place undue reliance on these statements, which speak only as of the date of this Annual Report. These cautionary statements should be considered with any written or oral forward-looking statements that we may issue in the future. You should read this Annual Report on Form 10-K with the understanding that our actual future results may be materially different from what we expect. All forward-looking statements speak only as of the date on which they are made. We undertake no obligation to update such statements to reflect events that occur or circumstances that exist after the date on which they are made, except as required by applicable law.
Management’s discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements which have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The following discussion and analysis of financial condition and results of operations of the Company is based upon and should be read in conjunction with the audited consolidated financial statements and related notes elsewhere in this Annual Report on Form 10-K.
Overview
We were incorporated on November 13, 2017, under the laws of the Commonwealth of Virginia, to acquire, fund, and operate oil exploration and production from assets in the Gulf States Drill Region. We are an early-stage corporation seeking to become an independent energy company focused on the acquisition and subsequent exploitation and development of crude oil and natural gas in the Gulf States Drill Region.
Since our inception, we have incurred operating losses. Prior to the Barrister Acquisition, we had not generated positive cash flows from operations, and while after the Barrister Acquisition, we started to generate revenue, there are no assurances that we will be successful in obtaining an adequate level of financing for the development and commercialization of our proposed oil exploration and production business. These factors raise substantial doubt about our ability to continue as a going concern. We expect to incur expenses and operating losses for the foreseeable future as we seek to implement our business plan. Due to its limited revenues, the Acquisitions do not remedy substantial doubts about our ability as a going concern. The Company has been unable to raise additional capital as of the date of this Annual Report, other than personal loans by Jeffrey J. Guzy, our Chief Financial Officer, and $53,000 raised in the initial public offering in 2020.
Reserve engineering is a process of estimating underground accumulations of oil that cannot be measured in an exact way. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data, and price and cost assumptions made by reserve engineers. In addition, the results of drilling, testing, and production activities may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of oil that are ultimately recovered. When we acquire oil exploration and production leases and rights, we will use oil reserve reports as one factor in deciding whether to drill in the property of a specific oil lease or right. Reserve estimates depend on many assumptions that may turn out to be inaccurate. Any material inaccuracies in reserve estimates or underlying assumptions will materially affect the quantities and present value of oil from a drilling site.
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Risks and Uncertainties
Oil and natural gas prices have and may continue to be volatile. Recessionary concerns have placed some downward pressure on commodity prices, causing oil and gas prices to decline in the first quarter of 2023 from their earlier highs in 2022. Although supply has increased throughout the last three years, there is still an element of volatility and uncertainty that we expect to continue at least for the near-term and possibly longer, in part by the impact of the Russian-Ukrainian military conflict on global commodity and financial markets, and the associated effect of trade sanctions on imports of oil and natural gas from Russia. This volatility could negatively impact future prices for oil, natural gas, petroleum products and industrial products.
34
Results of Operations
Year Ended December 31, 2024 Compared to Year Ended December 31, 2023
| For the Year Ended December 31, | ||||||||||||||||
| Change | Change | |||||||||||||||
| 2024 | 2023 | Amount | % | |||||||||||||
| Revenues | $ | 971,686 | $ | 927,983 | $ | 43,703 | 4.7% | |||||||||
| Lease operating expenses | 355,644 | 248,642 | 107,002 | 43.0% | ||||||||||||
| General & administrative expenses | 919,994 | 1,038,473 | (118,479) | (11.4% | ) | |||||||||||
| Depletion and accretion on discounted liabilities | 382,061 | 393,430 | (11,369) | (2.9% | ) | |||||||||||
| Impairment expense | 922,932 | 875,400 | 47,532 | 5.4% | ||||||||||||
| Loss from operations | (1,608,945 | ) | (1,627,962 | ) | 19,017 | (1.2% | ) | |||||||||
| Other expense, net | (901 | ) | (1,940 | ) | 1,039 | (53.6% | ) | |||||||||
| Net loss | $ | (1,609,846 | ) | $ | (1,629,902 | ) | $ | 20,056 | (1.2% | ) | ||||||
Revenues
Revenues were $971,686 for the year ended December 31, 2024, and $927,983 for the year ended December 31, 2023. The Company is an early-stage company and began producing significant revenue in 2023. The increase in revenue of $43,703 is attributable to the acquisition of additional mineral and oil and gas interests during 2024.
General and Administrative Expenses
General and administrative expenses consisted primarily of accounting and audit fees, legal and professional services fees, and payroll-related expenses. General and administrative expenses were $919,994 for the year ended December 31, 2024, compared to $1,038,473 in the same period in 2023, representing a decrease of 11.4% or $118,479. The decrease was primarily driven by a decrease in management fees.
Lease Operating Expenses
Lease operating expenses were $355,644 for the year ended December 31, 2024, compared to $248,642 in the same period in 2023. The increase in lease operating expenses of 43.0% or $107,002 was primarily driven by the 2024 acquisition of additional mineral and oil and gas interests and the operation of those interests.
Loss from Operations
Total operating loss was $1,608,945 for the year ended December 31, 2024, and $1,627,962 for the year ended December 31, 2023. The change in loss was primarily driven by the decrease in general and administrative expenses, offset by the increase in lease operating expenses.
Other Expense, Net
Other expense, net was ($901) for the year ended December 31, 2024, compared to ($1,940) for the same period in 2023. The change in other expense, net, was attributable to an increase in interest income.
35
Net Loss
As a result of the above factors, there was a net loss of $1,609,846 for the year ended December 31, 2024, compared to a net loss of $1,629,902 in the same period of 2023.
Liquidity and Capital Resources
Sources of Liquidity
The Company had cash and cash equivalents of $46,738 at December 31, 2024. The Company has incurred net operating losses and operating cash flow deficits since inception, continuing through the years ended December 31, 2024, and December 31, 2023. Since inception, the primary sources of financing have been a combination of loans or contributions of Jeffrey J. Guzy, an officer and director of the Company, and $53,000 raised in the public offering. This limited funding has been inadequate as of the date of this Annual Report to fund our business strategy. The Company has not attained profitable operations and its ability to pursue any future plan of operation is dependent upon our ability to obtain additional financing.
Funding Requirements
The Company believes that its working capital on hand, as of the date of this report, will not be sufficient to fund its plan of operations over the next 12 months. Until such time, if ever, as the Company can generate substantial revenues, it expects to continue relying on a combination of equity offerings and debt financings to fund ongoing operations. To the extent that the Company raises additional capital through the sale of equity or debt securities, the ownership interest of the Company may be materially diluted, and the terms of such securities could include liquidation or other preferences that adversely affect the rights of the Company’s existing stockholders. There is no assurance that the Company will be able to complete any additional sales of equity securities or that it will be able to arrange for other financing to fund its planned business activities.
Debt or equity financing arrangements may not be available to us or may be available only on unfavorable terms. Based on prior experience in seeking funding for drilling on properties without any significant oil production, funding for drilling is challenging to obtain at all or on affordable terms. Our ability to obtain additional financing may be impaired by many factors outside of our control, including the capital markets (both generally and in the crude oil industry in particular), our lack of operating history, the location of our proposed or future crude oil properties and prices of crude oil on the commodities markets (which will influence the amount of asset-based financing available to us) and other factors. Further, if oil prices on the commodities markets decline, our revenues from any exploitation of the Company Oil Rights will likely decrease, and such decreased revenues may increase our requirements for capital. The Company may continue to incur substantial costs in the future in connection with raising capital to fund our business, including investment banking fees, legal fees, accounting fees, securities law compliance fees, printing and distribution expenses, and other costs. The Company may also be required to recognize non-cash expenses in connection with certain securities we may issue, which may adversely affect our financial condition.
If the Company is unable to raise additional funds through equity or debt financings or other arrangements sufficient to satisfy its long-term capital requirements, together with its revenues from any acquired operations, it may be required to reduce operating costs, which are already minimal and delay, reduce or eliminate its acquisition and development activities. That reduction could jeopardize the Company’s future strategic initiatives and business plans. The Company may be required to sell some or all of its acquired properties (which could be on unfavorable terms), seek joint ventures with one or more strategic partners, strategic acquisitions, and other strategic alternatives, cease our operations, sell or merge our business, or file a petition for bankruptcy (either liquidation or reorganization under the U.S. Bankruptcy Code). Any of these actions could result in investors in the common stock losing their investment or failing to realize any appreciation in the common stock from the purchase price.
36
Working Capital (Deficit)
The following table summarizes our total current assets, total current liabilities, and working capital (deficit) as of December 31, 2024, and December 31, 2023:
| As of | As of | |||||||
| December 31, 2024 | December 31, 2023 | |||||||
| Current assets | $ | 215,030 | $ | 281,214 | ||||
| Current liabilities | 1,326,177 | 1,176,419 | ||||||
| Working capital deficit | $ | (1,111,147 | ) | $ | (895,205 | ) | ||
Cash Flows
Changes in the net cash provided by and (used in) operating, investing, and financing activities for the years ended December 31, 2024, and December 31, 2023, are set forth in the following table:
| Year Ended | Year Ended | |||||||
December 31, 2024 |
December 31, 2023 |
|||||||
| Net cash provided by/(used in) operating activities | $ | (19,187) | $ | 48,046 | ||||
| Net cash provided by investing activities | — | — | ||||||
| Net cash used in financing activities | (9,983) | (9,888 | ) | |||||
| Cash at beginning of period | 75,908 | 37,750 | ||||||
| Net increase (decrease) in cash | $ | (29,170) | $ | 38,158 | ||||
Net cash from operating activities is derived from net loss from operations adjusted for non-cash items, changes in accounts receivables balances, prepaid expenses, accounts payables, and accrued expenses. For the period ended December 31, 2024, net cash used in operating activities was $19,187 compared to net cash provided by operating activities of $48,046 for the period ended December 31, 2023. The net decrease was primarily attributable to a net $317,004 decrease in the non-cash adjustment for common stock issued for services and salaries. This change was offset by the net increase in accounts receivable during the period ended December 31, 2024.
Net cash used in investing activities was $0 for both the periods ended December 31, 2024, and December 31, 2023.
Total net cash used in financing activities was $9,983 for the period ended December 31, 2024. Net cash used in financing activities was $9,888 for the periods ended December 31, 2023. The net decrease was due to the decrease in payments made of the SBA PPP loan.
37
Going Concern
The accompanying consolidated financial statements have been prepared assuming we will continue as a going concern, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business for the twelve-month period following the date of these financial statements. On a consolidated basis, we have incurred significant operating losses since inception. Because we do not expect that existing operational cash flow will be sufficient to fund presently anticipated operations, this raises substantial doubt about our ability to continue as a going concern. Therefore, we will need to raise additional funds and are currently exploring sources of financing. Historically, we have raised capital through private offerings of debt and equity and officer loans to finance working capital needs. There can be no assurances that we will be able to continue to raise additional capital through the sale of common stock or other securities or obtain short-term loans.
Off-Balance Sheet Arrangements
We have no off-balance sheet arrangements.
Critical Accounting Policies and Estimates
Our discussion of financial condition and results of operations is based upon the information reported in our financial statements. The preparation of these statements requires us to make assumptions and estimates that affect the reported amounts of assets, liabilities, revenues, and expenses as well as the disclosure of contingent assets and liabilities at the date of our financial statements. We base our assumptions and estimates on historical experience and other sources that we believe to be reasonable at the time. Actual results may vary from our estimates due to changes in circumstances, weather, politics, global economics, mechanical problems, general business conditions, and other factors. Our significant accounting policies are detailed in Note 1 to our financial statements included in this Annual Report. We have outlined below certain of these policies as being of particular importance to the portrayal of our financial position and results of operations and which require the application of significant judgment by our management.
Revenue Recognition. In January 2018, the Company adopted Financial Accounting Standards Board (“FASB”) Codification Revenues from Contracts with Customers (Topic 606). The timing of recognizing revenue from the sale of produced crude oil and natural gas was not changed as a result of adopting ASC 606. The Company predominantly derives its revenue from the sale of produced crude oil and natural gas. The contractual performance obligation is satisfied when the product is delivered to the purchaser. Revenue is recorded in the month the product is delivered to the purchaser. The Company receives payment within one month after pickup. The transaction price includes variable consideration as product pricing is based on published market prices and reduced for contract-specified differentials. The new guidance regarding ASC 606 does not require that the transaction price be fixed or stated in the contract. Estimating the variable consideration does not require significant judgment. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration the Company expects to receive in exchange for those products. See Note 2 of our financial statements for additional information.
38
Successful Efforts Method of Accounting. We account for oil and natural gas properties in accordance with the successful efforts method. Under this method, all acquisition costs of proved properties are capitalized and amortized on a unit-of-production basis over the remaining life of the proved reserves. All development costs of proved properties are capitalized and amortized on a unit-of-production basis over the remaining life of the proved developed reserves. Costs of retired, sold, or abandoned properties that constitute a part of an amortization base are charged or credited, net of proceeds, to accumulated depreciation, depletion, and amortization unless doing so significantly affects the unit-of-production amortization rate, in which case a gain or loss is recognized in the current period. Gains or losses from the disposal of other properties are recognized in the current period. For assets acquired, we base the capitalized cost on the fair value at the acquisition date. We expense expenditures for maintenance and repairs necessary to maintain properties in operating condition, as well as annual lease rentals, as they are incurred. Estimated dismantlement and abandonment costs are capitalized at their estimated net present value and amortized over the remaining lives of the related assets. Interest is capitalized only during the periods in which these assets are brought to their intended use. We only capitalize the interest on borrowed funds related to our share of costs associated with qualifying capital expenditures.
Impairment of Oil and Natural Gas Properties. We evaluate the impairment of our proved oil and natural gas properties generally on a field-by-field basis or at the lowest level for which cash flows are identifiable, whenever events or changes in circumstance indicate that the carrying value may not be recoverable. We reduce the carrying values of proved properties to fair value when the expected undiscounted future cash flows are less than the net book value. We measure the fair values of proved properties using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount. Significant inputs used to determine the fair values of proved properties include estimates of (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a risk-adjusted discount rate. These inputs require significant judgments and estimates by our management at the time of the valuation. The most significant financial statement effect from a change in our oil and gas reserves or impairment of its proved properties would be the DD&A rate.
An impairment may not be reversed in future periods even though higher oil and natural gas prices may subsequently increase the ceiling.
Our estimates of reserves and future cash flow as of December 31, 2024, and 2023 were prepared using an average price equal to the unweighted arithmetic average of the first day of the month price for each month within the 12-month periods ended December 31, 2024, and 2023, respectively, in accordance with SEC guidelines. As of December 31, 2024, our reserves are based on an SEC average price of $73.68 per Bbl of WTI oil posted and $2.013 per MCF natural gas. As of December 31, 2023, our reserves are based on an SEC average price of $75.81 per Bbl of WTI oil posted and $0 per MCF natural gas. Prices are adjusted by local field and lease level differentials and are held constant for the life of reserves in accordance with SEC guidelines.
39
Income Taxes. Deferred income taxes are provided for the difference between the tax basis of assets and liabilities and the carrying amount in our financial statements. This difference will result in taxable income or deductions in future years when the reported amount of the asset or liability is settled. Since our tax returns are filed after the financial statements are prepared, estimates are required in valuing tax assets and liabilities. We record adjustments to the actual values in the period we file our tax returns.
Recent Issued Accounting Pronouncements
See Note 4 in the notes to our consolidated financial statements for further discussion regarding recently issued accounting standards.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKS
As a smaller reporting company, we are not required to provide the information required by this Item.
40
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
F 41
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders
CoJax Oil and Gas Corporation
Opinion on the Consolidated Financial Statements
We have audited the accompanying consolidated balance sheet of CoJax Oil and Gas Corporation (the Company) as of December 31, 2024, and the related consolidated statements of operations, stockholders’ equity, and cash flows for the year ended December 31, 2024, and the related notes (collectively referred to as the "consolidated financial statements"). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024, and the results of its operations and its cash flows for each the year ended December 31, 2024, in conformity with accounting principles generally accepted in the United States of America.
Going Concern
The accompanying consolidated financial statements have been prepared assuming the Company will continue as a going concern. As discussed in Note 2 to the consolidated financial statements, the Company has yet to achieve profitable operations, has negative cash flows from operating activities, and is dependent upon future issuances of equity or other financings to fund ongoing operations all of which raises substantial doubt about its ability to continue as a going concern. Management’s plans regarding these matters are also described in Note 2. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audit. 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 Company 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 audit 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 consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit, 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 Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audit included performing procedures to assess the risks of material misstatement of the consolidated 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 consolidated financial statements. Our audit also included evaluating the accounting principles used and the significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe our audit provides a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing separate opinions on the critical audit matter or on the accounts or disclosures to which it relates.
Oil and gas properties
As described in Notes 3 and 5 to the consolidated financial statements, the Company accounts for its oil and gas properties using the successful efforts method of accounting which requires management to estimate reserve volumes and future net revenues to assess if there are indications the carrying value of certain properties exceed the fair value and if so, determine the fair value of its oil and gas properties. To estimate the volume of reserves and future net revenues, management makes significant estimates and assumptions, and rely on third party experts. In addition, the estimation of reserves is also impacted by management’s judgments and estimates regarding the financial performance of wells associated with reserves to determine if wells are expected, with reasonable certainty, to be economical under the pricing assumptions required in the impairment evaluation and measurements. We identified the evaluation of oil and gas properties as a critical audit matter.
Our audit procedures related to the estimation of proved reserves included the following, among others.
| ● | We evaluated the level of knowledge, skill and ability of the Company’s reservoir engineering specialists and their relationship to the Company, made inquiries of those reservoir engineers regarding the process followed and judgments made to estimate the Company’s proved reserves, and read the reserve report prepared by the Company’s reservoir engineering specialists. |
| ● | We tested the accuracy of the Company’s impairment evaluation and measurement that included these proved reserve reports. |
| ● | We evaluated sensitive inputs and assumptions used to determine reserve volumes and other cash flow inputs and assumptions derived from the Company’s accounting records. These assumptions included historical pricing differentials, current and future operating costs, estimated future capital costs, and ownership interests. |
/s/ M&K CPAS, PLLC
PCAOB
ID:
We have served as the Company’s auditor since 2024
March 31, 2025
F 42
CoJax Oil and Gas Corporation
Consolidated Balance Sheets
| As of | As of | |||||||
| December 31, 2024 | December 31, 2023 | |||||||
| ASSETS | ||||||||
| Current assets: | ||||||||
| Cash | $ | |
$ | |||||
| Accounts receivable | |
|||||||
| Prepaid expenses | |
|||||||
| Total current assets | ||||||||
| Property and Equipment: | ||||||||
| Oil and gas properties at cost | |
|||||||
| Less: Accumulated depletion | ( |
( |
) | |||||
| Total property and equipment - net | |
|||||||
| Total assets | $ | $ | ||||||
| LIABILITIES and STOCKHOLDERS’ EQUITY | ||||||||
| Current liabilities: | ||||||||
| Accounts payable | $ | |
$ | |||||
| Workover expense payable | |
|||||||
| Accrued salaries and payroll taxes | |
|||||||
| Current portion of notes payable | |
|||||||
| Notes payable – related party | |
|||||||
| Total current liabilities | |
|||||||
| Long-term liabilities: | ||||||||
| Asset retirement obligations | |
|||||||
| Notes payable, net of current portion | |
|||||||
| Total long-term liabilities | ||||||||
| Total liabilities | ||||||||
| Stockholders’ equity: | ||||||||
| Preferred stock, $ par value, current shares authorized, and Series A shares, $ par value issued and outstanding at December 31, 2024 and 2023, respectively. | ||||||||
| Common stock, $ par value, current shares authorized, and shares issued and outstanding at December 31, 2024 and 2023, respectively. | ||||||||
| Subscription payable | ||||||||
| Additional paid-in capital | ||||||||
| Accumulated deficit | ( |
) | ( |
) | ||||
| Total stockholders’ equity | ||||||||
| Total liabilities and stockholders’ equity | $ | $ | ||||||
See accompanying notes to consolidated financial statements.
F 43
CoJax Oil and Gas Corporation
Consolidated Statements of Operations
For the Year Ended |
For the Year Ended |
|||||||
December 31, 2024 |
December 31, 2023 |
|||||||
| Revenues | $ | $ | ||||||
| Operating costs and expenses: | ||||||||
| Lease operating expenses | |
|||||||
| General and administrative expenses | |
|||||||
| Depletion and accretion on discounted liabilities | |
|||||||
| Impairment expense | |
|||||||
| Total operating costs and expenses | |
|||||||
| Loss from operations | ( |
( |
) | |||||
| Other income (expense): | ||||||||
| Other income and expense | ||||||||
| Interest expense | ( |
) | ( |
) | ||||
| Total other income (expense) | ( |
) | ( |
|||||
| Net loss | $ | ( |
) | $ | ( |
) | ||
| Net loss per common share - basic and diluted | $ | ) | $ | ) | ||||
| Weighted average number of common shares outstanding during the period - basic and diluted | ||||||||
See accompanying notes to consolidated financial statements.
F 44
CoJax Oil and Gas Corporation
Consolidated Statements of Stockholders’ Equity
For the years ending December 31, 2024, and December 31, 2023
| Additional | Total | |||||||||||||||||||||||||||||||
| Preferred stock | Common stock | Subscriptions | paid-in | Accumulated | Stockholder’s | |||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | payable | capital | deficit | equity | |||||||||||||||||||||||||
| Balance, December 31, 2022 | $ | $ | $ | $ | $ | ( |
) | $ | ||||||||||||||||||||||||
| Common stock issued for services | — | |||||||||||||||||||||||||||||||
| Preferred shares issued for accrued officer compensation | — | |||||||||||||||||||||||||||||||
| Cash received for stock subscriptions payable | — | |||||||||||||||||||||||||||||||
| Net loss for the year ending December 31, 2023 | — | — | $ | ( |
) | $ | ( |
) | ||||||||||||||||||||||||
| Balance, December 31, 2023 | $ | $ | $ | $ | $ | ( |
) | $ | ||||||||||||||||||||||||
| Common stock issued for services | — | |||||||||||||||||||||||||||||||
| Conversion of preferred stock to common stock | ( |
) | ( |
( |
||||||||||||||||||||||||||||
| Common stock issued for acquisition | — | |||||||||||||||||||||||||||||||
| Net loss for the year ending December 31, 2024 | — | — | ( |
) |
( |
) | ||||||||||||||||||||||||||
| Balance, December 31, 2024 | $ | $ | $ | $ | $ | ( |
) | $ | ||||||||||||||||||||||||
See accompanying notes to consolidated financial statements.
F 45
CoJax Oil and Gas Corporation
Consolidated Statements of Cash Flows
For the Year Ended | For the Year Ended | |||||||
December 31, 2024 | December 31, 2023 | |||||||
| Operating Activities: | ||||||||
| Net loss | $ | ( | ) | $ | ( | ) | ||
| Adjustments to reconcile net loss to net cash provided by (used in) operating activities: | ||||||||
| Impairment loss on oil and gas properties | ||||||||
| Depletion expense | ||||||||
| Accretion of asset retirement obligations | ||||||||
| Common stock issued for services and salaries | ||||||||
| Changes in operating assets and liabilities: | ||||||||
| Accounts receivable | ( | ) | ||||||
| Prepaid expense | ( | ) | ||||||
| Accounts payable and accrued liabilities | ||||||||
| Net cash provided by (used in) operating activities | ( | ) | ||||||
| Investing Activities: | ||||||||
| Net cash provided by investment activities | ||||||||
| Financing Activities: | ||||||||
| Payments of loans payable - related party | ( | |||||||
| Payments of loans payable – SBA PPP Loan | ( | ) | ( | ) | ||||
| Proceeds for stock subscriptions payable | ||||||||
| Net cash used in financing activities | ( | ) | ( | ) | ||||
| Net change in cash | ( | ) | ||||||
| Cash - beginning of period | ||||||||
| Cash - end of period | $ | $ | ||||||
| Supplemental disclosure of non-cash operating activities: | ||||||||
| Cash paid for interest | $ | $ | ||||||
| Cash paid for taxes | $ | $ | ||||||
| Supplemental disclosure of non-cash investing and financing activities: | ||||||||
| Common stock issued for acquisitions | $ | $ | ||||||
| Preferred stock issued for accrued compensation | $ | $ | ||||||
| Common shares issued upon conversion of Series A Preferred shares | $ | $ | ||||||
| ARO assumed from acquisitions | $ | $ | ||||||
| Change in estimate of ARO Asset and related liability | $ | $ | ||||||
See accompanying notes to consolidated financial statements.
F 46
CoJax Oil and Gas Corporation
Notes to Consolidated Financial Statements
NOTE 1 – ORGANIZATION, NATURE OF OPERATIONS AND BASIS OF PRESENTATION
Organization
CoJax Oil & Gas Corporation, a Virginia corporation (“Company”), was incorporated on November 13, 2017. The Company is based in Arlington, Virginia, with a wholly owned subsidiary, Barrister Energy LLC (‘Barrister Energy’), registered in Mississippi and based in Laurel, Mississippi.
Nature of Operations
The Company is a growing U.S. energy company engaged in the acquisition and development of lower-risk onshore oil and gas-producing properties within the Southeastern U.S. The Company’s focused growth strategy relies primarily on leveraging management’s expertise to acquire both operated and non-operated interests in producing properties with the goal of assembling a large oil and gas portfolio. Through this strategy of acquisition of operated and non-operated properties, the Company has the unique ability to benefit from the technical and scientific expertise of world-class exploration and production (“E&P”) companies operating in the area.
Since the company’s inception, it has been engaged in organizational activities and had limited revenue-generating operations prior to the periods covered by this current report. The company has begun to acquire assignments of hydrocarbon revenues and underlying oil and gas exploration and production rights as covered by this current report. The company runs all operations of its current acquisitions through Barrister Energy LLC, the operational subsidiary.
The Company focuses on the acquisition of and exploitation of upstream energy assets, specifically targeting select oil and gas mineral interests. These acquisitions are structured primarily as acquisitions of leases, working interests, real property interests and mineral rights and royalties and are generally not regarded as the acquisition of securities, but rather real property interests. As an owner, the Company has the right to receive a portion of the production from the leased acreage (or of the proceeds of the sale thereof). As an owner, the Company also has an obligation for its share of lease operating costs.
On March 11, 2020, the World Health Organization declared COVID-19 a global pandemic. This contagious disease outbreak and any related adverse public health developments, have adversely affected workforces, economies, and financial markets globally, leading to an economic downturn. The impact on the Company has not been significant, but management continues to monitor the situation.
Basis of Presentation
The accompanying financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“US GAAP”), which contemplate the continuation of the Company as a going concern.
NOTE 2 – GOING CONCERN DISCLOSURE
The Company’s consolidated financial statements are prepared in accordance with U.S. GAAP applicable to a going concern that contemplates the realization of assets and liquidation of liabilities in the normal course of business. There can be no assurance that the Company will be able to achieve its business plan, raise any additional capital, or secure the additional financing necessary to implement its current operating plan. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.
F 47
The Company has yet to achieve profitable operations, expects to incur further losses in the development of its business, has negative cash flows from operating activities, and is dependent upon future issuances of equity or other financings to fund ongoing operations, all of which raises substantial doubt about the Company’s ability to continue as a going concern for a period of twelve months from the issuance of these financial statements. The Company’s ability to continue as a going concern is dependent upon its ability to generate future profitable operations and/or to obtain the necessary financing from stockholders or other sources to meet its obligations and repay its liabilities arising from normal business operations when they come due. Management has no formal plan in place to address this concern but considers that the Company will be able to obtain additional funds by equity financing and/or related party advances, however, there is no assurance of additional funding being available or on acceptable terms, if at all.
NOTE 3 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of consolidation
The accompanying consolidated financial statements include the accounts of the Company and of its wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.
Use of Estimates
The preparation of financial statements in conformity U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosures of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Significant areas of estimate include the impairment of assets and rates for amortization, accrued liabilities, future income tax obligations, and the inputs used in calculating stock-based compensation. Actual results could differ from those estimates and would affect future results of operations and cash flows.
Reclassifications
Certain prior period amounts have been reclassified to conform with the current year presentation. Reclassifications include combining or further disaggregation of certain line items in the consolidated balance sheets, consolidated statements of operations, and consolidated statements of cash flows. Such reclassifications had no significant impact on our reported net loss, current assets, total assets, current liabilities, total liabilities, shareholders’ equity or cash flows.
Cash and Cash Equivalents
The
Company considers all highly liquid temporary cash investments with an original maturity of three months or less to be cash equivalents.
At December 31, 2024, and December 31, 2023, the Company had
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Oil and Gas Producing Activities
The Company uses the successful efforts method of accounting for oil and gas activities. Under this method, the costs of productive exploratory wells, all development wells, related asset retirement obligation assets, and productive leases are capitalized and amortized, principally by field, on a units-of-production basis over the life of the remaining proved reserves. Exploration costs, including personnel costs, geological and geophysical expenses, and delay rentals for oil and gas leases are charged to expense as incurred. Exploratory drilling costs are initially capitalized but charged to expense if and when the well is determined not to have found reserves in commercial quantities.
Estimates of oil and gas reserves, as determined by independent petroleum engineers, are continually subject to revision based on price, production history and other factors. Depletion expense, which is computed based on the units of production method, could be significantly impacted by changes in such estimates. Additionally, US GAAP requires that if the expected future undiscounted cash flows from an asset are less than its carrying cost, that asset must be written down to its fair market value. As the fair market value of an oil and gas property will usually be significantly less than the total undiscounted future net revenues expected from that asset, slight changes in the estimates used to determine future net revenues from an asset could lead to the necessity of recording a significant impairment of that asset.
Unproved oil and gas properties will be assessed annually to determine whether they have been impaired by the drilling of dry holes on or near the related acreage or other circumstances, which may indicate a decline in value. When impairment occurs, a loss will be recognized. When leases for unproved properties expire, the costs thereof, net of any related allowance for impairment, will be removed from the accounts and charged to expense.
The Company will review its proved oil and natural gas properties for impairment whenever events and circumstances indicate that a decline in the recoverability of its carrying value may have occurred. It estimates the undiscounted future net cash flows of its oil and natural gas properties and compares such undiscounted future cash flows to the carrying amount of the oil and natural gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will adjust the carrying amount of the oil and natural gas properties to fair value.
During
the years ended December 31, 2024, and 2023, the Company recorded impairments of $
Long-Lived Assets
The Company accounts for the impairment or disposal of long-lived assets according to the Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification (“ASC”) 360 “Property, Plant and Equipment”. ASC 360 clarifies the accounting for the impairment of long-lived assets and for long-lived assets to be disposed of, including the disposal of business segments and major lines of business. Long-lived assets are reviewed when facts and circumstances indicate that the carrying value of the asset may not be recoverable. When necessary, impaired assets are written down to estimated fair value based on the best information available. Estimated fair value is generally based on either appraised value or measured by discounting estimated future cash flows. Considerable management judgment is necessary to estimate discounted future cash flows. Accordingly, actual results could vary significantly from such estimates. The Company did not recognize any impairment losses on long-lived assets during the years ending December 31, 2024, and 2023.
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Fair Value of Financial Instruments
The Company had no financial instruments for the year ending December 31, 2024, or for the year ending December 31, 2023.
ASC 820 “Fair Value Measurements and Disclosures” defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. ASC 820 also establishes a fair value hierarchy that distinguishes between (1) market participant assumptions developed based on market data obtained from independent sources (observable inputs) and (2) a reporting entity’s own assumptions about market participant assumptions developed based on the best information available in the circumstances (unobservable inputs). The fair value hierarchy consists of three broad levels, which give the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The three levels of the fair value hierarchy are described below:
Level 1 – Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities;
Level 2 – Inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly, including quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; inputs other than quoted prices that are observable for the asset or liability (e.g., interest rates); and inputs that are derived principally from or corroborated by observable market data by correlation or other means; and
Level 3 – Fair value measurements are those derived from valuation techniques that include inputs for the asset or liability that are not based on observable market data (unobservable inputs).
Fair value estimates discussed herein are based upon certain market assumptions and pertinent information available to management as of December 31, 2024, and 2023. The respective carrying values of certain on-balance-sheet financial instruments approximated their fair values due to the short-term nature of these instruments.
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Revenue Recognition
The Company accounts for revenue under ASC 606 “Revenue from Contracts with Customers.” Under ASC 606, oil and natural gas sales revenues are recognized when control of the product is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. All the Company’s oil and natural gas sales are made under contracts with customers. The performance obligations for the Company’s contracts with customers are satisfied at a point in time through the delivery of oil and natural gas to its customers. Accordingly, the Company’s contracts do not give rise to contract assets or liabilities. The Company typically receives payment within 90 days of the month of delivery. The Company’s contracts for oil and natural gas sales are standard industry contracts that include variable consideration based on the monthly index price and adjustments that may include counterparty-specific provisions related to volumes, price differentials, discounts, and other adjustments and deductions.
Revenues consist of the following:
Year ended December 31, 2024 |
Year ended December 31, 2023 |
|||||||
| Crude oil revenues | $ | $ | ||||||
| Gas revenues | ||||||||
| Total revenues | $ | $ | ||||||
Accounts Receivable
Accounts
receivable consists of oil and natural gas receivables. Ongoing evaluations of collectability are performed and an allowance for
potential credit losses is provided against the portion of accounts receivable that is estimated to be uncollectible. The Company
did not recognize any write-offs during the years ended December 31, 2024, and 2023. The allowance for doubtful accounts is $
Stock-Based Compensation
The Company accounts for Stock-Based Compensation under ASC 718 “Compensation – Stock Compensation”, which addresses the accounting for transactions in which an entity exchanges its equity instruments for goods or services, with a primary focus on transactions in which an entity obtains employee services in share-based payment transactions. Generally accepted accounting principles require measurement of the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award. Incremental compensation costs arising from subsequent modifications of awards after the grant date must be recognized.
The Company issues stock to consultants for various services. The costs for these transactions are measured at the fair value of the consideration received or the fair value of the equity instruments issued, whichever is more reliably measurable. The value of the common stock is measured at the earlier of (i) the date at which a firm commitment for performance by the counterparty to earn the equity instruments is reached or (ii) the date at which the counterparty's performance is complete. The Company recognized consulting expense and a corresponding increase to additional paid-in-capital related to stock issued for services.
Income Taxes
Income taxes are accounted for under ASC 740, using the liability method of accounting for income taxes. Under the liability method, future tax liabilities and assets are recognized for the estimated future tax consequences attributable to differences between the amounts reported in the financial statement carrying amounts of assets and liabilities and their respective tax bases. Future tax assets and liabilities are measured using enacted or substantially enacted income tax rates expected to apply when the asset is realized, or the liability settled. The effect of a change in income tax rates on future income tax liabilities and assets is recognized in income in the period that the change occurs. Future income tax assets are recognized to the extent that they are considered more likely than not to be realized.
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ASC 740 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements. This standard requires a company to determine whether it is more likely than not that a tax position will be sustained upon examination based on the technical merits of the position. If the more-likely-than-not threshold is met, a company must measure the tax position to determine the amount to recognize in the financial statements.
Because of the implementation of this standard, the Company performed a review of its material tax positions in accordance with recognition and measurement standards established by ASC 740 and concluded that it had no uncertain tax positions as of December 31, 2024, or as of December 31, 2023.
The Company computes income per share in accordance with ASC 260, "Earnings per Share", which requires the presentation of both basic and diluted earnings per share (“EPS”) on the face of the consolidated statement of operations. Basic EPS is computed by dividing income available to common stockholders by the weighted average number of shares outstanding during the period. Diluted EPS gives effect to all dilutive potential shares of common stock outstanding during the period using the treasury stock method and convertible preferred stock using the if-converted method. In computing diluted EPS, the average stock price for the period is used in determining the number of shares assumed to be purchased from the exercise of stock options or warrants. Diluted EPS excludes all dilutive potential shares if their effect is anti-dilutive. As of December 31, 2024, and 2023, the Company had and potentially dilutive common shares outstanding, respectively.
Asset Retirement Obligations
The Company records the estimated fair value of obligations associated with the retirement of tangible, long-lived assets in the period in which they are incurred. When a liability is initially recorded, the Company capitalizes the cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value, and the capitalized cost is depleted over the useful life of the related asset.
Revisions to estimated asset retirement obligations will result in an adjustment to the related capitalized asset and corresponding liability. Upon settlement of the liability, the Company either settles the obligation for its recorded amount or incurs a gain or loss. The Company’s asset retirement obligation relates to the plugging, dismantling, removal, site reclamation, and similar activities of its oil and gas properties.
Asset retirement obligations are estimated at the present value of expected future net cash flows and are discounted using the Company’s credit adjusted risk-free rate. The Company uses unobservable inputs in the estimation of asset retirement obligations that include, but are not limited to: costs of labor, costs of materials, profits on costs of labor and materials, the effect of inflation on estimated costs, and discount rate. Due to the subjectivity of assumptions and the relative long lives of the Company’s leases, the costs to ultimately retire the Company’s obligations may vary significantly from prior estimates. Assumptions used in determining estimates are reviewed annually.
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Concentration of Credit Risk
Our revenue can be materially affected by current economic conditions and the price of oil and natural gas. However, based on the current demand for crude oil and natural gas and the fact that alternative purchasers are readily available, we believe that the loss of our marketing agents and/or any of the purchasers identified by our marketing agents would not have a long-term material adverse effect on our financial position or results of international operations. The continued economic disruption resulting from Russia’s invasion of Ukraine, a potential global recession, and other varying macroeconomic conditions could materially impact the Company's business in future periods. Any potential disruption will depend on the duration and intensity of these events, which are highly uncertain and cannot be predicted at this time.
Segment Information
The Company operates in one reportable segment engaged in the acquisition, exploration, and production of oil and natural gas properties in the Gulf States Drilling Region.
The Company’s chief operating decision maker (“CODM”) is the President and Chief Executive Officer as he maintains responsibility for assessment of the Company’s performance and decision making regarding resource allocation. Consolidated gross profit (loss) is the performance measure used by the CODM to evaluate the segment’s performance and allocate capital and to monitor budget versus actual results. The information regularly provided to the CODM on the segment’s revenues and significant expenses aligns with the categories presented in the Consolidated Statements of Income. Furthermore, the segment’s assets are reported on the Consolidated Balance Sheets as total assets.
NOTE 4 – RECENT ACCOUNTING PRONOUNCEMENTS
In November 2023, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. The ASU requires enhanced disclosures about significant segment expenses that are regularly provided to the Chief Operating Decision Maker and included in each reported measure of segment profit or loss. Additionally, the ASU expanded interim disclosure segments. The ASU was adopted by the Company during the year ended December 31, 2024 and did not have a material impact on the consolidated financial statements. See Segment Information as disclosed with Note 3 for additional information regarding the updates made.
Management does not believe any other recently issued accounting pronouncements, if adopted, would have a material effect on the Company’s present or future financial statements.
NOTE 5 –ROYALTY INTERESTS IN OIL AND GAS PROPERTIES
On August 29, 2024, the Company issued shares of common stock, $ par value per share, valued at $2.00 per share (the “Pine Grove Shares” to Liberty Operating, LLC, a Mississippi limited liability company (“Liberty”), in consideration for the sale and assignment of various mineral and oil and gas interests in and to certain properties located in Mississippi to Barrister Energy, LLC, a wholly-owned subsidiary of the Company organized under the laws of Mississippi. At the request and the instructions of Liberty, the Company issued the Pine Grove Shares to all members of Liberty on the pro rata basis of their ownership in Liberty. This acquisition was effective as of July 1, 2024.
On May 31, 2024, the Company issued shares of common stock, $ par value per share, valued at $2.00 per share (the “Liberty Shares”), to Liberty in consideration for the sale and assignment of various mineral oil and gas interests in and to certain properties located in Mississippi to Barrister Energy, LLC, a wholly-owned subsidiary of the Company organized under the laws of Mississippi. At the request and the instructions of Liberty, the Company issued the Liberty Shares to all members of Liberty on the pro rata basis of their ownership in Liberty. This acquisition was effective as of May 1, 2024.
The Company did not execute any acquisitions during the year ended December 31, 2023.
In
connection with fair value assessments for oil and gas proved properties, during the year ended December 31, 2024, the Company
recorded impairment of $
F 53
At
December 31, 2024, and December 31, 2023, the Company had leased oil and gas properties assets valued at $
Scheduled leased oil and gas properties assets
As of December 31, 2024 |
As of December 31, 2023 |
|||||||
| Beginning balance | $ | $ | ||||||
| Additions to proved reserves | ||||||||
| Additions to unproved reserves | ||||||||
| Revisions of prior year ARO estimates | ||||||||
| Depletion expense | ( |
) | ( |
) | ||||
| Impairment expense | ( |
) | ( |
) | ||||
| Ending Balance | $ | $ | ||||||
We
recorded depletion expense of ($
NOTE 6 – NOTES PAYABLE
Schedule of notes payable
|
December 31, 2024 |
December 31, 2023 |
|||||||
| On May 7, 2020, the Company applied for a Small Business Association (SBA) loan under the Paycheck Protection Program (PPP). The Company met all the necessary qualifications to apply for a $ |
$ | $ | ||||||
| Notes payable | $ | $ | ||||||
| Less: current portion | ( |
) | ( |
) | ||||
| Notes payable net of current portion | $ | $ | ||||||
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Related Party
The Company was a party to several loans with related parties. The note holder is the CEO and Executive Chairman of the Company. At December 31, 2024, and 2023, notes payable consisted of the following:
|
December 31, 2024 |
December 31, 2023 |
|||||||
| On |
$ | $ | ||||||
| On |
$ | $ | ||||||
| On |
$ | $ | ||||||
| On |
$ | $ | ||||||
| On |
$ | $ | ||||||
| On |
$ | $ | ||||||
| Notes payable – related party | $ | $ | ||||||
On December 19, 2024 all outstanding notes with the Company’s CEO and Executive Chairman were extended to have a maturity date of December 31, 2025.
During
the years ended December 31, 2024, and 2023 the Company recorded interest expense of $
NOTE 7 – RELATED PARTY TRANSACTIONS
For the years ending December 31, 2024, and 2023, in addition to the related party loans payable (NOTE 6), the following related party transactions occurred between the Company’s directors or executive officers or any person nominated or chosen by the Company to become a director or executive officer:
F 55
On
January 25, 2023, the Company issued shares of its Series A convertible preferred stock to Jeffrey J. Guzy, the Company’s
CFO, and shares of Series A convertible stock to Wm. Barrett Wellman, the Company’s former CFO.
On February 14, 2023, the Company entered into a new employment agreement with Mr. Guzy (the “Guzy 2023 Employment Agreement”), pursuant to which Mr. Guzy continued serving the Company as Chief Executive Officer, President and Chairman of the Company. That employment agreement was terminated on January 10, 2024, upon resignation of Mr. Guzy from these positions. On the same date, the Company entered into a new employment agreement with Mr. Guzy in connection with his appointment as Chief Financial officer.
On March 13, 2023, Mr. Wellman’s Employment Agreement was extended to a termination date of August 16, 2024. The Employment Agreement was terminated on January 10, 2024, upon resignation of Mr. Wellman as Chief Financial Officer.
Effective as of January 10, 2024, the board of directors of the Company (the “Board”) increased the size of the Board from two to three directors and appointed William R. Downs to the Board.
On January 10, 2024, Jeffrey J. Guzy resigned from serving as Chief Executive Officer, President and Chairman of the Board. Immediately upon Mr. Guzy’s resignation from these offices, Mr. Downs was appointed as Chief Executive Officer, President and Chairman of the Board. Also on January 10, 2024, Wm. Barrett Wellman resigned as Chief Financial Officer and Secretary of the Company. Effective immediately upon Mr. Wellman’s resignation, the Board appointed Mr. Guzy as the Company’s Chief Financial officer and Secretary.
On January 26, 2024, Mr. Guzy and Mr. Wellman, being the holders of all of the Company’s Series A Stock converted all shares issued and outstanding into common shares at a conversion rate of one to ten. The conversion occurred at the rate specified in the initial issuance agreement and therefore no gain or loss was recognized on the conversion. In connection with the exercise of the conversion option, the Company issued and common shares to Jeffrey J. Guzy and Wm. Barrett Wellman, respectively.
NOTE 8 – STOCKHOLDER’S EQUITY
Authorized Capital
The Company has authorized shares of Common Stock at $ par value and authorized shares of Preferred Stock at a par value of $, and Series A convertible shares at a par value of $. The Company had and shares of Common Stock issued and outstanding as of December 31, 2024, and 2023, respectively. The Company had and shares of Preferred Stock issued and outstanding as of December 31, 2024, and 2023, respectively.
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Preferred Stock
The holders of Preferred Stock are entitled to receive dividends equal to the amount of the dividend or distribution per share of common stock payable multiplied by the number of shares of common stock the shares of Series A preferred shares held by such holder are convertible into. Each Series A preferred shares is convertible into ten common shares.
The Company classified the Series A Preferred Stock as permanent equity in the consolidated financial statements as the terms do not provide for an obligation to buy back the shares in exchange for cash or other assets of the Company. The shares are not considered debt under ASC 480 “Distinguishing Liabilities from Equity” as the shares do not represent an obligation that must or may be settled with a variable number of shares. No other redemption features exist within the terms of the instrument.
Refer to Note 7 for details on convertible preferred stock activity during the years ending December 31, 2024, and 2023.
Common Stock
During the year ended December 31, 2023, the Company issued shares, shares, shares, shares, and shares for vendor payments at share prices of $ per share, $ per share, $ per share, $ per share, and $ per share, respectively.
Additionally, during the year ended December 31, 2023, the Company received $ for stock subscriptions payable of shares of common stock.
Refer to Note 7 for details on common share issuances to the Company’s officers.
Refer to Note 5 for details on common share issuances for acquired interests in oil and gas properties.
During the year ended December 31, 2024, there has been no additional common share activity outside of the items disclosed in Notes 5 and 7.
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The above shares of capital stock are restricted securities under Rule 144 and were issued in reliance on an exemption from the registration requirements of the Securities Act.
NOTE 9 - INCOME TAXES
The Company provides for income taxes using the liability method in accordance with ASC 740 “Income Taxes”. Deferred income taxes arise from the differences in the recognition of income and expenses for tax purposes. There were no deferred tax assets or liabilities at December 31, 2024, and 2023.
Management has reviewed the provisions regarding the assessment of their valuation allowance on deferred tax assets and based on those criteria determined that it would not have sufficient taxable income to realize those assets. Therefore, management has assessed the realization of the deferred tax assets and has determined that it is more likely than not that they will not be realized and has provided a full valuation allowance against the deferred tax asset.
The Company recognizes the financial statement effect of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. For tax positions meeting the more-likely-than-not threshold, the amount recognized in the consolidated financial statements is the largest benefit that has a greater than 50 percent likelihood of being realized upon ultimate settlement with the relevant tax authority.
The Company is subject to income taxes in the U.S. federal jurisdiction and the state of Virginia. The tax regulations within each jurisdiction are subject to the interpretation of related tax laws and regulations and require significant judgment to apply. The Company is not presently undergoing any tax audits.
The Company will apply the federal and state net operating loss (“NOL”) carry-forward in FY 2024 and later years.
On
December 22, 2017, the United States Government passed new tax legislation that, among other provisions, will lower the corporate
tax rate from
A reconciliation of the income tax provision computed at statutory rates to the reported tax provision is as follows:
Year ended December 31, 2024 |
Year ended December 31, 2023 |
|||||||
| Federal income tax rate | % | % | ||||||
| Loss before income taxes | $ | ( |
$ | ( |
) | |||
| Non-deductible expenses | ||||||||
| Taxable loss | $ | ( |
$ | ( |
) | |||
| Expected approximate tax recovery on net loss | $ | ( |
$ | ( |
) | |||
| Changes in valuation allowance | ||||||||
| Income tax | $ | $ | ||||||
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The component of the Company’s deferred tax asset is as follows:
As of December 31, 2024 | As of December 31, 2023 | |||||||
| Deferred income tax assets: | ||||||||
| Net operating losses carried forward | $ | $ | ||||||
| Impairments | ||||||||
| Other | ||||||||
| Total gross deferred income tax assets | $ | $ | ||||||
| Less: valuation allowance | (2,329,999) | ( | ) | |||||
| Net deferred tax asset | $ | $ | ||||||
The Company has a valuation allowance against the full amount of its net deferred tax assets due to the uncertainty of the realization of the deferred tax assets.
At December 31, 2024, and December 31, 2023, the Company has incurred accumulated net operating losses in the United States of America totaling $ and $ respectively which are available to reduce taxable income in future taxation years.
NOTE 10 - COMMITMENTS AND CONTINGENCIES
Operating Lease Commitments
The
Company has
Purchase Commitments
The Company has no purchase obligations at December 31, 2024, and 2023.
Significant Risks and Uncertainties
Concentration
of Credit Risk – Cash – The Company maintains cash and cash equivalent balances at a single financial institution
that are insured by the Federal Deposit Insurance Corporation (FDIC) up to $
F 59
Concentration of Credit Risk – Accounts Receivable and Revenues – For the periods presented, all of the Company’s outstanding accounts receivable and revenues were transacted with one party, Taxodium Energy, LLC.
Legal Matters
During the course of business, litigation commonly occurs. From time to time, the Company may be a party to litigation matters involving claims against the Company. The Company operates in a highly regulated industry and employs personnel, which may inherently lend itself to legal matters. Management is aware that litigation has associated costs and that results of adverse litigation verdicts could have a material effect on the Company's financial position or results of operations.
There are no known legal proceedings against the Company or its officers and directors in their capacity as officers and directors of the Company.
NOTE 11 – ASSET RETIREMENT OBLIGATION
Changes in the asset retirement obligation were as follows:
As of December 31, 2024 |
As of December 31, 2023 |
|||||||
| Beginning balance | $ | $ | ||||||
| Liabilities acquired | ||||||||
| Accretion expense | ||||||||
| Revisions | ||||||||
| Ending Balance | $ | $ | ||||||
NOTE 12 – RESERVE AND RELATED FINANCIAL DATA - UNAUDITED
Disclosure of Reserves
The table below summarizes our estimated net proved reserves, as of December 31, 2024, and 2023, based on reserve reports prepared by Netherland, Sewell & Associates, Inc. (NSAI), our third-party independent reserve engineers. In preparing its reports, NSAI evaluated properties representing all of our proved reserves at December 31, 2024, and 2023 in accordance with the rules and regulations of the SEC applicable to companies involved in oil and natural gas producing activities. Our estimated net proved reserves in the table below do not include probable or possible reserves and do not in any way include or reflect our commodity derivatives.
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Schedule of proved developed and undeveloped oil and gas reserve quantities
| Natural Gas (Mmcf) | Oil (Mbbl) | BOE | ||||||||||
| Proved Developed and Undeveloped Reserves at December 31, 2022 | ||||||||||||
| Revisions of Previous Estimates | ( | ) | ( | ) | ( | ) | ||||||
| Purchases of Minerals in Place | ||||||||||||
| Production | ( | ) | ( | ) | ( | ) | ||||||
| Proved Developed and Undeveloped Reserves at December 31, 2023 | ||||||||||||
| Revisions of Previous Estimates | ( | ) | ( | ) | ( | ) | ||||||
| Purchases of Minerals in Place | ||||||||||||
| Production | ( | ) | ( | ) | ||||||||
| Proved Developed and Undeveloped Reserves at December 31, 2024 | ||||||||||||
The
table above values oil and natural gas reserve quantities as of December 31, 2024, and 2023, assuming constant realized prices
of $
Standardized Measure
The standardized measure of discounted future net cash flows and changes in such cash flows are prepared using assumptions required by the Financial Accounting Standards Board. Such assumptions include using 12-month average prices for oil and gas, based on the first-day-of-the-month price for each month in the period, and year-end costs for estimated future development and production expenditures to produce year-end estimated proved reserves.
Discounted future net cash flows are calculated using a 10% rate. Estimated future income taxes are calculated by applying year-end statutory rates to future pre-tax net cash flows, less the tax basis of related assets and applicable tax credits.
The estimated well abandonment costs are deducted from the standardized measure using year-end costs and discounted at 10%. Such abandonment costs are recorded as a liability on the consolidated balance sheet, using estimated values as the projected abandonment date and discounted using a risk-adjusted rate when the well is drilled or acquired.
The standardized measure does not represent management’s estimate of the Company’s future cash flows or the value of proved oil and gas reserves. Probable and possible reserves, which may become proved in the future, are excluded from the calculations. Furthermore, prices used to determine the standardized measure are influenced by supply and demand as affected by recent economic conditions and other factors and may not be the most representative in estimating future revenues or reserve data.
The table below reflects the standardized measure of discounted future net cash flows related to the Company’s interest in proved reserves.
F 61
| Year Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| (in thousands) | ||||||||
| Future cash inflows | $ | $ | ||||||
| Future production costs | ||||||||
| Future development and abandonment costs | ||||||||
| Future tax expense | ||||||||
| Future net cash flows | ||||||||
| 10% annual discount for estimated timing of cash flows | ||||||||
| Standardized measure of discounted future net cash flows | $ | $ | ||||||
The principal changes in the standardized measure of discounted future net cash flows attributable to the Company's proved reserves are as follows:
| Year Ended December 31, | ||||||||
| 2024 | 2023 | |||||||
| (in thousands) | ||||||||
| Beginning of period | $ | $ | ||||||
| Sales of oil and natural gas produced, net of production costs | ( |
) | ( |
) | ||||
| Net change due to extensions, discoveries, and improved recovery | ||||||||
| Net change of prices and production costs | ( |
) | ( |
) | ||||
| Change in future development costs | ( |
) | ||||||
| Revisions of quantity and timing estimates | ( |
) | ( |
) | ||||
| Accretion of discount | ||||||||
| Change in income taxes | ( |
) | ||||||
| Purchases of minerals in place | ||||||||
| Other | ( |
) | ||||||
| End of period | $ | $ | ||||||
NOTE 13 - SUBSEQUENT EVENTS
The Company has evaluated all events that occurred after the balance sheet date through the date when the financial statements were issued to determine if they must be reported. Management determined that there were no reportable subsequent events to be disclosed beyond the following:
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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
ITEM 9A. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
We maintain disclosure controls and procedures (as that term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to ensure that information required to be disclosed in our reports under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosures. In designing disclosure controls and procedures, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible disclosure controls and procedures. The design of any disclosure controls and procedures also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Any controls and procedures, no matter how well designed and operated, can provide only reasonable, not absolute, assurance of achieving the desired control objectives.
Our management, with the participation of our principal executive officer and principal financial officer, has evaluated the effectiveness of the design and operation of our disclosure controls and procedures as of the end of the period covered by this report. Based upon that evaluation and subject to the foregoing, our principal executive officer and principal financial officer concluded that, our disclosure controls and procedures were not effective as of December 31, 2024, due to the material weaknesses in internal control over financial reporting described below.
Management’s Report on Internal Control Over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting. The Company’s internal control over financial reporting is a process designed under the supervision of its principal executive and principal financial officer to provide reasonable assurance regarding the reliability of financial reporting and the preparation of its consolidated financial statements for external reporting purposes in accordance with GAAP.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. In addition, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with the policies or procedures may deteriorate.
Material Weaknesses in Internal Control over Financial Reporting
Management assessed the effectiveness of the Company’s internal control over financial reporting as of December 31, 2024, based on the framework established in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this assessment, management has determined that the Company’s internal control over financial reporting as of December 31, 2024, was not effective.
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A material weakness, as defined in the standards established by the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), is a deficiency, or a combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of our annual or interim consolidated financial statements will not be prevented or detected on a timely basis.
The ineffectiveness of the Company’s internal control over financial reporting was due to the following material weaknesses:
| ● | Inadequate segregation of duties consistent with control objectives; |
| ● | Lack of formal policies and procedures; |
| ● | Lack of a functioning audit committee and independent directors on the Company’s board of directors to oversee financial reporting responsibilities; and |
| ● | Lack of risk assessment procedures on internal controls to detect financial reporting risks on a timely manner. |
Management’s Plan to Remediate the Material Weakness
Management has been implementing and continues to implement measures designed to ensure that control deficiencies contributing to the material weakness are remediated, such that these controls are designed, implemented, and operating effectively. The remediation actions planned include:
| ● | Continue to search for and evaluate qualified independent outside directors; |
| ● | Identify gaps in our skills base and the expertise of our staff required to meet the financial reporting requirements of a public company; and |
| ● | Continue to develop policies and procedures on internal control over financial reporting and monitor the effectiveness of operations on existing controls and procedures. |
We are committed to maintaining a strong internal control environment and believe that these remediation efforts will deliver improvements in our control environment. Our management will continue to monitor and evaluate the relevance of our risk-based approach and the effectiveness of our internal controls and procedures over financial reporting on an ongoing basis and is committed to taking further action and implementing additional enhancements or improvements, as necessary and as funds allow.
This Annual Report does not include an attestation report of the Company’s independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Company’s independent registered public accounting firm pursuant to temporary rules of the Securities and Exchange Commission that permit the Company to provide only management’s report in this Annual Report, which may increase the risk that weaknesses or deficiencies in our internal control over financial reporting go undetected.
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Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during our fourth fiscal quarter that have materially affected, or that are reasonably likely to materially affect, our internal control over financial reporting.
ITEM 9B. OTHER INFORMATION
During
the three months ended December 31, 2024,
ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
None.
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PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, AND CORPORATE GOVERNANCE
Executive Officers and Directors
The following table sets forth information regarding our current directors and executive officers:
| Name | Age | Position | ||
| William R. Downs | 65 | Chief Executive Officer, President, Chairman, Director | ||
| Jeffrey J. Guzy | 73 | Chief Financial Officer, Secretary, Director | ||
| William Allan Bradley | 57 | Director |
Our directors hold office until the next annual meeting of stockholders of the Company and until their successors have been elected and qualified. Our officers are elected by the Board and serve at the discretion of the Board.
Biographies
William R. Downs, age 65, has more than 43 years of experience in the Oil and Gas Industry, specifically in generating, evaluating and managing oil and gas exploration, development and acquisition projects of private, independent and public companies in the area of North and South Louisiana, East Texas, South Arkansas, Mississippi, Oklahoma, Alabama and Montana. He also owned and managed several oilfield service companies.
Prior to joining CoJax, between February 2022 and October 2023, Mr. Downs served as Executive Vice President and Chief Operating Officer of Topcat Companies, an oilfield service company, where he was responsible for the management of the workover rigs, saltwater transportation and disposal, drilling fluids disposal, financial and safety oversight, oversight of individual vice presidents and their team management. Between August 2020 and October 2023, Mr. Downs served as Executive Vice President and Chief Operating Officer of Topcat Waste Management Facility and was responsible for managing of the drilling fluids and solids waste disposal site in Waskom, Texas, saltwater disposal and transportation and workover rigs.
In August 2017, Mr. Downs founded Downs Energy Acquisitions and Downs Operating Company, an oil and gas production acquisition and operating company, which he managed and owned between August 2017 and December 2020. This company operated three gas field in East Texas and North Louisiana, and Mr. Downs managed the operational, financial and personnel activities of the Company. In December 2020, Mr. Downs divested his ownership in this company.
Mr. Downs is a Certified Petroleum Geologist, a member of American Association of Petroleum Geologists, a former Convention Chairman and President of the GCAGS and a member of Division of Professional Affairs. Mr. Downs earned his Bachelor of Science in Geology in 1981 from Centenary College of Louisiana.
Jeffrey J. Guzy, age 73, served as our Chief Executive Officer from January 22, 2020 to January 10, 2024, and as a director since November 17, 2017. He served as our Chief Financial Officer from November 17, 2017, through March 16, 2020, and effective, January 10, 2024, is currently serving as the Chief Financial Officer.
Mr. Guzy has served as an outside director of Leatt Corp. (OTC Trading Symbol: LEAT), since April 2007. Mr. Guzy also served, from October 2007 to August 2010, as Leatt Corp’s President. Mr. Guzy has served as an executive manager or consultant for business development, sales, customer service, and management in the telecommunications industry, specifically, with IBM Corp., Sprint International, Bell Atlantic Video Services, Loral CyberStar, and FaciliCom International. Mr. Guzy has also started his own telecommunications company providing Internet services in Western Africa. He serves as an independent director and chairman of the audit committee of Capstone Companies, Inc. (OTC Trading Symbol: CAPC), Since 2020, he has also served as an independent director of Brownies Marine Group, Inc. (OTC Trading Symbol: BWMG). Mr. Guzy has an MBA in Strategic Planning and Management from The Wharton School of the University of Pennsylvania, an M.S. in Systems Engineering from the University of Pennsylvania; a B.S. in Electrical Engineering from Penn State University; and a Certificate in Theology from Georgetown University. Mr. Guzy’s management and extensive experience led to the conclusion that he should serve as a director.
William Bradley, age 57, has served as our director since March 7, 2022. Mr. Bradley has over fifteen years of leadership, business consulting, financial, and management experience for publicly traded and private companies. Since June 2011, Mr. Bradley served as M&A/Business Consulting Managing Director and Chief Financial Officer at Global Advisors Inc. where he provided business consulting services, reviewed client’s financial positions and managed relationships, conducted financial reviews, including the PCAOB or IFRS audit process, and provided his consulting business advice on restructuring and potential mergers and acquisitions. Since September 2018 he has served as the Chairman of the Board of Magagram Social Media Inc., a Toronto-based private company, from December 2006 to June 2011 as Chief Executive Officer of Ocean to Ocean Inc., and from January 2002 until November 2006, as Vice President of Gourmet Foods International. Mr. Bradley graduated from York University in 1998 in Finance and Economics and received his undergraduate degree with honors in 1991 in Business Finance from Sandford College.
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Board Committees
We currently do not have any committees of our Board of Directors.
Family Relationships
There are no family relationships among any of our officers or directors.
Code of Ethics and Insider Trading Policy
We have adopted a Code of Business Conduct and Ethics (the “Code of Ethics”) that applies to our principal executive, financial and accounting officers (or persons performing similar functions).
On March 6, 2025, our Board of Directors adopted a stand-alone insider trading policy (the “Insider Trading Policy”) to update and expand the scope of the insider trading policy included in the Code of Ethics. The Insider Trading Policy is applicable to all officers, directors, employees and other covered persons and governs the purchase, sale and other disposition of our securities that we believe are reasonably designed to promote compliance with insider trading laws, rules and regulations and any applicable OTC Markets Group standards. A copy of our Insider Trading Policy is filed as Exhibit 19.1 to this Annual Report on Form 10-K.
Involvement in Certain Legal Proceedings
To our knowledge, our directors and executive officers have not been involved in any of the following events during the past ten years:
| 1. | any bankruptcy petition filed by or against such person or any business of which such person was a general partner or executive officer either at the time of the bankruptcy or within two years prior to that time; |
| 2. | any conviction in a criminal proceeding or being subject to a pending criminal proceeding (excluding traffic violations and other minor offenses); |
| 3. | being subject to any order, judgment, or decree, not subsequently reversed, suspended or vacated, of any court of competent jurisdiction, permanently or temporarily enjoining him from or otherwise limiting his involvement in any type of business, securities or banking activities or to be associated with any person practicing in banking or securities activities; |
| 4. | being found by a court of competent jurisdiction in a civil action, the SEC or the Commodity Futures Trading Commission to have violated a Federal or State securities or commodities law, and the judgment has not been reversed, suspended, or vacated; |
| 5. | being subject of, or a party to, any Federal or State judicial or administrative order, judgment decree, or finding, not subsequently reversed, suspended, or vacated, relating to an alleged violation of any Federal or state securities or commodities law or regulation, any law or regulation respecting financial institutions or insurance companies, or any law or regulation prohibiting mail or wire fraud or fraud in connection with any business entity; or |
| 6. | being subject of or party to any sanction or order, not subsequently reversed, suspended, or vacated, of any self-regulatory organization, any registered entity, or any equivalent exchange, association, entity or organization that has disciplinary authority over its members or persons associated with a member. |
Delinquent Section 16(a) Reports
The Company is not aware of any reporting person that failed to file on a timely basis reports required by Section 16(a) of the Exchange Act during the most recent fiscal year.
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Compensation of Directors
2024 Director Compensation Table
| Name | Fees Earned or Paid in Cash | Stock Awards | Option Awards | Non-Equity Incentive Plan Compensation | Nonqualified Deferred Compensation Earnings | All Other Compensation | Total | ||||||||||||||
| William R. Downs | 2024 | — | — | — | — | — | — | ||||||||||||||
| 2023 | — | — | — | — | — | — | |||||||||||||||
| Jeffrey J. Guzy | 2024 | — | — | — | — | — | — | ||||||||||||||
| 2023 | — | — | — | — | — | — | |||||||||||||||
| William A. Bradley | 2024 | — | — | — | — | — | — | ||||||||||||||
| 2023 | — | — | — | — | — | — |
For the years ended December 31, 2024, and 2023, no compensation has been paid to our directors in consideration for their services rendered in their capacities as directors.
Outstanding Equity Awards at Fiscal Year-End
There are no current outstanding equity awards to our executive officers as of December 31, 2024.
Long-Term Incentive Plans
There are no arrangements or plans in which we provide pension, retirement, or similar benefits for directors or executive officers.
ITEM 11. EXECUTIVE COMPENSATION
The following table sets forth information concerning all cash and non-cash compensation awarded to, earned by or paid to our Chief Executive Officer and the other executive officer with compensation exceeding $100,000 during 2024 and 2023 (each a “Named Executive Officer”).
SUMMARY COMPENSATION TABLE
| Name and Principal Position | Year | Salary ($) |
Bonus ($) |
Option Awards ($)(2) |
All Other Compensation ($) |
Total ($) |
||||||||||||||||||
| William R. Downs | 2024 | $ | 150,000 | $ | — | $ | — | $ | — | $ | 21,250 | |||||||||||||
| 2023 | $ | — | $ | — | $ | — | $ | — | $ | — | ||||||||||||||
| Jeffrey J. Guzy(1) | 2024 | $ | 100,000 | $ | — | $ | — | $ | — | $ | 21,250 | |||||||||||||
| 2023 | $ | 120,000 | $ | — | $ | — | $ | — | $ | — | ||||||||||||||
| Wm. Barrett Wellman (2) | 2024 | $ | 100,000 | $ | — | $ | — | $ | — | $ | — | |||||||||||||
| 2023 | $ | 100,000 | $ | — | $ | — | $ | — | $ | — | ||||||||||||||
(1) Mr. Guzy was appointed as Chief Executive Officer on January 22, 2020 and served in this capacity until January 10, 2024. Jeffrey Guzy’s base annual salary of $120,000 is payable on a semi-monthly basis in equal installments, but the base salary is deferred until the Company has sufficient cash flow to pay the base salary. Further, the base salary can either be paid in total when Company is adequately funded, or the accrued unpaid base salary can be converted into shares of the CoJax Common Stock at the lower conversion price of the initial public offering price of $2.00 or current market price at the time of conversion by Mr. Guzy.
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(2) Mr. Wellman was appointed Chief Financial Officer on March 16, 2020. He resigned from this position on January 10, 2024. Mr. Wellman’s base salary of $100,000 is payable semi-monthly in equal installments, but the base salary is deferred until the Company has sufficient cash flow to pay the base salary. Alternatively, the accrued unpaid base salary can be converted into shares of the CoJax Common Stock at the lower conversion price of the initial public offering price of $2.00 or current market price at the time of conversion by Mr. Wellman.
Employment Agreements with Key Executives
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On February 20, 2020, the Company entered into an initial employment agreement with Jeffrey Guzy. The term of that agreement was 3 years. This initial employment agreement was terminated on February 14, 2023, on the date the Company entered into a second employment agreement with Mr. Guzy (the “Guzy 2023 Employment Agreement”), pursuant to which Mr. Guzy continued serving the Company as Chief Executive Officer, President and Chairman of the Company. The Guzy 2023 Employment Agreement has a 3-year term through February 14, 2026, unless terminated earlier pursuant to the terms of the Guzy 2023 Employment Agreement. Pursuant to the Guzy 2023 Employment Agreement, Mr. Guzy will be paid a base salary of $120,000 per annum, which salary will accrue and can either be paid in total when the Company is adequately funded or, alternatively, the accrued unpaid base salary can be converted into shares of the Company’s common stock at the lower conversion price of the initial public offering price of $2.00 or current market price at the time of conversion by Mr. Guzy. Pursuant to the Guzy 2023 Employment Agreement, Mr. Guzy may participate in any incentive compensation and other benefit plans may be granted bonus performance bonus payments to be paid in cash, stock, or both. In addition, the Guzy 2023 Employment Agreement includes provisions for paid vacation time and expense reimbursement.
The Guzy 2023 Employment Agreement provided for termination (i) immediately upon Mr. Guzy’s death or Disability; (ii) by the Company for Cause; (iii) by Mr. Guzy for Good Reason (as these terms are defined in the Guzy 2023 Employment Agreement or (iv) other than for Cause or Good Reason, by Mr. Guzy or the Company upon not less than sixty (60) days prior written notice of termination. If Mr. Guzy terminates the employment for a Good Reason, then he would be entitled to: a cash payment, payable in equal installments over a six (6) month period after Mr. Guzy terminates employment, equal to the sum of the following: (a) subject to the payment of the following sums not causing the insolvency of the Company, the equivalent of the greater of (i) twenty-four (24) months of Mr. Guzy’s then-current base salary or (ii) the remainder of the term of the Guzy 2023 Employment Agreement; plus (b) any previously earned but unpaid salary through Mr. Guzy’s final date of employment, being Mr. Guzy’s termination of employment. On January 10, 2024, the Guzy 2023 Employment Agreement was terminated in connection with Mr. Guzy’s resignation from serving as Chief Executive Officer, President and Chairman. On the same date, in connection with the appointment of Mr. Guzy to serve as Chief Financial Officer, the Company entered into a new employment agreement with Mr. Guzy for his services as Chief Financial Officer.
The Company entered into an employment agreement with Wm. Barrett Wellman on March 16, 2020, for his service as Chief Financial Officer. That agreement had an initial 3-year term and was extended until August 16, 2024. This employment agreement provided for the following:
| (1) | a base annual salary of $100,000 to be paid semi-monthly in equal installments, but the base salary can either be paid in total when CoJax is adequately funded or, alternatively, the accrued unpaid base salary can be converted into shares of the CoJax common stock at the lower conversion price of the initial public offering price of $2.00 or current market price at the time of conversion by Mr. Wellman; |
| (2) | Mr. Wellman is eligible for an ad hoc performance bonus if and in an amount approved by the disinterested directors; |
| (3) | Mr. Wellman may participate in any incentive compensation and other benefit plans to the extent that he is eligible to do so; |
| (4) | continuation of Mr. Wellman’s benefits under CoJax’s health insurance and other benefit plans for 24 months after any termination of his employment for good reason (as defined in the employment agreement); |
| (5) | imposes confidentiality and non-recruitment of Company employees’ obligations on Mr. Wellman for one year after end of employment, and |
| (6) | the employment agreement provides for CoJax to terminate Mr. Wellman’s employment for cause (as defined in the employment agreement) and for Mr. Wellman to terminate the employment agreement for ”good reason” (as defined in the employment agreement). |
Mr. Wellman’s unpaid base salary is deferred if unpaid at the time due.
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If Mr. Wellman terminates the employment for a good reason, then he would be entitled to: A cash payment, payable in equal installments over a six (6) month period after Mr. Wellman terminates employment, equal to the sum of the following:
Base Annual Salary. Subject to the payment of the following sums subject to not causing the insolvency of the Company, the equivalent of the greater of (i) twenty-four (24) months of Mr. Wellman’s then-current base salary or (ii) the remainder of the term of the employment agreement (the "Severance Period"); plus
Earned but Unpaid Amounts. Any previously earned but unpaid salary through Mr. Wellman’s final date of employment, Mr. Wellman’s termination of employment.
The employment agreement also provided the following indemnification to Mr. Wellman: The Company shall indemnify and save harmless Mr. Wellman for any liability incurred by reason of any act or omission performed by Mr. Wellman while acting in good faith on behalf of the Company. No indemnification barred by regulations or policies of the SEC or in clear violation of public policy will be permitted under the employment agreement.
Mr. Wellman’s Employment Agreement was terminated on January 10, 2024 upon his resignation as Chief Financial and Secretary.
Director Compensation
Jeffrey Guzy did not receive any cash compensation for his role as a director for the year ended December 31, 2024.
William A. Bradley did not receive any cash compensation for his role as a director for the year ended December 31, 2024.
Employee Benefit Plans
The Company currently has no employee benefit plans.
2018 Equity Incentive Plan
Our Board of Directors and stockholders approved the 2018 Equity Incentive Plan on December 31, 2018 (“2018 Plan”), which replaced the 2017 Equity Incentive Plan (“2017 Plan”) that was approved by the Board of Directors and stockholders on January 2, 2018. The Board of Directors terminated the 2017 Plan on December 31, 2018. No options or awards were granted under the 2017 Plan.
No options or other incentive compensation has been granted as of December 31, 2024.
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The following is a summary of the 2018 Plan:
2018 Plan Purpose. The 2018 Plan will allow us to grant equity awards, including performance awards, to incentivize high levels of performance and productivity by individuals who provide services to us and to further align the interests of our employees with those of CoJax and its stockholders. The use of our common stock as part of our compensation program is intended to foster a pay-for-performance culture that is an essential element of our overall compensation philosophy. Our equity will be used to retain our officers and other employees and promote a focus on sustained enhancement through improved performance. The 2018 Plan is intended to be “performance-based compensation” under Section 162(m) of the Internal Revenue Code (“Section 162(m)”), to be exempt from the tax deduction limits of Section 162(m) if they meet the other requirements of Section 162(m).
2018 Plan Administration. The Board of Directors, or the Compensation Committee of the Board of Directors when formed by the Board of Directors, has the authority to administer our 2018 Plan. Subject to the terms of the 2018 Plan, the Board of Directors or the authorized board committee, referred to as the “plan administrator,” determines recipients, dates of grant, the numbers and types of stock awards to be granted, and the terms and conditions of the stock awards, including the period of their exercisability and vesting schedule applicable to a stock award. Subject to the limitations set forth below, the plan administrator will also determine the exercise price, strike price, or purchase price of awards granted and the types of consideration to be paid for the award. The plan administrator has the authority to modify outstanding awards under our 2018 Plan. Subject to the terms of our 2018 Plan, the plan administrator has the authority, without stockholder approval, to reduce the exercise, purchase or strike price of any outstanding stock award, cancel any outstanding stock award in exchange for new stock awards, cash, or other consideration, or take any other action that is treated as a repricing under generally accepted accounting principles; provided, that, stockholders must approve any repricing of SAR’s.
2018 Plan Share Reserve. Three million shares of common stock are reserved for issuance under grants or awards made pursuant to the 2018 Plan. If a stock award granted under our 2018 Plan expires or otherwise terminates without being exercised in full, or is settled in cash, the shares of our common stock not acquired pursuant to the stock award again will become available for subsequent issuance under our 2018 Plan. The following types of shares under our 2018 Plan may become available for the grant of new stock awards under our 2018 Plan: (1) shares that are forfeited to or repurchased by us before becoming fully vested; (2) shares withheld to satisfy income or employment withholding taxes; or (3) shares used to pay the exercise or purchase price of a stock award. Shares issued under our 2018 Plan may be previously unissued shares or reacquired shares bought by us on the open market.
2018 Plan Stock Awards. Our 2018 Plan provides for the grant of incentive stock options (within the meaning of Section 422 of the Internal Revenue Code of 1986, as amended, (“Code”)), non-statutory stock options, stock appreciation rights, or SARs, restricted stock awards, restricted stock unit awards, performance-based stock awards and other forms of equity compensation, which are collectively referred to as stock awards. Our 2018 Plan also provides for the grant of performance cash awards. Incentive stock options may be granted only to employees. All other awards may be granted to employees, including officers, and to non-employee directors and consultants. Incentive and non-statutory stock options are evidenced by stock option agreements adopted by the plan administrator. The plan administrator determines the exercise price for a stock option, within the terms and conditions of our 2018 Plan, provided that the exercise price of a stock option generally cannot be less than 100% of the fair market value of our common stock on the date of grant. Options granted under our 2018 Plan vest at the rate specified by the plan administrator. The plan administrator determines the term of stock options granted under our 2018 Plan, up to a maximum of ten years. Unless the terms of an option holder’s stock option agreement provide otherwise, if an option holder’s service relationship with us, or any of our affiliates, ceases for any reason other than disability, death, or cause, the option holder may generally exercise any vested options for three months following the cessation of service. The option term will automatically be extended in the event that exercise of the option following such a termination of service is prohibited by applicable securities laws or our insider trading policy.
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Acceptable consideration for the purchase of common stock issued upon the exercise of a stock option will be determined by the plan administrator and may include (1) cash, check, bank draft, or money order, (2) a broker-assisted cashless exercise, (3) the tender of shares of our common stock previously owned by the option holder, (4) a net exercise of the option if it is a nonqualified stock option, and (5) other legal consideration approved by the plan administrator.
Unless the plan administrator provides otherwise, options generally are not transferable except by will, the laws of descent and distribution, or pursuant to a domestic relations order.
Tax Limitations on Incentive Stock Options. The aggregate fair market value, determined at the time of grant, of our common stock with respect to incentive stock options that are exercisable for the first time by an option holder during any calendar year under all of our stock plans, may not exceed $100,000. Options or portions thereof that exceed such limit will be treated as nonqualified stock options. No incentive stock option may be granted to any person who, at the time of the grant, owns or is deemed to own stock possessing more than 10% of our total combined voting power or that of any of our affiliates unless (1) the option exercise price is at least 110% of the fair market value of the stock subject to the option on the date of grant and (2) the term of the incentive stock option does not exceed five years from the date of grant.
Restricted Stock Awards. Restricted stock awards are evidenced by restricted stock award agreements adopted by the plan administrator. Restricted stock awards may be granted in consideration for (1) cash, check, bank draft, or money order, (2) services rendered to us or our affiliates, or (3) any other form of legal consideration. Common stock acquired under a restricted stock award may, but need not, be subject to a share repurchase option in our favor in accordance with a vesting schedule as determined by the plan administrator. Rights to acquire shares under a restricted stock award may be transferred only upon such terms and conditions as set by the plan administrator. Except as otherwise provided in the applicable award agreement, restricted stock unit awards that have not vested will be forfeited upon the participant’s cessation of continuous service for any reason.
Restricted Stock Unit Awards. Restricted stock unit awards are evidenced by restricted stock unit award agreements adopted by the plan administrator. Restricted stock unit awards may be granted in consideration for any form of legal consideration or no consideration. A restricted stock unit award may be settled by cash, delivery of stock, a combination of cash and stock as deemed appropriate by the plan administrator, or in any other form of the consideration set forth in the restricted stock unit award agreement. Additionally, dividend equivalents may be credited in respect of shares covered by a restricted stock unit award. Rights under a restricted stock units award may be transferred only upon such terms and conditions as set by the plan administrator. Restricted stock unit awards may be subject to vesting as determined by the plan administrator. Except as otherwise provided in the applicable award agreement, restricted stock units that have not vested will be forfeited upon the participant’s cessation of continuous service for any reason.
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Stock Appreciation Rights or “SARs.” SARs are evidenced by SAR grant agreements adopted by the plan administrator. The plan administrator determines the strike price for a SAR, which generally cannot be less than 100% of the fair market value of our common stock on the date of grant. Upon the exercise of a SAR, we will pay the participant an amount in cash or stock equal to (1) the excess of the per-share fair market value of our common stock on the date of exercise over the strike price, multiplied by (2) the number of shares of common stock with respect to which the SAR is exercised. A SAR granted under our 2018 Plan vests at the rate specified in the SAR agreement as determined by the plan administrator.
The plan administrator determines the term of SARs granted under our 2018 Plan, up to a maximum of ten years. Unless the terms of a participant’s SAR agreement provides otherwise, if a participant’s service relationship with us or any of our affiliates ceases for any reason other than cause, disability, or death, the participant may generally exercise any vested SAR for a period of three months following the cessation of service. The SARs’ term will be further extended in the event that applicable securities laws prohibit the exercise of the SAR following such a termination of service. In no event may a SAR be exercised beyond the expiration of its term.
Unless the plan administrator provides otherwise, SARs generally are not transferable except by will, the laws of descent and distribution, or pursuant to a domestic relations order. A SAR holder may designate a beneficiary, however, who may exercise the SAR following the holder’s death.
Performance Awards. Our 2018 Plan permits the grant of performance-based stock and cash awards. Our compensation committee can structure such awards so that stock or cash will be issued or paid pursuant to such award only after the achievement of certain pre-established performance goals during a designated performance period. The plan administrator determines the performance goals. The performance goals may be based on company-wide performance or performance of one or more business units, divisions, affiliates, or business segments. They may be either absolute or relative to the performance of one or more comparable companies or the performance of one or more relevant indices.
Other Stock Awards. The plan administrator may grant other awards based in whole or in part by reference to our common stock. The plan administrator will set the number of shares under the stock award and all other terms and conditions of such awards.
Changes to Capital Structure. In the event that there is a specified type of change in our capital structure, such as a stock split or recapitalization, appropriate adjustments will be made to (1) the class and a maximum number of shares reserved for issuance under our 2018 Plan, (2) the class and a maximum number of shares by which the share reserve may increase each year automatically, (3) the class and a maximum number of shares that may be issued upon the exercise of incentive stock options and (4) the class and number of shares and exercise price, strike price or purchase price, if applicable, of all outstanding stock awards.
Change in Control. The plan administrator may provide, in an individual award agreement or any other written agreement between a participant and us, that the stock award will be subject to additional acceleration of vesting and exercisability or settlement in the event of a change in control. Under our 2018 Plan, a change in control is generally (1) the acquisition by a person or entity of more than 50% of our combined voting power other than by merger, consolidation, or similar transaction, (2) a consummated merger, consolidation, or similar transaction immediately after which our stockholders cease to own more than 50% of the combined voting power of the surviving entity or (3) a consummated sale, lease or exclusive license or other disposition of all or substantially all of our consolidated assets.
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Amendment and Termination. Board of Directors has the authority to amend, suspend or terminate our 2018 Plan, provided that such action does not materially impair the existing rights of any participant without such participant’s written consent and provided further that certain types of amendments will require the approval of stockholders. No incentive stock options may be granted after the tenth anniversary of the date that the Board of Directors adopts the 2018 Plan.
Outstanding Equity Awards
There were no outstanding equity awards to our Named Executive Officers as of December 31, 2024.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
The following table lists, as of the date of this Annual Report, the number of shares of common stock beneficially owned by (i) each person, entity or group (as that term is used in Section 13(d)(3) of the Securities Exchange Act of 1934) known to the Company to be the beneficial owner of more than 5% of the outstanding common stock; (ii) each of our directors (iii) each of our Named Executive Officers and (iv) all executive officers and directors as a group. Information relating to beneficial ownership of common stock by our principal stockholders and management is based upon information furnished by each person using “beneficial ownership” concepts under the rules of the SEC. Under these rules, a person is deemed to be a beneficial owner of a security if that person directly or indirectly has or shares voting power, which includes the power to vote or direct the voting of the security, or investment power, which includes the power to dispose or direct the disposition of the security. The person is also deemed to be a beneficial owner of any security of which that person has a right to acquire beneficial ownership within 60 days. Under the SEC rules, more than one person may be deemed to be a beneficial owner of the same securities, and a person may be deemed to be a beneficial owner of securities as to which he or she may not have any pecuniary interest. Except as noted below, each person has sole voting and investment power with respect to the shares beneficially owned and each stockholder’s address is c/o CoJax Oil and Gas Corporation, 4830 Line Avenue, Suite 152, Shreveport, Louisiana, 71106. The percentages below are calculated based on 13,998,639 shares of common stock issued and outstanding as of March 31, 2025.
| Name of Beneficial Owner | Shares | Percentage | ||||||
| Executive Officers and Directors: | ||||||||
| Jeffrey J. Guzy | 1,121,241 | 8.0 | % | |||||
| William R. Downs | 135,000 | 1.0 | % | |||||
| William Allan Bradley | 10,000 | 0.1 | % | |||||
| Total Directors and Executive Officers (3 persons) | 1,266,241 | 9.1 | % | |||||
| 5% Beneficial Owners | ||||||||
| Roger Allums McLeod | 2,920,000 | 20.86 | % | |||||
| Rosswood Capital LLC(1) | 1,350,000 | 9.64 | % | |||||
| Stone Creek Properties, LLC (2) | 889,559 | 6.35 | % | |||||
| Stonefield Fund LLC (3) | 755,000 | 5.39 | % | |||||
| Lamar Resources, LLC (4) | 1,035,909 | 7.40 | % | |||||
| Lazaro Resources, LLC (5) | 729,954 | 5.21 | % | |||||
| United Oil & Gas, LLC (6) | 729,954 | 5.21 | % | |||||
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(1) Peter Biglane is the Manager of Rosswood Capital LLC and has sole voting and dispositive power over the shares held by Rosswood Capital LLC.
(2) David Sullivan is the Manager of Stone Creek Properties LLC and has sole voting and dispositive power over the shares held by Stone Creek Properties LLC.
(3) Alfonso Rivera Revilla is the Manager of Stonefield Fund LLC and has sole voting and dispositive power over the shares held by Stonefield Fund LLC.
(4) Marty Rutland is the Owner of Lamar Resources, LLC and has sole voting and dispositive power over the shares held by Lamar Resources, LLC.
(5) John young is the Owner of Lazaro Resources, LLC and has sole voting and dispositive power over the shares held by Lazaro Resources, LLC.
(6) William Wildman Jr. is the Owner of United Oil & Gas, LLC and has sole voting and dispositive power over the shares held by United Oil & Gas, LLC.
Changes in Control Agreements.
As of December 31, 2024, we are not aware of any arrangements that may result in “changes in control”, as that term is defined by the provisions of Item 403(c) of Regulation S-K.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
In addition to the executive officer compensation arrangements discussed in “Executive Compensation,” below we describe transactions since incorporation, in which we have been a participant, in which the amount involved in the transaction is material to our Company, and in which any of the following is a party:
| (a) | enterprises that directly or indirectly through one or more intermediaries, control or are controlled by, or are under common control with, our Company; |
| (b) | associates; |
| (c) | individuals owning, directly or indirectly, an interest in the voting power of our Company that gives them significant influence over our Company, and close members of any such individual’s family; |
| (d) | key management personnel, that is, those persons having authority and responsibility for planning, directing, and controlling the activities of our Company, including directors and senior management of companies and close members of such individuals’ families; and |
| (e) | enterprises in which a substantial interest in the voting power is owned, directly or indirectly, by any person described in (c) or (d) or over which such a person is able to exercise significant influence. |
Review, Approval, and Ratification of Related Party Transactions
Given our small size and limited financial resources, we have not adopted formal policies and procedures for the review, approval, or ratification of transactions, such as those described above, with our executive officer(s), Director(s), and significant stockholders. We intend to establish formal policies and procedures in the future, once we have sufficient resources and have appointed additional Directors, so that such transactions will be subject to the review, approval, or ratification of our Board of Directors, or an appropriate committee thereof. On a moving forward basis, our Directors will continue to approve any related party transaction.
On January 10, 2024, the Company issued 100,000 common shares at $0.99 per share to William R. Downs in connection with his appointment as the Company’s new Chief Financial officer. The issuance of 100,000 shares was recognized at the share price on the date of the employment agreement.
On January 26, 2024, Mr. Guzy and Mr. Wellman, being the holders of all of the Company’s Series A Stock converted all 105,000 shares issued and outstanding into common shares at a conversion rate of one to ten. The conversion occurred at the rate specified in the initial issuance agreement and therefore no gain or loss was recognized on the conversion. In connection with the exercise of the conversion option, the Company issued 575,000 and 475,000 common shares to Jeffrey J. Guzy and Wm. Barrett Wellman, respectively.
On August 20, 2024, Mr. Guzy purchased 475,000 shares of common stock from Mr. Wellman in a negotiated transaction. The transfer had no financial impact on the Company during the year ended December 31, 2024.
76
Legal Proceedings
We know of no material, active, pending, or threatened to proceed against us or our subsidiaries, nor are we, or any subsidiary, involved as a plaintiff or defendant in any material proceeding or pending litigation.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Audit and Accounting Fees
Effective as of January 4, 2024, Sadler, Gibb & Associates, LLC resigned as the Company’s independent registered public accounting firm and the Board of the Company appointed M&K CPAs, PLLC (“M&K”) as our independent registered public accounting firm for the fiscal year ended December 31, 2024. The following table sets forth the fees billed to the Company for professional services rendered by M&K and S|G for each of the years ended December 31, 2024, and 2023, respectively:
| Services | 2024 | 2023 | ||||||
| Audit fees | $ | 97,000 | $ | 51,000 | ||||
| Audit related fees | — | — | ||||||
| Tax fees | — | — | ||||||
| All other fees | — | — | ||||||
| Total fees | $ | 97,000 | $ | 51,000 | ||||
Audit Fees
The aggregate audit fees billed and unbilled for the fiscal years ended December 31, 2024, and 2023 were for professional services rendered by M&K and S|G, respectively, for the audits of our annual consolidated financial statements, the audit of our consolidated financial statements included in our registration statement on Form 10-K.
Tax Fees
The Company did not incur any aggregate tax fees billed and unbilled for the fiscal years ended December 31, 2024, and 2023.
Other Fees
The Company did not incur any other fees related to services rendered by our principal accountant for the fiscal years ended December 31, 2024, and 2023.
Effective May 6, 2003, the Securities and Exchange Commission adopted rules that require that before our auditor is engaged by us to render any auditing or permitted non-audit related service, the engagement be:
| ● | approved by our audit committee; or |
| ● | entered into pursuant to pre-approval policies and procedures established by the audit committee, provided that the policies and procedures are detailed as to the particular service, the audit committee is informed of each service, and such policies and procedures do not include delegation of the audit committee’s responsibilities to management. |
77
We do not have an audit committee. Our entire board of directors pre-approves all services provided by our independent auditors.
All of the above services and fees were reviewed and approved by the entire board of directors before the respective services were rendered.
78
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
The following exhibits are included with this Annual Report:
79
* Filed Herewith
ITEM 16. FORM 10–K SUMMARY
None.
80
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
COJAX OIL AND GAS CORPORATION
| By: | /s/ William R. Downs | |
| William R. Downs | ||
Chief Executive Officer and President (Principal Executive Officer) | ||
| Date: | March 31, 2025 | |
| By: | /s/ Jeffrey J. Guzy | |
| Jeffrey J. Guzy | ||
Chief Financial Officer (Principal Financial and Accounting Officer) | ||
| Date: | March 31, 2025 | |
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.
| By: | /s/ William R. Downs | |
| William R. Downs | ||
Chief Executive Officer and President (Principal Executive Officer) | ||
| Date: | March 31, 2025 | |
| By: | /s/ Jeffrey J. Guzy | |
| Jeffrey J. Guzy | ||
Chief Financial Officer (Principal Financial and Accounting Officer) | ||
| Date: | March 31, 2025 | |
81
Exhibit 23.1
CONSENT OF INDEPENDENT PETROLEUM ENGINEERS AND GEOLOGISTS
We hereby consent to the use of the name Netherland, Sewell & Associates, Inc., the references to our report of CoJax Oil and Gas Corporation’s proved oil and natural gas reserves estimates and future net revenue as of December 31, 2024, and the inclusion of our corresponding report letter, dated January 10, 2025, in the 2024 Annual Report on Form 10-K (the “Annual Report”) of CoJax Oil and Gas Corporation.
| NETHERLAND, SEWELL & ASSOCIATES, INC. | |||
| By: | /s/ Richard B. Talley, Jr. | ||
| Richard B. Talley, Jr., P.E. | |||
| Chairman and Chief Executive Officer | |||
Houston, Texas
March 31, 2025
EXHIBIT 31.1
CERTIFICATION PURSUANT TO SECTION 302(a)
OF THE SARBANES-OXLEY ACT OF 2002
I, William R. Downs, certify that:
| 1. | I have reviewed this Annual Report on Form 10-K of CoJax Oil and Gas Corporation, a Virginia corporation, for the year ended December 31, 2024; |
| 2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
| 3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
| 4. | The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have; |
| (a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
| (b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
| (c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
| (d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the most recent quarter (the registrant’s fourth fiscal quarter in the case of an annual report) covered by this report that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
| 5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions): |
| (a) | All significant deficiencies and material weakness in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
| (b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
| Date: March 31, 2025 | By: | /s/ William R. Downs |
| William R. Downs | ||
| Chief
Executive Officer (Principal Executive Officer) |
EXHIBIT 31.2
CERTIFICATION PURSUANT TO SECTION 302(a)
OF THE SARBANES-OXLEY ACT OF 2002
I, Jeffrey J. Guzy, certify that:
| 1. | I have reviewed this Annual Report on Form 10-K of CoJax Oil and Gas Corporation, a Virginia corporation, for the year ended December 31, 2024; |
| 2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
| 3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
| 4. | The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have; |
| (a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
| (b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
| (c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
| (d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the most recent quarter (the registrant’s fourth fiscal quarter in the case of an annual report) covered by this report that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
| 5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions): |
| (a) | All significant deficiencies and material weakness in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
| (b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
| Date: March 31, 2025 | By: | /s/ Jeffrey J. Guzy |
| Jeffrey J. Guzy | ||
Chief Financial Officer (Principal Executive Officer) | ||
EXHIBIT 32.1
CERTIFICATION PURSUANT TO 18
U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report on Form 10-K of CoJax Oil and Gas Corporation, a Virginia corporation (the “Company”), for the year ended December 31, 2024, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William R. Downs, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that;
| (1) | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and |
| (2) | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.
| Date: March 31, 2025 | By | /s/ William R. Downs |
| William R. Downs | ||
| Chief
Executive Officer (Principal Executive Officer) |
EXHIBIT 32.2
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report on Form 10-K of CoJax Oil and Gas Corporation, a Virginia corporation (the “Company”), for the year ended December 31, 2024, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jeffrey J. Guzy, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that;
| (1) | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and |
| (2) | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.
| Date: March 31, 2025 | By | /s/ Jeffrey J. Guzy |
| Jeffrey J. Guzy | ||
Chief Financial Officer (Principal Executive Officer) |
Exhibit 99.2
January 10, 2025
Mr. John Young
CoJax Oil and Gas Corporation
4830 Line Avenue, Suite 152
Shreveport, Louisiana 71106
Dear Mr. Young:
In accordance with your request, we have estimated the proved reserves and future revenue, as of December 31, 2024, to the CoJax Oil and Gas Corporation (CoJax) interest in certain oil and gas properties located in Alabama and Mississippi. We completed our evaluation on or about the date of this letter. It is our understanding that the proved reserves estimated in this report constitute all of the proved reserves owned by CoJax. The estimates in this report have been prepared in accordance with the definitions and regulations of the U.S. Securities and Exchange Commission (SEC) and, with the exception of the exclusion of future income taxes, conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas. Definitions are presented immediately following this letter. This report has been prepared for CoJax's use in filing with the SEC; in our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose.
We estimate the net reserves and future net revenue to the CoJax interest in these properties, as of December 31, 2024, to be:
| Net Reserves | Future Net Revenue (M$) | |||||||||||||||
| Oil | Gas | Present Worth | ||||||||||||||
| Category | (MBBL) | (MMCF) | Total | at 10% | ||||||||||||
| Proved Developed Producing | 162.7 | 0.0 | 7,157.2 | 4,408.7 | ||||||||||||
| Proved Developed Non-Producing | 427.0 | 861.3 | 27,435.6 | 14,517.1 | ||||||||||||
| Proved Undeveloped | 528.0 | 1,242.7 | 27,842.9 | 10,444.5 | ||||||||||||
| Total Proved | 1,117.6 | 2,104.0 | 62,435.7 | 29,370.3 | ||||||||||||
Totals may not add because of rounding.
The oil volumes shown include crude oil only. Oil volumes are expressed in thousands of barrels (MBBL); a barrel is equivalent to 42 United States gallons. Gas volumes are expressed in millions of cubic feet (MMCF) at standard temperature and pressure bases.
Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. No study was made to determine whether probable or possible reserves might be established for these properties. The estimates of reserves and future revenue included herein have not been adjusted for risk. This report does not include any value that could be attributed to interests in undeveloped acreage beyond those tracts for which undeveloped reserves have been estimated.
Gross revenue is CoJax's share of the gross (100 percent) revenue from the properties prior to any deductions. Future net revenue is after deductions for CoJax's share of production taxes, capital costs, abandonment costs, and operating expenses but before consideration of any income taxes. The future net revenue has been discounted at an annual rate of 10 percent to determine its present worth, which is shown to indicate the effect of time on the value of money. Future net revenue presented in this report, whether discounted or undiscounted, should not be construed as being the fair market value of the properties.
Prices used in this report are based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period January through December 2024. For oil volumes, the average West Texas Intermediate posted price of $71.96 per barrel is adjusted by well for quality, transportation fees, and market differentials. For gas volumes, the average Henry Hub spot price of $2.130 per MMBTU is adjusted by well for energy content, transportation fees, and market differentials. All prices are held constant throughout the lives of the properties. The average adjusted product prices weighted by production over the remaining lives of the properties are $73.68 per barrel of oil and $2.013 per MCF of gas.
Operating costs used in this report are based on operating expense records of CoJax. These costs include the per-well overhead expenses allowed under joint operating agreements along with estimates of costs to be incurred at and below the district and field levels. Since all properties are nonoperated, headquarters general and administrative overhead expenses are not included. Operating costs are not escalated for inflation.
Capital costs used in this report were provided by CoJax and are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for workovers, new development wells, and production equipment. Based on our understanding of future development plans, a review of the records provided to us, and our knowledge of similar properties, we regard these estimated capital costs to be reasonable. Abandonment costs used in this report are our estimates of the costs to abandon the wells and production facilities, net of any salvage value; these costs are based on our knowledge of similar operations. Capital costs and abandonment costs are not escalated for inflation.
For the purposes of this report, we did not perform any field inspection of the properties, nor did we examine the mechanical operation or condition of the wells and facilities. We have not investigated possible environmental liability related to the properties; therefore, our estimates do not include any costs due to such possible liability.
We have made no investigation of potential volume and value imbalances resulting from overdelivery or underdelivery to the CoJax interest. Therefore, our estimates of reserves and future revenue do not include adjustments for the settlement of any such imbalances; our projections are based on CoJax receiving its net revenue interest share of estimated future gross production. Additionally, we have made no specific investigation of any firm transportation contracts that may be in place for these properties; our estimates of future revenue include the effects of such contracts only to the extent that the associated fees are accounted for in the historical lease-level accounting statements.
The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible; probable and possible reserves are those additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, our estimates are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by CoJax, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of the interest owner to recover the reserves, and that our projections of future production will prove consistent with actual performance. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing this report.
For the purposes of this report, we used technical and economic data including, but not limited to well logs, geologic maps, well test data, production data, historical price and cost information, and property ownership interests. The reserves in this report have been estimated using deterministic methods; these estimates have been prepared in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards). We used standard engineering and geoscience methods, or a combination of methods, including performance analysis, volumetric analysis, and analogy, that we considered to be appropriate and necessary to categorize and estimate reserves in accordance with SEC definitions and regulations. A substantial portion of these reserves are for behind-pipe zones, non-producing zones, and undeveloped locations; such reserves are based on estimates of reservoir volumes and recovery efficiencies along with analogy to properties with similar geologic and reservoir characteristics. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment.
The data used in our estimates were obtained from CoJax, public data sources, and the nonconfidential files of Netherland, Sewell & Associates, Inc. (NSAI) and were accepted as accurate. Supporting work data are on file in our office. We have not examined the titles to the properties or independently confirmed the actual degree or type of interest owned. The technical persons primarily responsible for preparing the estimates presented herein meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. Connor B. Riseden, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at NSAI since 2006 and has over 4 years of prior industry experience. Edward C. Roy III, a Licensed Professional Geoscientist in the State of Texas, has been practicing consulting petroleum geoscience at NSAI since 2008 and has over 11 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis.
| Sincerely, | ||||
| NETHERLAND, SEWELL & ASSOCIATES, INC. | ||||
| Texas Registered Engineering Firm F-2699 | ||||
| By: | /s/ Richard B. Talley, Jr., | |||
| Richard B. Talley, Jr., P.E. | ||||
| Chairman and Chief Executive Officer | ||||
| By: | /s/ Connor B. Riseden | By: | /s/ Edward C. Roy III | |
| Connor B. Riseden, P.E. 100566 | Edward C. Roy III, P.G. 2364 | |||
| Vice President | Vice President | |||
| Date Signed: January 10, 2025 | Date Signed: January 10, 2025 | |||
LPV:LRG
DEFINITIONS OF OIL AND GAS RESERVES
Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a)
The following definitions are set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Section 210.4-10(a). Also included is supplemental information from (1) the 2018 Petroleum Resources Management System approved by the Society of Petroleum Engineers, (2) the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas, and (3) the SEC's Compliance and Disclosure Interpretations.
(1) Acquisition of properties. Costs incurred to purchase, lease or otherwise acquire a property, including costs of lease bonuses and options to purchase or lease properties, the portion of costs applicable to minerals when land including mineral rights is purchased in fee, brokers' fees, recording fees, legal costs, and other costs incurred in acquiring properties.
(2) Analogous reservoir. Analogous reservoirs, as used in resources assessments, have similar rock and fluid properties, reservoir conditions (depth, temperature, and pressure) and drive mechanisms, but are typically at a more advanced stage of development than the reservoir of interest and thus may provide concepts to assist in the interpretation of more limited data and estimation of recovery. When used to support proved reserves, an "analogous reservoir" refers to a reservoir that shares the following characteristics with the reservoir of interest:
| (i) | Same geological formation (but not necessarily in pressure communication with the reservoir of interest); |
| (ii) | Same environment of deposition; |
| (iii) | Similar geological structure; and |
| (iv) | Same drive mechanism. |
Instruction to paragraph (a)(2): Reservoir properties must, in the aggregate, be no more favorable in the analog than in the reservoir of interest.
(3) Bitumen. Bitumen, sometimes referred to as natural bitumen, is petroleum in a solid or semi-solid state in natural deposits with a viscosity greater than 10,000 centipoise measured at original temperature in the deposit and atmospheric pressure, on a gas free basis. In its natural state it usually contains sulfur, metals, and other non-hydrocarbons.
(4) Condensate. Condensate is a mixture of hydrocarbons that exists in the gaseous phase at original reservoir temperature and pressure, but that, when produced, is in the liquid phase at surface pressure and temperature.
(5) Deterministic estimate. The method of estimating reserves or resources is called deterministic when a single value for each parameter (from the geoscience, engineering, or economic data) in the reserves calculation is used in the reserves estimation procedure.
(6) Developed oil and gas reserves. Developed oil and gas reserves are reserves of any category that can be expected to be recovered:
| (i) | 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 |
| (ii) | Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well. |
Supplemental definitions from the 2018 Petroleum Resources Management System:
Developed Producing Reserves – Expected quantities to be recovered from completion intervals that are open and producing at the effective date of the estimate. Improved recovery Reserves are considered producing only after the improved recovery project is in operation.
Developed Non-Producing Reserves – Shut-in and behind-pipe Reserves. Shut-in Reserves are expected to be recovered from (1) completion intervals that are open at the time of the estimate but which have not yet started producing, (2) wells which were shut-in for market conditions or pipeline connections, or (3) wells not capable of production for mechanical reasons. Behind-pipe Reserves are expected to be recovered from zones in existing wells that will require additional completion work or future re-completion before start of production with minor cost to access these reserves. In all cases, production can be initiated or restored with relatively low expenditure compared to the cost of drilling a new well.
(7) Development costs. Costs incurred to obtain access to proved reserves and to provide facilities for extracting, treating, gathering and storing the oil and gas. More specifically, development costs, including depreciation and applicable operating costs of support equipment and facilities and other costs of development activities, are costs incurred to:
| (i) | Gain access to and prepare well locations for drilling, including surveying well locations for the purpose of determining specific development drilling sites, clearing ground, draining, road building, and relocating public roads, gas lines, and power lines, to the extent necessary in developing the proved reserves. |
| (ii) | Drill and equip development wells, development-type stratigraphic test wells, and service wells, including the costs of platforms and of well equipment such as casing, tubing, pumping equipment, and the wellhead assembly. |
Definitions - Page 1 of 6
DEFINITIONS OF OIL AND GAS RESERVES
Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a)
| (iii) | Acquire, construct, and install production facilities such as lease flow lines, separators, treaters, heaters, manifolds, measuring devices, and production storage tanks, natural gas cycling and processing plants, and central utility and waste disposal systems. |
| (iv) | Provide improved recovery systems. |
(8) Development project. A development project is the means by which petroleum resources are brought to the status of economically producible. As examples, the development of a single reservoir or field, an incremental development in a producing field, or the integrated development of a group of several fields and associated facilities with a common ownership may constitute a development project.
(9) Development well. A well drilled within the proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive.
(10) Economically producible. The term economically producible, as it relates to a resource, means a resource which generates revenue that exceeds, or is reasonably expected to exceed, the costs of the operation. The value of the products that generate revenue shall be determined at the terminal point of oil and gas producing activities as defined in paragraph (a)(16) of this section.
(11) Estimated ultimate recovery (EUR). Estimated ultimate recovery is the sum of reserves remaining as of a given date and cumulative production as of that date.
(12) Exploration costs. Costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects of containing oil and gas reserves, including costs of drilling exploratory wells and exploratory-type stratigraphic test wells. Exploration costs may be incurred both before acquiring the related property (sometimes referred to in part as prospecting costs) and after acquiring the property. Principal types of exploration costs, which include depreciation and applicable operating costs of support equipment and facilities and other costs of exploration activities, are:
| (i) | Costs of topographical, geographical and geophysical studies, rights of access to properties to conduct those studies, and salaries and other expenses of geologists, geophysical crews, and others conducting those studies. Collectively, these are sometimes referred to as geological and geophysical or "G&G" costs. |
| (ii) | Costs of carrying and retaining undeveloped properties, such as delay rentals, ad valorem taxes on properties, legal costs for title defense, and the maintenance of land and lease records. |
| (iii) | Dry hole contributions and bottom hole contributions. |
| (iv) | Costs of drilling and equipping exploratory wells. |
| (v) | Costs of drilling exploratory-type stratigraphic test wells. |
(13) Exploratory well. An exploratory well is a well drilled to find a new field or to find a new reservoir in a field previously found to be productive of oil or gas in another reservoir. Generally, an exploratory well is any well that is not a development well, an extension well, a service well, or a stratigraphic test well as those items are defined in this section.
(14) Extension well. An extension well is a well drilled to extend the limits of a known reservoir.
(15) 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 which 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.
(16) Oil and gas producing activities.
| (i) | Oil and gas producing activities include: |
| (A) | The search for crude oil, including condensate and natural gas liquids, or natural gas ("oil and gas") in their natural states and original locations; |
| (B) | The acquisition of property rights or properties for the purpose of further exploration or for the purpose of removing the oil or gas from such properties; |
| (C) | The construction, drilling, and production activities necessary to retrieve oil and gas from their natural reservoirs, including the acquisition, construction, installation, and maintenance of field gathering and storage systems, such as: |
| (1) | Lifting the oil and gas to the surface; and |
| (2) | Gathering, treating, and field processing (as in the case of processing gas to extract liquid hydrocarbons); and |
Definitions - Page 2 of 6
DEFINITIONS OF OIL AND GAS RESERVES
Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a)
| (D) | Extraction of saleable hydrocarbons, in the solid, liquid, or gaseous state, from oil sands, shale, coalbeds, or other nonrenewable natural resources which are intended to be upgraded into synthetic oil or gas, and activities undertaken with a view to such extraction. |
Instruction 1 to paragraph (a)(16)(i): The oil and gas production function shall be regarded as ending at a "terminal point", which is the outlet valve on the lease or field storage tank. If unusual physical or operational circumstances exist, it may be appropriate to regard the terminal point for the production function as:
| a. | The first point at which oil, gas, or gas liquids, natural or synthetic, are delivered to a main pipeline, a common carrier, a refinery, or a marine terminal; and |
| b. | In the case of natural resources that are intended to be upgraded into synthetic oil or gas, if those natural resources are delivered to a purchaser prior to upgrading, the first point at which the natural resources are delivered to a main pipeline, a common carrier, a refinery, a marine terminal, or a facility which upgrades such natural resources into synthetic oil or gas. |
Instruction 2 to paragraph (a)(16)(i): For purposes of this paragraph (a)(16), the term saleable hydrocarbons means hydrocarbons that are saleable in the state in which the hydrocarbons are delivered.
| (ii) | Oil and gas producing activities do not include: |
| (A) | Transporting, refining, or marketing oil and gas; |
| (B) | Processing of produced oil, gas, or natural resources that can be upgraded into synthetic oil or gas by a registrant that does not have the legal right to produce or a revenue interest in such production; |
| (C) | Activities relating to the production of natural resources other than oil, gas, or natural resources from which synthetic oil and gas can be extracted; or |
| (D) | Production of geothermal steam. |
(17) Possible reserves. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves.
| (i) | When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates. |
| (ii) | Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project. |
| (iii) | Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves. |
| (iv) | The proved plus probable and proved plus probable plus possible reserves estimates must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar projects. |
| (v) | Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir. |
| (vi) | Pursuant to paragraph (a)(22)(iii) of this section, where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations. |
(18) Probable reserves. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered.
| (i) | When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates. |
Definitions - Page 3 of 6
DEFINITIONS OF OIL AND GAS RESERVES
Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a)
| (ii) | Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir. |
| (iii) | Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves. |
| (iv) | See also guidelines in paragraphs (a)(17)(iv) and (a)(17)(vi) of this section. |
(19) Probabilistic estimate. The method of estimation of reserves or resources is called probabilistic when the full range of values that could reasonably occur for each unknown parameter (from the geoscience and engineering data) is used to generate a full range of possible outcomes and their associated probabilities of occurrence.
(20) Production costs.
| (i) | Costs incurred to operate and maintain wells and related equipment and facilities, including depreciation and applicable operating costs of support equipment and facilities and other costs of operating and maintaining those wells and related equipment and facilities. They become part of the cost of oil and gas produced. Examples of production costs (sometimes called lifting costs) are: |
| (A) | Costs of labor to operate the wells and related equipment and facilities. |
| (B) | Repairs and maintenance. |
| (C) | Materials, supplies, and fuel consumed and supplies utilized in operating the wells and related equipment and facilities. |
| (D) | Property taxes and insurance applicable to proved properties and wells and related equipment and facilities. |
| (E) | Severance taxes. |
| (ii) | Some support equipment or facilities may serve two or more oil and gas producing activities and may also serve transportation, refining, and marketing activities. To the extent that the support equipment and facilities are used in oil and gas producing activities, their depreciation and applicable operating costs become exploration, development or production costs, as appropriate. Depreciation, depletion, and amortization of capitalized acquisition, exploration, and development costs are not production costs but also become part of the cost of oil and gas produced along with production (lifting) costs identified above. |
(21) Proved area. The part of a property to which proved reserves have been specifically attributed.
(22) Proved oil and gas reserves. Proved oil and gas reserves are those quantities of oil and gas, which, 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.
| (i) | The area of the reservoir considered as proved includes: |
| (A) | The area identified by drilling and limited by fluid contacts, if any, and |
| (B) | 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. |
| (ii) | In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty. |
| (iii) | Where direct observation from well penetrations has defined a highest known oil (HKO) 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. |
| (iv) | Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: |
| (A) | 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 |
Definitions - Page 4 of 6
DEFINITIONS OF OIL AND GAS RESERVES
Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a)
| (B) | The project has been approved for development by all necessary parties and entities, including governmental entities. |
| (v) | Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be 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. |
(23) Proved properties. Properties with proved reserves.
(24) Reasonable certainty. If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate. A high degree of confidence exists if the quantity is much more likely to be achieved than not, and, as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease.
(25) Reliable technology. Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation.
(26) Reserves. Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project.
Note to paragraph (a)(26): Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).
Excerpted from the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas:
932-235-50-30 A standardized measure of discounted future net cash flows relating to an entity's interests in both of the following shall be disclosed as of the end of the year:
| a. | Proved oil and gas reserves (see paragraphs 932-235-50-3 through 50-11B) |
| b. | Oil and gas subject to purchase under long-term supply, purchase, or similar agreements and contracts in which the entity participates in the operation of the properties on which the oil or gas is located or otherwise serves as the producer of those reserves (see paragraph 932-235-50-7). |
The standardized measure of discounted future net cash flows relating to those two types of interests in reserves may be combined for reporting purposes.
932-235-50-31 All of the following information shall be disclosed in the aggregate and for each geographic area for which reserve quantities are disclosed in accordance with paragraphs 932-235-50-3 through 50-11B:
| a. | Future cash inflows. These shall be computed by applying prices used in estimating the entity's proved oil and gas 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. |
| b. | 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. |
| c. | 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 entity'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 and tax credits and allowances relating to the entity's proved oil and gas reserves. |
| d. | 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. |
| e. | 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. |
| f. | Standardized measure of discounted future net cash flows. This amount is the future net cash flows less the computed discount. |
Definitions - Page 5 of 6
DEFINITIONS OF OIL AND GAS RESERVES
Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a)
(27) Reservoir. A porous and permeable underground formation containing a natural accumulation of producible oil and/or gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.
(28) Resources. Resources are quantities of oil and gas estimated to exist in naturally occurring accumulations. A portion of the resources may be estimated to be recoverable, and another portion may be considered to be unrecoverable. Resources include both discovered and undiscovered accumulations.
(29) Service well. A well drilled or completed for the purpose of supporting production in an existing field. Specific purposes of service wells include gas injection, water injection, steam injection, air injection, salt-water disposal, water supply for injection, observation, or injection for in-situ combustion.
(30) Stratigraphic test well. A stratigraphic test well is a drilling effort, geologically directed, to obtain information pertaining to a specific geologic condition. Such wells customarily are drilled without the intent of being completed for hydrocarbon production. The classification also includes tests identified as core tests and all types of expendable holes related to hydrocarbon exploration. Stratigraphic tests are classified as "exploratory type" if not drilled in a known area or "development type" if drilled in a known area.
(31) Undeveloped oil and gas reserves. Undeveloped oil and gas reserves are reserves of any category 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.
| (i) | Reserves on undrilled acreage shall be 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. |
| (ii) | 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. |
From the SEC's Compliance and Disclosure Interpretations (October 26, 2009):
Although several types of projects — such as constructing offshore platforms and development in urban areas, remote locations or environmentally sensitive locations — by their nature customarily take a longer time to develop and therefore often do justify longer time periods, this determination must always take into consideration all of the facts and circumstances. No particular type of project per se justifies a longer time period, and any extension beyond five years should be the exception, and not the rule.
Factors that a company should consider in determining whether or not circumstances justify recognizing reserves even though development may extend past five years include, but are not limited to, the following:
| ● | The company's level of ongoing significant development activities in the area to be developed (for example, drilling only the minimum number of wells necessary to maintain the lease generally would not constitute significant development activities); |
| ● | The company's historical record at completing development of comparable long-term projects; |
| ● | The amount of time in which the company has maintained the leases, or booked the reserves, without significant development activities; |
| ● | The extent to which the company has followed a previously adopted development plan (for example, if a company has changed its development plan several times without taking significant steps to implement any of those plans, recognizing proved undeveloped reserves typically would not be appropriate); and |
| ● | The extent to which delays in development are caused by external factors related to the physical operating environment (for example, restrictions on development on Federal lands, but not obtaining government permits), rather than by internal factors (for example, shifting resources to develop properties with higher priority). |
| (iii) | Under no circumstances shall estimates for undeveloped reserves 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, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty. |
(32) Unproved properties. Properties with no proved reserves.
Definitions - Page 6 of 6