EDGAR 10-K Filing

Company CIK: 855787
Filing Year: 2022
Filename: 855787_10-K_2022_0001437749-22-008152.json

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ITEM 1. BUSINESS
ITEM 1. BUSINESS.
Overview
We are an independent oil and gas company engaged primarily in the exploration for, and the acquisition, development, production, and sale of, natural gas and crude oil. Our core areas of operation are in the Mid-Continent and Rocky Mountain Regions where we have developed a significant inventory of prospects that consist of proved and unproved locations, offset and on trend with existing production. Prior to December 31, 2021 we pursued various projects and entered into option agreements which were terminated, other than as described herein.
On June 30, 2020, we entered into an Option Agreement (the “Agreement”) with Progressive Well Service, LLC (“Progressive”) to acquire oil and gas assets in Logan County in Central Oklahoma (the “Coral Project”). On February 17, 2022, we entered into a Purchase and Sale Agreement (the “APA”) with Progressive and on March 9, 2022 closed on the acquisition of 34 well bores and related assets including the proceeds of production since January 1, 2022. The well bores acquired consist of developed and undeveloped proven production on the Cherokee Uplift in Central Oklahoma. Of the 34 well bores, acquired five are presently active. The Purchase Price consists of $600,000 cash the balance, after payment of option extension amounts, was paid upon closing, plus three (3%) percent of the net revenue from new wells drilled until Progressive receives three hundred and fifty thousand dollars ($350,000.00).
Strategy
We intend to generally concentrate our exploration and development efforts in fields where we can apply technical exploration and development expertise through management and consultants and where we have accumulated significant operational and exploration experience.
Our business model is to acquire oil and gas properties to be held as long-term assets through cash or equity transactions. Oil and gas commodity pricing, while admittedly volatile, has been stable enough under the current economic market conditions to encourage investment in development projects. Our lean operating structure positions us well to succeed in this very competitive market. Our strategy is to acquire producing properties that we can operate which have proven un-drilled locations available for further development. Application of enhanced drilling technologies in previously undeveloped or underdeveloped areas assures the continued value of these properties. At this time, we have secured the rights to one development property and identified two target areas meeting our criteria.
We will continue with well activations and recompletions and initiate drilling activity with the proceeds from future financings. In addition, our management’s years of experience and knowledge of the oil and gas industry lead us to believe that there are an abundance of additional good drilling prospects available that have either been overlooked or are not big enough for larger companies to pursue. In the process of identifying these drilling prospects, we will utilize the expertise of existing management and employ contract engineering firms to further evaluate the properties. To qualify for acquisition, the calculated cash flow after taxes and operating expenses is expected recover the acquisition cost in under 30 months. The cash flow calculation will be based on NYMEX flat pricing of $60.00 per barrel of oil and $3.00 per MCF of gas, further adjusted by regional differentials. In addition, the selection criteria will require the life of current producing wells to be seven years or longer and the field must have a minimum total life of 15 years.
Our business operations are in the exploration and development of oil and gas, including unconventional natural gas, in the continental United States. Specifically, in the primary oil and gas basins located within the states in the Mid-Continent and Rocky Mountain Regions listed below:
A)
Oklahoma
B)
Texas
C)
New Mexico
Corporate History and Information
Our principal executive office is located at 4162 Meyerwood Drive, Houston, TX 77025, which is where our records are kept and the principal business address for our chief Financial Officer and our telephone number is (713) 316-0061. Our website address is www.alpha-energy.us.
We were incorporated on September 26, 2013 as a Colorado corporation.
Production and Reserve Overview
The Company engaged Liquid Gold Technologies, lnc. (LGT) to evaluate and deliver a Certified SEC Reserves and Valuation Report of the Rogers County Project. On March 10, 2021, but effective December 31, 2020, LGT delivered the report, of which, a full copy is attached and incorporated herein. LGT used their interpretations of the Company's supplied data and the definitions and disclosure guidelines of the United States Securities and Exchange Commission (SEC) contained in Title 17, Code of Federal Regulations, Modernization of Oil and Gas Reporting, Final Rule released June 14, 2009 in the Federal Register (SEC regulations), to determine the Project contains Proven net reserves (all non-producing or undeveloped) of 345,110 mcf of gas and 866,340 barrels of oil/condensate with an SEC PV10% of $10,286,180. In addition, the Project contains additional Probable net reserves (all non-producing or undeveloped) of 271,910 mcf of gas and 194,500 barrels of oil/condensate with an additional SEC PV10% of $2,427,660. PV10% as of December 31, 2020 was based on SEC prices of $39.54 per barrel of oil and $1.985 per mmbtu of natural gas as calculated by LGT.
Geological and geophysical
We may engage detailed geological interpretation combined with advanced seismic exploration techniques to identify the most promising drilling sites within our leases.
Geological interpretation is based upon data recovered from existing oil and gas wells in an area and other sources. Such information is either purchased from the company that drilled the wells or becomes public knowledge through state agencies after a period of years. Through analysis of rock types, fossils and the electrical and chemical characteristics of rocks from existing wells, we can construct a picture of rock layers in the area. We will have access to the well logs and decline curves from existing operating wells. Well logs allow us to calculate an original oil or gas volume in place while decline curves from production history allow us to calculate remaining proved producing reserves.
We have not purchased, leased or entered into any agreements to purchase or lease any of the equipment necessary to conduct the geological or geophysical testing referred to herein and will only be able to do so upon raising additional capital through loans or the sale of equity securities.
Market for Oil and Gas Production
The market for oil and gas production is regulated by both the state and federal governments. The overall market is mature and with the exception of gas, all producers in a producing region will receive the same price. The major oil companies will purchase all crude oil offered for sale at posted field prices. There are price adjustments for quality differences from the Benchmark. Benchmark is Saudi Arabian light crude oil employed as the standard on which OPEC price changes have been based. Quality variances from Benchmark crude results in lower prices being paid for the variant oil. Oil sales are normally contracted with a purchaser or gatherer as it is known in the industry who will pick up the oil at the well site. In some instances, there may be deductions for transportation from the well head to the sales point. At this time the majority of crude oil purchasers do not charge transportation fees unless the well is outside their service area. The service area is a geographical area in which the purchaser of crude oil will not charge a fee for picking upon the oil. The purchaser or oil gatherer as it is called within the oil industry, will usually handle all check disbursements to both the working interest and royalty owners. We will be a working interest owner. By being a working interest owner, we are responsible for the payment of our proportionate share of the operating expenses of the well. Royalty owners and overriding royalty owners receive a percentage of gross oil production for the particular lease and are not obligated in any manner whatsoever to pay for the costs of operating the lease. Therefore, we, in most instances, will be paying the expenses for the oil and gas revenues paid to the royalty and overriding royalty interests.
Gas sales are by contract. The gas purchaser will pay the well operator 100% of the sales proceeds on or about the 25th of each and every month for the previous month's sales. The operator is responsible for all checks and distributions to the working interest and royalty owners. There is no standard price for gas. Price will fluctuate with the seasons and the general market conditions. It is our intention to utilize this market whenever possible in order to maximize revenues. We do not anticipate any significant change in the manner production is purchased; however, no assurance can be given at this time that such changes will not occur.
Acquisition of Future Leases
Our strategy is to acquire producing properties that the Company can operate which have proven un-drilled locations available for further development. Our management’s years of experience, knowledge of the oil and gas industry, and existing networks provide access to both marketed and off-market acquisition opportunities. The Company anticipates evaluating many potential acquisitions; however, to qualify for acquisition, the calculated cash flow after taxes and operating expenses will recover the acquisition cost in under 30 months. The cash flow calculation will be based on NYMEX pricing of $55 per barrel of oil and $2.50 per MCF of gas. In addition, the selection criteria will require the life of current producing wells to be seven years or longer and the field must have a minimum total life of 15 years.
Competition
The oil and gas industry is highly competitive. Our competitors and potential competitors include major oil companies and independent producers of varying sizes which are engaged in the acquisition of producing properties and the exploration and development of prospects. Most of our competitors have greater financial, personnel and other resources than we do and therefore have greater leverage in acquiring prospects, hiring personnel and marketing oil and gas. In addition, larger companies operating in the same area may be willing or able to offer oil and gas at a lower price.
We compete in Oklahoma with over 1,000 independent companies and approximately 40 significant independent operators including Marathon Oil, Contango Oil and Gas and Newfield Exploration Company in addition to over 950 smaller operations with no single producer dominating the area. Major operators such as Exxon, Shell Oil, ConocoPhillips, Mobil and others that are considered major players in the oil and gas industry retain significant interests in Texas.
We believe that we can successfully compete against other independent companies by utilizing the expertise of consultants familiar with the structures to be developed, maintaining low corporate overhead and otherwise efficiently developing current lease interests.
Government Regulation
The production and sale of oil and gas is subject to regulation by state, federal and local authorities. In most areas there are statutory provisions regulating the production of oil and natural gas under which administrative agencies may set allowable rates of production and promulgate rules in connection with the operation and production of such wells, ascertain and determine the reasonable market demand of oil and gas, and adjust allowable rates with respect thereto.
The sale of liquid hydrocarbons was subject to federal regulation under the Energy Policy and Conservation Act of 1975 which amended various acts, including the Emergency Petroleum Allocation Act of 1973. These regulations and controls included mandatory restrictions upon the prices at which most domestic and crude oil and various petroleum products could be sold. All price controls and restrictions on the sale of crude oil at the wellhead have been withdrawn. It is possible, however, that such controls may be re-imposed in the future but when, if ever, such reimposition might occur and the effect thereof is unknown.
The sale of certain categories of natural gas in interstate commerce is subject to regulation under the Natural Gas Act and the Natural Gas Policy Act of 1978 ("NGPA"). Under the NGPA, a comprehensive set of statutory ceiling prices applies to all first sales of natural gas unless the gas is specifically exempt from regulation (i.e., unless the gas is deregulated). Administration and enforcement of the NGPA ceiling prices are delegated to the Federal Energy Regulatory Commission ("FERC"). In June 1986, the FERC issued Order No. 451, which in general is designed to provide a higher NGPA ceiling price for certain vintages of old gas. It is possible that we may in the future acquire significant amounts of natural gas subject to NGPA price regulations and/or FERC Order No. 451.
Our operations are subject to extensive and continually changing regulation because of legislation affecting the oil and natural gas industry is under constant review for amendment and expansion. Many departments and agencies, both federal and state, are authorized by statute to issue and have issued rules and regulations binding on the oil and natural gas industry and its individual participants. The failure to comply with such rules and regulations can result in large penalties. The regulatory burden on this industry increases our cost of doing business and, therefore, affects our profitability. However, we do not believe that we are affected in a significantly different way by these regulations than our competitors are affected.
Transportation and Production
We can make sales of oil, natural gas and condensate at market prices, which are not subject to price controls at this time. The price that we receive from the sale of these products is affected by our ability to transport and the cost of transporting these products to market. Under applicable laws, FERC regulates:
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the construction of natural gas pipeline facilities, and
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the rates for transportation of these products in interstate commerce.
Our possible future sales of natural gas are affected by the availability, terms and cost of pipeline transportation. The price and terms for access to pipeline transportation remain subject to extensive federal and state regulation. Several major regulatory changes have been implemented by Congress and FERC from 1985 to the present. These changes affect the economics of natural gas production, transportation and sales. In addition, FERC is continually proposing and implementing new rules and regulations affecting these segments of the natural gas industry that remain subject to FERC's jurisdiction. The most notable of these are natural gas transmission companies.
FERC's more recent proposals may affect the availability of interruptible transportation service on interstate pipelines. These initiatives may also affect the intrastate transportation of gas in some cases. The stated purpose of many of these regulatory changes is to promote competition among the various sectors of the natural gas industry. These initiatives generally reflect more light-handed regulation of the natural gas industry. The ultimate impact of the complex rules and regulations issued by FERC since 1985 cannot be predicted. In addition, some aspects of these regulatory developments have not become final but are still pending judicial and FERC final decisions. We cannot predict what further action FERC will take on these matters. However, we do not believe that any action taken will affect us much differently than it will affect other natural gas producers, gatherers and marketers with which we might compete.
Effective as of January 1, 1995, FERC implemented regulations establishing an indexing system for transportation rates for oil. These regulations could increase the cost of transporting oil to the purchaser. We do not believe that these regulations will affect us any differently than other oil producers and marketers with which we compete.
Drilling and Production.
Our anticipated drilling and production operations are subject to regulation under a wide range of state and federal statutes, rules, orders and regulations. Among other matters, these statutes and regulations govern:
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the amounts and types of substances and materials that may be released into the environment;
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the discharge and disposition of waste materials,
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the reclamation and abandonment of wells and facility sites, and
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the remediation of contaminated sites, and require:
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permits for drilling operations,
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drilling bonds, and
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reports concerning operations.
Environmental Regulations
General. Our operations are affected by various state, local and federal environmental laws and regulations, including the:
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Clean Air Act,
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Oil Pollution Act of 1990,
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Federal Water Pollution Control Act,
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Resource Conservation and Recovery Act ("RCRA"),
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Toxic Substances Control Act, and
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Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA").
These laws and regulations govern the discharge of materials into the environment or the disposal of waste materials, or otherwise relate to the protection of the environment. In particular, the following activities are subject to stringent environmental regulations:
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drilling,
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development and production operations,
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activities in connection with storage and transportation of oil and other liquid hydrocarbons, and
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use of facilities for treating, processing or otherwise handling hydrocarbons and wastes.
Violations are subject to reporting requirements, civil penalties and criminal sanctions. As with the industry generally, compliance with existing regulations increases our overall cost of business. The increased costs cannot be easily determined. Such areas affected include:
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unit production expenses primarily related to the control and limitation of air emissions and
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the disposal of produced water,
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capital costs to drill exploration and development wells resulting from expenses primarily related to the management and disposal of drilling fluids and other oil and natural gas exploration wastes, and
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capital costs to construct, maintain and upgrade equipment and facilities and remediate, plug and abandon inactive well sites and pits.
Environmental regulations historically have been subject to frequent change by regulatory authorities. Therefore, we are unable to predict the ongoing cost of compliance with these laws and regulations or the future impact of such regulations on our operations.
A discharge of hydrocarbons or hazardous substances into the environment could subject us to substantial expense, including both the cost to comply with applicable regulations pertaining to the cleanup of releases of hazardous substances into the environment and claims by neighboring landowners and other third parties for personal injury and property damage. We do not maintain insurance for protection against certain types of environmental liabilities.
The Clean Air Act requires or will require most industrial operations in the United States to incur capital expenditures in order to meet air emission control standards developed by the EPA and state environmental agencies. Although no assurances can be given, we believe the Clean Air Act requirements will not have a material adverse effect on our financial condition or results of operations.
RCRA is the principal federal statute governing the treatment, storage and disposal of hazardous wastes. RCRA imposes stringent operating requirements, and liability for failure to meet such requirements, on a person who is either:
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a "generator" or "transporter" of hazardous waste, or
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an "owner" or "operator" of a hazardous waste treatment, storage or disposal facility.
At present, RCRA includes a statutory exemption that allows oil and natural gas exploration and production wastes to be classified as nonhazardous waste. As a result, we will not be subject to many of RCRA's requirements because our operations will probably generate minimal quantities of hazardous wastes.
CERCLA, also known as "Superfund," imposes liability, without regard to fault or the legality of the original act, on certain classes of persons that contributed to the release of a "hazardous substance" into the environment. These persons include:
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the "owner" or "operator" of the site where hazardous substances have been released, and
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companies that disposed or arranged for the disposal of the hazardous substances found at the site.
CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. In the course of our ordinary operations, we could generate waste that may fall within CERCLA's definition of a "hazardous substance." As a result, we may be liable under CERCLA or under analogous state laws for all or part of the costs required to clean up sites at which such wastes have been disposed. Under such law we could be required to:
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remove or remediate previously disposed wastes, including wastes disposed of or released by prior owners or operators,
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clean up contaminated property, including contaminated groundwater, or
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perform remedial plugging operations to prevent future contamination.
We could also be subject to other damage claims by governmental authorities or third parties related to such contamination.
Employees
As of December 31, 2021, we have one employee, John Lepin, our CFO, who also serves as Chairman of the Board of Directors and has three (3) Directors who are non-employees. On June 1, 2020, the Company contracted with Leaverite Consulting to engage Jay Leaver as Interim President. On April 1, 2021, the Company entered into an agreement with Kelloff Oil & Gas, LLC to engage Joe Kelloff as Interim Senior Vice President of Operations. We consider our relations with our subcontractors to be good.
Company's Office
Our office is located at 4162 Meyerwood Drive, Houston, Texas 77025 and our telephone number is (713) 316-0061.
Available Information
You can access, free of charge, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to these reports as filed with the SEC under the Securities Exchange Act of 1934, as amended on the SEC’s website www.sec.gov. These documents may also be accessed on our website: www.alpha-energy.us. These documents are placed on our website as soon as is reasonably practicable after their filing with the SEC. The information contained in, or that can be accessed through, the website is not part of this Annual Report on Form 10-K.

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ITEM 1A. RISK FACTORS
ITEM 1A. RISK FACTORS.
Certain factors may have a materially adverse effect on our business, financial condition, and results of operations, including the risk, factors, and uncertainties described under this Part I, Item 1A, and elsewhere in this Annual Report. This is not an exhaustive list, and there are other factors that may be applicable to our business that are not currently known to us or that we currently do not believe are material. Any of these risks could have an adverse effect on our business, financial condition, operating results, or prospects, which could cause the trading price of our common stock to decline, and you could lose part or all of your investment. You should carefully consider the risks, factors, and uncertainties described below, together with the other information contained in this Annual Report, as well as the risk, factors, uncertainties, and other information we disclose in other filings we make with the SEC before making an investment decision regarding our securities.
Risks Related To Our Common Stock
Our management and others have voting control of the Company.
Our current officers and directors currently own approximately 5% of the total issued and outstanding common stock of the Company. In addition, AEI Acquisition Company, LLC (“AEI”) owns approximately 84% of the total issued and outstanding common stock of the Company and has advanced $413,206 under the terms of the Company’s 7.25% Convertible Promissory Notes due February 25, 2024 (the “7.25% Notes”). The 7.25% Notes are currently convertible at $5.00 per share and presently represent an additional 82,641 shares of common stock of the Company upon conversion. See “Terms of 7.25% Convertible Notes on Footnote 11”. Accordingly, AEI and its controlling member Harry McMillan, may be deemed to have voting control over the common stock of the Company and alone or together with other members of management, if they act together, will be able to influence the outcome of all corporate actions requiring approval of our shareholders, including the election of directors and approval of significant corporate transactions, which may result in corporate action with which other stockholders do not agree. This concentration of ownership may have the effect of delaying or preventing a change in control and may adversely affect the market price of our common stock.
Our Bylaws provide that we will indemnify our directors, and that we have the power to indemnify our officers and employees, to the fullest extent permitted by law.
Our Bylaws (the “Bylaws”) provide that we will indemnify our directors, officers and employees to the fullest extent permitted by applicable law against expenses judgments, fines, settlements, and other amounts actually and reasonably incurred in connection with any proceeding. Our Bylaws also provide that the Company shall have the power (though not the obligation), to advance expenses incurred in connection with any indemnification obligation. These indemnification provisions may discourage shareholders from bringing a lawsuit against directors for breach of their fiduciary duties. They may also reduce the likelihood of derivative litigation against directors and officers, even though an action, if successful, might provide a benefit to us and our shareholders. Our results of operations and financial condition may be harmed to the extent we pay the costs of settlement and damage awards against directors, officers and key employees pursuant to these indemnification provisions.
Our failure to maintain effective internal controls over financial reporting could have an adverse impact on us.
We are required to establish and maintain appropriate internal controls over financial reporting. Failure to establish those controls, or any failure of those controls once established, could adversely impact our public disclosures regarding our business, financial condition or results of operations. In addition, management’s assessment of internal controls over financial reporting may identify weaknesses and conditions that need to be addressed in our internal controls over financial reporting or other matters that may raise concerns for investors. Any actual or perceived weaknesses and conditions in our internal controls could have a material adverse effect on our business, results of operations, cash flows and growth plans, on our regulatory and reporting status, and on our stock price.
Our business and stock price could be adversely affected if we are not successful in enhancing our management, systems, accounting, controls and reporting performance.
We have experienced, and may continue to experience, difficulties in implementing the management, operations and accounting systems, controls and procedures necessary to support our growth and expanded operations, as well as difficulties in complying with the accounting and reporting requirements related to our business. With respect to enhancing our management and operations team, we may experience difficulties in finding and retaining qualified personnel, and if such personnel are not available, we may incur higher recruiting, relocation, and compensation expense. In an effort to meet the demands of our planned activities, we will be required to supplement our staff with contract and consultant personnel until we are able to hire new employees. We further may not be successful in our efforts to enhance our systems, accounting, controls and reporting performance. All of this may have a material adverse effect on our business, results of operations, cash flows and growth plans, on our regulatory and reporting status, and on our stock price.
We have never paid dividends and we do not expect to pay dividends for the foreseeable future
We intend to retain earnings, if any, to finance the growth and development of our business and do not intend to pay cash dividends on shares of our common stock in the foreseeable future. The payment of future cash dividends, if any, depends upon, among other things, conditions then existing including earnings, financial condition and capital requirements, restrictions in financing agreements, business opportunities and other factors. As a result, capital appreciation, if any, of our common stock, will be your sole source of gain for the foreseeable future.
We are not traded on any national securities exchange. An active, liquid trading market for our common stock may not develop or be sustained. If and when an active market develops the price of our common stock may be volatile.
Presently, our common stock is not traded on any market, but is quoted on the OTC Pink Open Markets under the symbol “APHE” established by OTC Markets which does not establish financial standards or disclosure requirements for trading. As a result, Pink Open Markets trading is often avoided by investors or disallowed for traders and fund managers. We are in our early stages, an investment in our company will require a long-term commitment, with no certainty of return. Presently there is limited interest in our stock and 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 your ability to sell your shares at the time you wish to sell them or at a price that you consider reasonable. The lack of an active market may also reduce the fair market value of your shares. An inactive market may also impair our ability to raise capital to continue to fund operations by selling shares.
Trading in stocks quoted on the Pink Open Market 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. Moreover, the Pink Open Market is not a stock exchange, and trading of securities is often more sporadic than the trading of securities listed on a quotation system like NASDAQ or a national stock exchange like the NYSE Mkts. Accordingly, stockholders may have difficulty reselling any shares of common stock.
Our Board of Directors may authorize and issue shares of new classes of stock that could be superior to or adversely affect current holders of our common stock.
Our board of directors has the power to authorize and issue shares of classes of stock, including preferred stock that have voting powers, designations, preferences, limitations and special rights, including preferred distribution rights, conversion rights, redemption rights and liquidation rights without further shareholder approval which could adversely affect the rights of the holders of our common stock. In addition, our board could authorize the issuance of a series of preferred stock that has greater voting power than our common stock or that is convertible into our common stock, which could decrease the relative voting power of our common stock or result in dilution to our existing common stockholders.
Any of these actions could significantly adversely affect the investment made by holders of our common stock. Holders of common stock could potentially not receive dividends that they might otherwise have received. In addition, holders of our common stock could receive less proceeds in connection with any future sale of the Company, whether in liquidation or on any other basis.
Our shares will be subordinate to all of our debts and liabilities, which increases the risk that you could lose your entire investment.
Our shares are equity interests that will be subordinate to all of our current and future indebtedness with respect to claims on our assets. In any liquidation, all of our debts and liabilities must be paid before any payment is made to our shareholders.
Future capital raises may dilute our existing stockholders’ ownership and/or have other adverse effects on our operations.
If we raise additional capital by issuing equity securities, our existing stockholders’ percentage ownership may decrease, and these stockholders 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 stockholders.
The market price of our shares of common stock is subject to fluctuation.
The market prices of our shares may fluctuate significantly in response to factors, some of which are beyond our control, including:
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The announcement of new developments by our competitors
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The release of new technologies by our competitors
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Developments in pricing, costs and other factors affecting industry or targets
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General market conditions including factors unrelated to our operating performance
Recently, the stock market, in general, has experienced extreme price and volume fluctuations. Continued market fluctuations could result in extreme market volatility in the price of our shares of common stock which could
Offers or availability for sale of a substantial number of shares of our common stock may cause the price of our common stock to decline.
If our stockholders sell substantial amounts of our common stock in the public market upon the expiration of any statutory holding period, under Rule 144, or issued upon the exercise of outstanding warrants, it could create a circumstance commonly referred to as an "overhang" and in anticipation of which the market price of our common stock could fall. The existence of an overhang, whether or not sales have occurred or are occurring, also could make more difficult our ability to raise additional financing through the sale of equity or equity-related securities in the future at a time and price that we deem reasonable or appropriate. The shares of our restricted common stock will be freely tradable upon the earlier of: (i) effectiveness of a registration statement covering such shares and (ii) the date on which such shares may be sold without registration pursuant to Rule 144 (or other applicable exemption) under the Securities Act.
Investor relations activities, nominal “float” and supply and demand factors may affect the price of our stock.
We expect to utilize various techniques such as non-deal road shows and investor relations campaigns in order to create investor awareness for us. These campaigns may include personal, video and telephone conferences with investors and prospective investors in which our business practices are described. We may provide compensation to investor relations firms and pay for newsletters, websites, mailings and email campaigns that are produced by third-parties based upon publicly-available information concerning us. We do not intend to review or approve the content of such analysts’ reports or other materials based upon analysts’ own research or methods. Investor relations firms should generally disclose when they are compensated for their efforts, but whether such disclosure is made or complete is not under our control. In addition, investors in us may, from time to time, also take steps to encourage investor awareness through similar activities that may be undertaken at the expense of the investors. Investor awareness activities may also be suspended or discontinued which may impact the trading market our common stock.
The SEC and FINRA enforce various statutes and regulations intended to prevent manipulative or deceptive devices in connection with the purchase or sale of any security and carefully scrutinize trading patterns and company news and other communications for false or misleading information, particularly in cases where the hallmarks of “pump and dump” activities may exist, such as rapid share price increases or decreases. We, and our shareholders may be subjected to enhanced regulatory scrutiny due to the small number of holders who initially will own the shares of our common stock publicly available for resale, and the limited trading markets in which such shares may be offered or sold which have often been associated with improper activities concerning penny-stocks, such as the OTC Bulletin Board or the OTCQB Marketplace or Pink Open Markets (OTC Pink). Until such time as our restricted shares are registered or available for resale under Rule 144, there will continue to be a small percentage of shares held by a small number of investors, many of whom acquired such shares in privately negotiated purchase and sale transactions, which will constitute the entire available trading market. The Supreme Court has stated that manipulative action is a term of art connoting intentional or willful conduct designed to deceive or defraud investors by controlling or artificially affecting the price of securities. Often times, manipulation is associated by regulators with forces that upset the supply and demand factors that would normally determine trading prices. Since only a small percentage of our shares of outstanding common stock will initially be available for trading and will be held by a small number of individuals and entities, the supply of our common stock for sale will be extremely limited for an indeterminate length of time, which could result in higher bids, asks or sales prices than would otherwise exist. Securities regulators have often cited factors such as thinly-traded markets, small numbers of holders, and awareness campaigns as hallmarks of claims of price manipulation and other violations of law when combined with manipulative trading, such as wash sales, matched orders or other manipulative trading timed to coincide with false or touting press releases. There can be no assurance that our or third-parties’ activities, or the small number of potential sellers or small percentage of stock in the “float,” or determinations by purchasers or holders as to when or under what circumstances or at what prices they may be willing to buy or sell stock will not artificially impact (or would be claimed by regulators to have affected) the normal supply and demand factors that determine the price of the stock, which could subject us to regulatory action and lawsuits.
Our common stock is subject to the “penny stock” rules of the SEC, which makes transactions in our stock cumbersome and may reduce the value of an investment in our stock.
Our common stock is considered a “Penny Stock”. The Securities and Exchange Commission has adopted Rule 15g-9 which generally defines "penny stock" to be any equity security that has a market price (as defined) less than $5.00 per share or an exercise price of less than $5.00 per share, subject to certain exceptions. Our securities are covered by the penny stock rules, which impose additional sales practice requirements on broker-dealers who sell to persons other than established customers and "accredited investors". The term "accredited investor" refers generally to institutions with assets in excess of $5,000,000 or individuals with a net worth in excess of $1,000,000 or annual income exceeding $200,000 or $300,000 jointly with their spouse. The penny stock rules require a broker-dealer, prior to a transaction in a penny stock not otherwise exempt from the rules, to deliver a standardized risk disclosure document in a form prepared by the SEC which provides information about penny stocks and the nature and level of risks in the penny stock market. The broker-dealer also must provide the customer with current bid and offer quotations for the penny stock, the compensation of the broker-dealer and its salesperson in the transaction and monthly account statements showing the market value of each penny stock held in the customer's account. The bid and offer quotations, and the broker-dealer and salesperson compensation information, must be given to the customer orally or in writing prior to effecting the transaction and must be given to the customer in writing before or with the customer's confirmation. In addition, the penny stock rules require that prior to a transaction in a penny stock not otherwise exempt from these rules; the broker-dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser's written agreement to the transaction. These disclosure requirements may have the effect of reducing the level of trading activity in the secondary market for the stock that is subject to these penny stock rules. Consequently, these penny stock rules may affect the ability of broker-dealers to trade our securities. We believe that the penny stock rules discourage investor interest in and limit the marketability of our common stock. The Financial Industry Regulatory Authority, or FINRA, has adopted sales practice requirements which may also limit a stockholder's ability to buy and sell our stock. In addition to the "penny stock" rules described above, 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. FINRA requirements make it more difficult for broker-dealers to recommend that their customers buy our common stock, which may limit investors’ ability to buy and sell our stock and have an adverse effect on the market for our shares.
Risk Factors Relating to Our Business
The coronavirus disease 2019 (COVID-19) pandemic has had, and may continue to have, an adverse effect on our business, results of operations, financial condition and cash flows. Future epidemics or other public health emergencies could have similar effects.
Our operations expose us to risks associated with pandemics, epidemics or other public health emergencies, such as the COVID-19 pandemic which spread from China to many other countries including the United States. In March 2020, the World Health Organization characterized COVID-19 as a pandemic, and the President of the United States declared the COVID-19 outbreak a national emergency. The outbreak resulted in governments around the world implementing stringent measures to help control the spread of the virus, followed by phased regulations and guidelines for reopening communities and economies. In addition, governments and central banks in several parts of the world have enacted fiscal and monetary stimulus measures to counteract the impacts of COVID-19.
We are a company operating in a critical infrastructure industry, as defined by the U.S. Department of Homeland Security. Consistent with federal guidelines and with state and local orders to date, we have continued to operate across our footprint. Notwithstanding our continued operations, COVID-19 has negatively impacted and may have further negative impacts on our financial performance, operations, supply chain and flows of raw materials, transportation and logistics networks and customers. Due in large part to the impacts of and response to the spread of COVID-19, global economic conditions declined sharply during the second quarter of fiscal 2020, resulting in historic unemployment levels, rapid changes in supply and demand in certain industry sectors, businesses switching to remote work or ceasing operations, and consumers eliminating, restricting or redirecting spending. The economic downturn adversely affected demand for our products and contributed to weaker supply and demand conditions affecting prices and volumes in the markets for our products, services and raw materials.
The COVID-19 pandemic could further negatively impact our business or results of operations through the temporary closure of our operating locations or those of our customers or suppliers. In addition, the ability of our employees and our suppliers’ and customers’ employees to work may be significantly impacted by individuals contracting or being exposed to COVID-19, or as a result of prevention and control measures, which may significantly hamper our production throughout the supply chain and constrict sales channels.
Because the severity, magnitude and duration of the COVID-19 pandemic and its economic consequences are uncertain, continually changing and difficult to predict, the pandemic’s impacts on our operations and financial performance, as well as its impact on our ability to successfully execute our business strategies and initiatives, are also uncertain and difficult to predict. Further, the ultimate impact of the COVID-19 pandemic on our operations and financial performance depends on many factors that are not within our control, including, but not limited to: governmental, business and individuals’ actions that have been and continue to be taken in response to the pandemic (including restrictions on travel and transportation and workforce pressures); the impact of the pandemic and actions taken in response on global and regional economies and on levels of economic activity; the availability of federal, state or local funding programs; general economic uncertainty in key global markets and financial market volatility; global economic conditions and levels of economic growth; and the pace of recovery when the COVID-19 pandemic subsides. While we expect the COVID-19 pandemic to continue to negatively impact our results of operations, cash flows and financial position, the current level of uncertainty over the economic and operational impacts of COVID-19 means the related financial impact cannot be reasonably estimated at this time.
The COVID-19 pandemic has resulted in a severe worldwide economic downturn, significantly disrupting the demand for oil throughout the world and has created significant volatility, uncertainty and turmoil in the oil and gas industry. This has led to a significant global oversupply of oil and a subsequent substantial decrease in oil prices. While global oil producers, including the Organization of Petroleum Exporting Countries (“OPEC”) and other oil producing nations reached an agreement to cut oil production in April 2020, downward pressure on, and volatility in, commodity prices has remained and could continue for the foreseeable future, particularly given concerns over available storage capacity for oil, which have negatively affected and are expected to continue to negatively affect our cash flow, liquidity and financial position. Oil prices are expected to continue to be volatile as a result of these events and the ongoing COVID-19 pandemic, and as changes in oil inventories, oil demand and economic performance are reported. We cannot predict when, or to what extent, the negative effects of COVID-19 on the world and domestic economies, and on our industry and Company, will improve, or when oil prices will improve and stabilize.
Recent events involving military action in the Ukraine by Russia have recently countermanded the effect of COVID-19 on the price of energy. It is impossible to determine if recent increases in energy prices and restrictions from government boycotts on the importation of oil and gas from Russia are or will be felt in the foreseeable future and continue to result in historically high prices of oil and gas presently experiences.
Prices fluctuate and decline based on factors beyond our control. Factors that can cause price fluctuations and declines include:
● Overall economic and market conditions, domestic and global.
● The impact of the COVID-19 pandemic, including reduced demand for oil and natural gas, economic slowdown, governmental actions and stay-at-home orders.
● The domestic and foreign supply of oil and natural gas.
● The level of consumer product demand.
● The cost of exploring for, developing, producing, refining and marketing oil, natural gas and NGLs.
● Adverse weather conditions, natural disasters, climate change and health emergencies and pandemics.
● The price and availability of competitive fuels such as LNG, heating oil and coal, and alternative fuels.
● Political and economic conditions in the Middle East, Russia and other oil and natural gas producing regions.
● The ability of the members of OPEC and other oil exporting nations to agree to and maintain oil price and production controls.
● Domestic and foreign governmental regulations, including temporary orders limiting economic activity.
● Special taxes on production or the loss of tax credits and deductions.
● Technological advances affecting energy consumption and sources of energy supply.
● Access to pipelines and gas processing plants and other capacity constraints or production disruptions.
● The effects of energy conservation efforts, including by virtue of shareholder activism or activities of non-governmental organizations.
We may not be able to continue operating as a going concern.
We have generated minimal revenues and our ability to pay our expenses is dependent upon advances from related parties.
For the fiscal year ended December 31, 2021, we reported a net loss of $1,070,738. We had a working capital deficit of $2,601,105 at December 31, 2021. We have generated minimal revenue from our operations and are dependent upon a line of credit or other advances from AEI, a related party, to pay our operating expenses and the continued development of our business plan. There are no assurances this related party will continue to advance funds to us that will satisfy our working capital needs until such time as we are able to raise additional capital or generate sufficient revenues to fund our operating expenses. While we seek ways to continue to operate by securing additional financing resources or alliances or other partnership agreements, we do not at this time have any commitments or agreements that provide for additional capital resources.
We have experienced losses from operations since inception and have never generated positive cash flow. The success of our business plan during the next 12 months and beyond will be contingent upon generating sufficient revenue to cover our operating costs and obtaining additional financing. The report from our independent registered public accounting firm for the fiscal year ended 2021 and 2020 includes an explanatory paragraph stating the Company has recurring net losses from operations, negative operating cash flows, does not yet generate revenue from operations and will need additional working capital for ongoing operations. 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.
We have incurred net losses since inception.
We have accumulated net losses of approximately $5,371,918 as of December 31, 2021. These losses have had an adverse effect on our financial condition, stockholders’ equity, net current assets, and working capital. We will need to generate higher revenues and control operating costs in order to attain profitability. There can be no assurances that we will be able to do so or to reach profitability.
We will need additional capital to fund our expanding operations, and if we are not able to obtain sufficient capital, we may be forced to limit the scope of our operations.
We will need additional financing which we may not be able to obtain on acceptable terms if at all. We expect that our planned expansion and acquisition and development of oil and gas properties will require additional working capital. If adequate additional debt and/or equity financing is not available on reasonable terms or at all, then we may not be able to continue to develop our business activities, and we will have to modify our business plan. These factors could have a material adverse effect on our future operating results and our financial condition.
If we are unable to raise needed additional funds to continue as a going concern, we could be forced to cease our business activities and dissolve. In such an event, we may incur additional financial obligations, including the accelerated maturity of debt obligations, lease termination fees, employee severance payments, and other creditor and dissolution-related obligations.
Our ability to raise financing through sales of equity securities depends on general market conditions and the demand for our common stock. We may be unable to raise adequate capital through sales of equity securities, and if our stock has a low market price at the time of such sales, our existing stockholders could experience substantial dilution. If adequate financing is not available or unavailable on acceptable terms, we may find we are unable to fund expansion, continue offering products and services, take advantage of acquisition opportunities, develop or enhance services or products, or to respond to competitive pressures in the industry which may jeopardize our ability to continue operations.
Our current operations are not sufficient to fund our operating expenses and we will need to raise additional working capital to continue to implement our business model, to provide funds for marketing to support our efforts to increase our revenues and for general overhead expenses. Generally, small businesses such as ours for which there is only a limited public market for their securities face significant difficulties in their efforts to raise equity capital. While to date we have relied upon the relationships of our executives, directors and shareholders in our capital raising efforts, there are no assurances that these resources will continually be available to us or provide us with sufficient funding. We do not have any commitments to provide additional capital and there are no assurances we will be able to raise capital upon terms which are favorable to our company. Even if we are able to raise capital, the structure of that capital raise could impact our company and our shareholders in a variety of ways. If we raise additional capital through the issuance of debt, this will result in interest expense. If we raise additional funds through the issuance of equity or convertible debt securities, the percentage ownership of our company held by existing shareholders will be reduced and those shareholders may experience significant dilution. In addition, new securities may contain certain rights, preferences or privileges that are senior to those of our common stock. We cannot assure you that we will be able to raise the working capital as needed in the future on terms acceptable to us, if at all. If we do not raise funds as needed, we may not be able to continue to implement our business plan.
Our products may not be accepted by our targeted customers.
The risks, uncertainties and challenges encountered by companies operating in new industries include:
• Generating sufficient revenue to cover operating costs and sustain operations;
• Acquiring and maintaining market share;
• Attracting and retaining qualified personnel, especially with requisite technical skills;
• Successfully developing and commercially marketing energy resources:
• Accessing the capital markets to raise additional capital, on reasonable terms, if and when required to sustain operations or to grow the business.
We face competition from larger companies that have substantially greater resources which challenges our ability to establish market share, grow the business, and reach profitability.
The industry in which we operate is dominated by a wide range of significantly larger companies which have substantially greater financial, management, exploration and development resources than we have. According to Forbes Global 2000 PetroChina, Sinopec, Saudi Aramco, BP, Exxon Mobil, Royal Dutch Shell, Total, Chevron, Gazprom and Marathon Petroleum are the ten largest oil and gas companies by revenue. Our competitors may be able to provide customers with different or greater capabilities than we can provide, including quantity, pricing, and support. Many of our competitors may utilize their greater resources to develop resources inaccessible to us, leverage their multi-national presence, financial strength to utilize economies of scale and offer lower pricing. In order to secure contracts, we may have to offer comparable products and services at lower pricing which could adversely affect our operating margins. Our inability to compete effectively against these larger companies could have a material adverse effect on our business, financial condition and operating results.
We may not be able to keep pace with technological advances.
The oil and gas industry in general, and the energy industry in particular, continue to undergo significant changes, primarily due to technological developments. Because of the rapid growth of technology, shifting consumer tastes and the popularity and availability of other forms of energy, it is impossible to predict the overall effect these factors could have on potential revenue from, and profitability of, oil and gas exploration and drilling. It is impossible to predict the overall effect these factors could have on our ability to compete effectively in a changing market, and if we are not able to keep pace with technological advances, then our revenues, profitability and results from operations may be materially adversely affected.
Our results of operations may fluctuate from period to period which could cause volatility in our stock price.
Results of operations for any company developing oil and gas can be expected to fluctuate until the products are in the market and could fluctuate thereafter even when products are in the marketplace. There is significant lead time in developing, opening and reopening wells. Unanticipated delays can adversely impact the release of supplies into the marketplace. Revenues generated could be adversely impacted if a lack of working capital limits our ability to purchase new assets.
Our results of operations depend significantly upon the price and forward contract value of our reserves and production, none of which can be predicted with certainty. Accordingly, our revenues and results of operations may fluctuate from period to period. The results of one period may not be indicative of the results of any future period. Any quarterly fluctuations that we report in the future may not match the expectations of market analysts and investors. This could cause the price of our common stock to fluctuate significantly.
The loss of key personnel may adversely affect our business.
The officers and directors for the Company are involved in other business activities and may, in the future, become involved in other business opportunities. If a specific business opportunity becomes available, such persons may face a conflict in selecting between the Company and their other business interests. The Company has not formulated a policy for the resolution of such conflicts.
Our success is dependent upon the continued efforts of our largest shareholder, AEI and Jay Lever, our President. If it became necessary to replace them, it is unlikely new management could be found with the same level of knowledge and dedication to our success. The loss of the services of these professionals, especially in the development of future expansion prospects, would adversely affect our business. None of these advisors or executives have employment agreements or provisions that would restrict or prohibit them from competing with us. As a result, any of these individuals could terminate their employment and immediately compete against us. The loss of the services of any member of our executive management team or other key persons could have a material adverse effect on our business, results of operations and financial condition.
We may lose the services of key management personnel and may not be able to attract and retain other necessary personnel.
Changes in our management could have an adverse effect on our business, and in particular while our staff is relatively small with no full-time employees, we are dependent upon the active participation of several key management and outside personnel, including Jay Leaver, an investor and our President and Harry McMillan of AEI. Each of these persons are critical to the strategic direction and overall management of our company as well as our ability to attract and retain personnel, contractors, and investors. The loss of any of them could adversely affect our business, financial condition, and operating results. We do not carry key person life insurance on any of our personnel.
We will need to hire and retain highly skilled technical personnel as employees and as independent contractors in order to develop our properties and grow our business. The competition for highly skilled technical, managerial, and other personnel is at times intense. Our recruiting and retention success is substantially dependent upon our ability to offer competitive salaries and benefits to our employees. We must compete with companies that possess greater financial and other resources than we do and that may be more attractive to potential employees and contractors. To be competitive, we may have to increase the compensation, bonuses, stock options and other fringe benefits we offer to employees in order to attract and retain such personnel. The costs of retaining or attracting new personnel may have a material adverse effect on our business and operating results. If we fail to attract and retain the technical and managerial personnel required to be successful, our business, operating results and financial condition could be materially adversely affected.
Litigation could harm our business or otherwise distract management.
Substantial, complex or extended litigation could cause us to incur large expenditures and could distract management. For example, lawsuits by environmental groups, employees or stockholders or litigation with federal, state or local governments or regulatory bodies could be very costly and disrupt business. While disputes from time to time are not uncommon, we may not be able to resolve such disputes on terms favorable to us which could have a material, adverse impact on our results of operations and financial condition.
If we lose our rights under our third-party leases, our operations could be adversely affected.
Our business depends in part on property leases and other rights licensed from third parties. We could lose our exclusivity or other rights if we fail to comply with the terms and performance requirements of the leases, including continuing to produce oil and gas on leased properties. In addition, certain leases may terminate upon our breach and have the right to consent to sublease arrangements. If we were to lose our rights under any of these leases, or if we were unable to obtain required consents to future subleases, we could lose a competitive advantage in the market, and may even lose the ability to operate completely. Either of these results could substantially decrease our revenues
The nature of our business involves significant risks and uncertainties that may not be covered by insurance or indemnity, including the Logan assets.
We develop and sell resources where insurance or indemnification may not be available, including failure of certain of our activities could result in loss of life or property damage. Certain activities may raise questions with respect to issues of environmental harm or injury, trespass, conversion and similar concepts, which may raise new legal issues. Indemnification to cover potential claims or liabilities resulting from a failure may be available in certain circumstances, but not in others. We do not and are not able to maintain insurance to protect against our risks and uncertainties. Substantial claims resulting from an accident, failure, or liability arising from our activities in excess of any indemnity or insurance coverage (or for which indemnity or insurance is not available or was not obtained) could harm our financial condition, cash flows, and operating results. Any accident, contamination or spill, even if fully covered or insured, could negatively affect our reputation among our customers and the public, and make it more difficult for us to compete effectively.
Our growth strategy may not be successful.
We intend to expand our operations and marketing base, in large part, by acquiring additional leases. Our operations are subject to all the risks inherent in the growth of a new business. The timing and related expenses of expansion may cause our revenues, if any, to fluctuate. The likelihood of our success must be considered in the light of the problems, expenses, difficulties, complications, and delays frequently encountered in connection with the growth of a business and the reliance on our ability to establish ongoing relationships with purchasers of oil and gas, market acceptance, unfamiliarity with operating and marketing methods, and competition. We may not be successful in our proposed expanded business activities.
We may be unable to generate sufficient revenue from the commercialization of our leases to achieve and sustain profitability.
At present, we rely solely on the Logan assets to generate revenue and we expect to substantially generate all our revenue in the foreseeable future from sales from these assets. In order to successfully operate, we will need to continue to expand our marketing efforts to develop new relationships and expand existing relationships with customers, to achieve and maintain compliance with all applicable regulatory requirements. If we fail, we may never receive a return on the investments we have made, as well as further investments we intend to make, which may cause us to fail to generate revenue and gain economies of scale from such investments.
Cybersecurity risks could adversely affect our business and disrupt our operations.
The threats to network and data security are increasingly diverse and sophisticated. Despite our efforts and processes to prevent breaches, our devices, as well as our servers, computer systems, and those of third parties that we use in our operations are vulnerable to cybersecurity risks, including cyber-attacks such as viruses and worms, phishing attacks, denial-of-service attacks, physical or electronic break-ins, employee theft or misuse, and similar disruptions from unauthorized tampering with our servers and computer systems or those of third parties that we use in our operations, which could lead to interruptions, delays, loss of critical data, unauthorized access to user data, and loss of consumer confidence. In addition, we may be the target of email scams that attempt to acquire personal information or company assets. Despite our efforts to create security barriers to such threats, we may not be able to entirely mitigate these risks. Any cyber-attack that attempts to obtain our or our users’ data and assets, disrupt our service, or otherwise access our systems, or those of third parties we use, if successful, could adversely affect our business, operating results, and financial condition, be expensive to remedy, and damage our reputation. In addition, any such breaches may result in negative publicity, adversely affect our brand, decrease demand for our products and services, and adversely affect our operating results and financial condition.
There are economic and general risks relating to our business.
The success of our activities is subject to risks inherent in business generally, including demand for products and services, general economic conditions, changes in taxes and tax laws, and changes in governmental regulations and policies.
Our operations are vulnerable to interruption or loss due to natural or other disasters, power loss, strikes, and other events beyond our control.
A major earthquake, fire, or other disaster (such as a major flood, tsunami, volcanic eruption, or terrorist attack) affecting our facilities, or those of our suppliers, contractors or customers, could significantly disrupt our operations, and delay or prevent shipment or sales during the time required to repair, rebuild, or replace damaged facilities; these delays could be lengthy and costly. If any of the facilities are negatively impacted by a disaster, operations and deliveries could be delayed. Even if we are able to quickly respond to a disaster, the ongoing effects of the disaster could create some uncertainty in the operations of our business. In addition, our facilities may be subject to a shortage of available electrical power and other energy supplies. Any shortages may increase our costs for power and energy supplies or could result in blackouts, which could disrupt the operations of our affected facilities and harm our business. In addition, concerns about terrorism, the effects of a terrorist attack, political turmoil, or an outbreak of epidemic diseases could have a negative effect on our operations, those of our suppliers and customers, including the ability to travel.
We are an “emerging growth company” and as such, our disclosures may be less extensive than the information you receive from other public companies that are not emerging growth companies.
We qualify as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act of 2012, or the JOBS Act. For so long as we remain an emerging growth company, we are permitted and intend to rely on exemptions from specified disclosure requirements that are applicable to other public companies that are not emerging growth companies. These exemptions include:
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being permitted to provide only two years of audited financial statements, in addition to any required unaudited interim financial statements, with correspondingly reduced “Management’s Discussion and Analysis of Financial Condition and Results of Operations” disclosure;
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not being required to comply with the auditor attestation requirements in the assessment of our internal control over financial reporting;
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reduced disclosure obligations regarding executive compensation; and
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exemption from the requirements of holding a nonbinding advisory vote on executive compensation and shareholder approval of any golden parachute payments not previously approved.
We have elected to use the extended transition period for complying with Section 107(b) of the JOBS Act, which allows us to delay the adoption of new or revised accounting standards that have different effective dates for public and private corporations until those standards also apply to private corporations. Further, as the result of our election, our financial statements may not be as comparable to companies that comply with public company effective dates.
Risk Factors Relating to the Oil and Natural Gas Industry
Oil and natural gas prices fluctuate widely, and lower prices for an extended period of time are likely to have a material adverse impact on our business.
Our revenues, profitability, cash flows and future growth, as well as liquidity and ability to access additional sources of capital, depend substantially on prevailing prices for oil and natural gas and the relative mix of these commodities in our reserves and production. Sustained lower prices will reduce the amount of oil and natural gas that we can economically produce and may result in impairments of our proved reserves or reduction of our proved undeveloped reserves. Oil and natural gas prices also affect the amount of cash flow available for capital expenditures and our ability to borrow and raise additional capital.
The market prices for oil and natural gas depend on factors beyond our control. Some, but not all, of the factors that can cause fluctuations include:
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the domestic and foreign supply of, and demand for, oil and natural gas;
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domestic and world-wide economic conditions;
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the level and effect of trading in commodity futures markets, including commodity price speculators and others;
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military, economic and political conditions in oil and gas producing regions;
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the actions taken by OPEC and other foreign oil and gas producing nations, including the ability of members of OPEC to agree to and maintain production controls;
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the impact of the U.S. dollar exchange rates on oil and natural gas prices;
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the price and availability of, and demand for, alternative fuels;
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weather conditions and climate change;
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world-wide conservation measures;
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technological advances affecting energy consumption and production;
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changes in the price of oilfield services and technologies;
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the price and level of foreign imports;
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expansion of U.S. exports of oil, natural gas and/or NGLs;
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the availability, proximity and capacity of transportation, processing, storage and refining facilities;
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the costs of exploring for, developing, producing, transporting and marketing oil and natural gas; and
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the nature and extent of domestic and foreign governmental regulations and taxation, including environmental regulations.
Sustained material declines in oil or natural gas prices may have the following effects on our business:
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limit our access to sources of capital, such as equity and long-term debt;
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cause us to delay or postpone capital projects;
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cause us to lose certain leases because we fail to meet obligations of the leases prior to expiration;
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reduce reserve estimates and the amount of products we can economically produce;
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downgrade or other negative rating action with respect to our credit rating;
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reduce revenues, income and cash flows available for capital expenditures, repayment of indebtedness and other corporate purposes; or
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reduce the carrying value of our assets in our balance sheet through ceiling test impairments.
Legislation or regulatory initiatives intended to address seismic activity in Oklahoma and elsewhere could increase our costs of compliance or lead to operational delays, which could have a material adverse effect on our business, results of operations, cash flows or financial condition.
Water sourcing, use and disposal are common practices in oil and gas operations. We dispose of large volumes of water produced alongside oil and natural gas “produced water” or "saltwater" in connection with our drilling and production operations, pursuant to permits issued to us by governmental authorities overseeing such disposal activities. While these permits are issued under existing laws and regulations, these legal requirements are subject to change, which could result in the imposition of more stringent operating constraints or new monitoring and reporting requirements, owing to, among other things, concerns of the public or governmental authorities regarding such gathering or disposal activities.
There exists a growing concern that the injection of produced water into belowground disposal wells triggers seismic events in certain areas, including Oklahoma, where we operate. In response to recent seismic events near underground water disposal wells, federal and some state agencies are investigating whether certain high volume disposal wells have caused or contributed to increased seismic activity, and some states have restricted, suspended or shut down the use of such disposal wells that are located in close proximity to areas of increased seismic activity.
The Oklahoma Corporation Commission (OCC) evaluates existing disposal wells to assess their continued operation, or operation with restrictions, based on location relative to faults, seismicity and other factors, with well operators in certain geographic locations required to make frequent, or even daily, volume and pressure reports. In addition, the OCC has adopted rules requiring operators of certain saltwater disposal wells in the state to, among other things, conduct additional mechanical integrity testing or make certain demonstrations of such wells’ depth that, depending on the depth, could require the plugging back of such wells to shallower depths and/or the reduction of volumes disposed in such wells. As a result of these measures, the OCC from time to time has developed and implemented plans calling for wells within Areas of Interest where seismic incidents have occurred to restrict or suspend disposal well operations in an attempt to mitigate the occurrence of such incidents. For example, OCC has established a 15 thousand square mile Area of Interest in the Arbuckle formation located primarily north and east of the Anadarko Basin in the Mississippi Lime play. Since 2013, OCC has prohibited disposal into the basement rock and ordered reduction of disposal volumes into the overlying Arbuckle formation and directed the shut-in of a number of Arbuckle disposal wells in response to seismic activity. In addition, in January 2016, the Governor of Oklahoma announced a grant of $1.4 million in emergency funds to support earthquake research to be directed by the OCC and the Oklahoma Geological Survey (OGS). During September and November 2016, in response to the occurrence of earthquakes in Cushing and Pawnee, Oklahoma, located in the northeast area of the Anadarko Basin, the OCC developed action plans in conjunction with the OGS and the EPA. The plans require reductions in disposal volumes in three concentric zones from the center of the earthquake activity in both Cushing and Pawnee, Oklahoma, with the greatest reductions in the zone located closest to the center of the largest quakes. These actions are in addition to any previous orders to shut in wells or reduce disposal volumes. Prior measures had already reduced disposal volumes in the areas of concern by up to 50 percent for some disposal wells. In the Pawnee area, the action plan covers a total of 38 Arbuckle disposal wells under OCC jurisdiction and 26 Arbuckle disposal wells under EPA jurisdiction and in the Cushing area the plan covers a total of 58 Arbuckle disposal wells. Local residents have also recently filed lawsuits against saltwater disposal well operators in these areas for damages resulting from the increased seismic activity.
Additionally, in recent years there has been increased public concern regarding an alleged potential for hydraulic fracturing to induce seismic events. In December 2016, the OCC announced the development of seismicity guidelines focused on operators in SCOOP and STACK to directly address concerns related to induced seismicity and hydraulic fracturing. The OCC has established three action levels to be followed if events are detected at a M2.5 or above and within 1.24 miles (2 km) of hydraulic fracturing activities.
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Magnitude 2.5 - OCC contacts the operator, discusses mitigation plan, operations may continue
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Magnitude 3.0 - required minimum six-hour pause, technical call with OCC regarding mitigations, operations continue with an approved and revised completion plan
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Magnitude 3.5 - required operations suspension, technical meeting with OCC and decision made to resume or halt operations based on approved and revised completion plan
On March 1, 2017, the OCC also issued a statement saying that further actions to reduce the earthquake rate in Oklahoma could be expected.
Restrictions on disposal well volumes or a lack of sufficient disposal wells, the filing of lawsuits, or curtailment or restrictions on oil and gas activity generally in response to concerns related to induced seismicity, could cause us to delay, curb or discontinue our exploration and development plans. Increased costs associated with restrictions on hydraulic fracturing or the transportation and disposal of produced water, including the cost of complying with regulations concerning produced water disposal or hydraulic fracturing, such as mandated produced water recycling in some portion or all of our operations or prohibitions on performing hydraulic fracturing in certain areas, may reduce our profitability.
These developments may result in additional levels of regulation, or increased complexity and costs with respect to existing regulations, that could lead to operational delays or increased operating and compliance costs, which could have a material adverse effect on our business, results of operations, cash flows or financial condition.
We have substantial capital requirements to fund our business plans that could be greater than cash flows from operations. Limited liquidity would likely negatively impact our ability to execute our business plan.
Our 2022 capital investment levels may exceed our projected cash flows from operations. As a result, we may use available cash or borrow funds under a credit facility, due in part to our decision to continue our drilling program in order to avoid future lease renewals to retain certain acreage. If necessary, we may continue to use cash on hand, sell non- strategic assets or potentially access public debt and/or equity markets to fund any shortfall. Our ability to generate operating cash flows is subject to many risks and variables, such as the level of production from existing wells; prices of oil and natural gas; production costs; availability of economical gathering, processing, storage and transportation in our operating areas; our success in developing and producing new reserves and the other risk factors discussed in this Prospectus. Actual levels of capital expenditures may vary significantly due to many factors, including drilling results, commodity prices, industry conditions, the prices and availability of goods and services, unbudgeted acquisitions and the promulgation of new regulatory requirements. Alternatively, we may have to reduce capital expenditures, and our ability to execute our business plans could be adversely affected, if:
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we generate less operational cash flow than we anticipate;
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we are unable to sell non-strategic assets at acceptable prices;
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our customers or working interest owner’s default on their obligations to us;
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one or more lenders fails to honor its contractual obligation to lend to us;
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investors limit funding or refrain from funding oil and gas companies; or
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we are unable to access the capital markets at a time when we would like, or need, to raise capital.
We will be subject to risks in connection with acquisitions, and the integration of significant acquisitions may be difficult.
Our business plan contemplates significant acquisitions of reserves, properties, prospects, and leaseholds and other strategic transactions that appear to fit within our overall business strategy, which may include the acquisition of asset packages of producing properties or existing companies or businesses operating in our industry. The successful acquisition of producing properties requires an assessment of several factors, including:
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recoverable reserves;
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future oil and natural gas prices and their appropriate differentials;
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development and operating costs; and
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potential environmental and other liabilities.
The accuracy of these assessments is inherently uncertain. In connection with these assessments, we perform a review of the subject properties that we believe to be generally consistent with industry practices. Our review will not reveal all existing or potential problems, nor will it permit us to become sufficiently familiar with the properties to fully assess their deficiencies and potential recoverable reserves. Inspections may not always be performed on every well, and environmental problems are not necessarily observable even when an inspection is undertaken. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or part of the problems. We are not entitled to contractual indemnification for environmental liabilities and acquired properties on an "as is" basis. Significant acquisitions of existing companies or businesses and other strategic transactions may involve additional risks, including:
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diversion of our management's attention to evaluating, negotiating, and integrating significant acquisitions and strategic transactions;
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the challenge and cost of integrating acquired operations, information management, and other technology systems, and business cultures with our own while carrying on our ongoing business;
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difficulty associated with coordinating geographically separate organizations; and
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the challenge of attracting and retaining personnel associated with acquired operations.
The process of integrating operations could cause an interruption of, or loss of momentum in, the activities of our business. Members of our senior management may be required to devote considerable amounts of time to this integration process, which will decrease the time they will have to manage our business. If our senior management is not able to manage the integration process effectively, or if any significant business activities are interrupted as a result of the integration process, our business could be materially and adversely affected.
Actual quantities of oil and natural gas reserves and future cash flows from those reserves will most likely vary from our estimates.
Estimating quantities of oil and natural gas reserves is complex and inexact. The process relies on interpretations of geologic, geophysical, engineering and production data. The extent, quality and reliability of these data can vary. The process also requires a number of economic assumptions, such as oil and natural gas prices, the relative mix of oil and natural gas that will be ultimately produced, drilling and operating expenses, capital expenditures, the effect of government regulation, taxes and availability of funds. The accuracy of a reserve estimate is a function of:
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the quality and quantity of available data;
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the interpretation of that data;
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the accuracy of various mandated economic assumptions and our expected development plan; and
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the judgment of the persons preparing the estimate.
Actual quantities of oil and natural gas reserves, future oil and natural gas production and the relative mix of oil and natural gas that will be ultimately produced, oil and natural gas prices, revenues, taxes, capital expenditures, effects of regulations, funding availability and drilling and operating expenses will most likely vary from our estimates. In addition, the methodologies and evaluation techniques that we use, which include the use of multiple technologies, data sources and interpretation methods, may be different than those used by our competitors. Further, reserve estimates are subject to the evaluator’s criteria and judgment and show important variability, particularly in the early stages of development. Any significant variance could be systematic and undetected for an extended period of time, which would materially affect the quantities and net present value of our reserves. In addition, we may adjust estimates of reserves to reflect production history, results of exploration and development activities, prevailing oil and natural gas prices and other factors, many of which are beyond our control. Our reserves also may be susceptible to drainage by operators on adjacent properties.
Actual future prices and costs may be materially higher or lower than the prices and costs we used as of the date of an estimate. In addition, actual production rates for future periods may vary significantly from the rates assumed in the calculation. You should not assume that the present value of future net cash flows is the current market value of our proved reserves.
Estimates of oil and natural gas reserves are inherently imprecise. Any material inaccuracies in these reserve estimates or underlying assumptions will affect materially the quantities and present value of our reserves.
Estimates of proved oil and natural gas reserves and the future net cash flows attributable to those reserves are prepared by independent petroleum engineers and geologists. There are numerous uncertainties inherent in estimating quantities of proved oil and natural gas reserves and cash flows attributable to such reserves, including factors beyond our control and that of our engineers. Reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact manner. Different reserve engineers may make different estimates of reserves and cash flows based on the same available data. The accuracy of an estimate of quantities of reserves, or of cash flows attributable to such reserves, is a function of the available data, assumptions regarding future oil and natural gas prices and expenditures for future development drilling and exploration activities, and of engineering and geological interpretation and judgment. Additionally, reserves and future cash flows may be subject to material downward or upward revisions, based upon production history, development drilling and exploration activities and prices of oil and natural gas. Actual future production, revenue, taxes, development drilling expenditures, operating expenses, underlying information, quantities of recoverable reserves and the value of cash flows from such reserves may vary significantly from the assumptions and underlying information set forth herein
To maintain and grow our production and cash flows, we must continue to develop existing reserves and locate or acquire new reserves.
Through our drilling programs and the acquisition of properties, we strive to maintain and grow our production and cash flows. However, as we produce from our properties, our reserves decline. Unless we successfully replace the reserves that we produce, the decline in our reserves will eventually result in a decrease in oil and natural gas production and lower revenue, income and cash flows from operations. Future oil and natural gas production is, therefore, highly dependent on our success in efficiently finding, developing or acquiring additional reserves that are economically recoverable. We may be unable to find, develop or acquire additional reserves or production at an acceptable cost, if at all. In addition, these activities require substantial capital expenditures.
Lower oil and gas prices and other factors have resulted in ceiling test impairments in the past and may result in future ceiling test or other impairments.
We use the full cost method of accounting for our oil and gas producing activities. Under this method, all costs incurred in the acquisition, exploration and development of oil and gas properties are capitalized into cost centers that are established on a country-by-country basis. The net capitalized costs of our oil and gas properties may not exceed the present value of estimated future net revenues from proved reserves, discounted at 10%, plus the lower of cost or fair value of unproved properties. If net capitalized costs of our oil and gas properties exceed the cost center ceiling, we are subject to a ceiling test impairment to the extent of such excess. If required, a ceiling test impairment reduces income and stockholders’ equity in the period of occurrence.
The risk that we will be required to further impair the carrying value of our oil and gas properties increases when oil and natural gas prices are low or volatile for a prolonged period of time. In addition, impairments may occur if we experience substantial downward adjustments to our estimated proved reserves or our unproved property values, or if estimated future development costs increase.
Drilling is a costly and high-risk activity.
In addition to the numerous operating risks described in more detail below, the drilling of wells involves the risk that no commercially productive oil or gas reservoirs will be encountered. The seismic data and other technologies we use do not allow us to know conclusively prior to drilling a well that oil and natural gas are present or may be produced economically. In addition, we are often uncertain of the future cost or timing of drilling, completing and producing wells. Furthermore, our drilling operations may be curtailed, delayed or canceled as a result of a variety of factors, including:
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increases in the costs of, or shortages or delays in the availability of, drilling rigs, equipment and materials;
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decreases in oil and natural gas prices;
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limited availability to us of financing on acceptable terms;
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adverse weather conditions and changes in weather patterns;
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unexpected operational events and drilling conditions;
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abnormal pressure or irregularities in geologic formations;
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surface access restrictions;
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access to, and costs for, water needed in our waterflood project in the Greater Monument Butte Unit (GMBU);
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the presence of underground sources of drinking water, previously unknown water or other extraction wells or endangered or threatened species;
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embedded oilfield drilling and service tools;
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equipment failures or accidents;
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lack of necessary services or qualified personnel;
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availability and timely issuance of required governmental permits and licenses;
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loss of title and other title-related issues;
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availability, costs and terms of contractual arrangements, such as leases, pipelines and related facilities to gather, process and compress, transport and market oil and natural gas; and
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compliance with, or changes in, environmental, tax and other laws and regulations.
As we implement pad development and increase the lateral length and size of hydraulic fracturing stimulations of our horizontal wells, the costs and other impacts associated with any curtailment, delay or cancellation may increase due to the concentration of capital expenditures prior to bringing production online. Future drilling activities may not be successful, and if unsuccessful, this could have an adverse effect on our future results of operations, cash flows and financial condition.
The oil and gas business involves many operating risks that can cause substantial losses.
Our oil and gas exploration and production activities are subject to all of the operating risks associated with drilling for and producing oil and gas, including the risk of:
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fires and explosions;
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blow-outs and cratering;
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uncontrollable or unknown flows of oil, gas or well fluids;
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pipe or cement failures and casing collapses;
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pipeline or other facility ruptures and spills;
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equipment malfunctions or operator error;
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discharges of toxic gases;
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induced seismic events;
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environmental costs and liabilities due to our use, generation, handling and disposal of materials, including wastes, hydrocarbons and other chemicals; and
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environmental damages caused by previous owners of property we purchase and lease.
Some of these risks or hazards could materially and adversely affect our results of operations and cash flows by reducing or shutting in production from wells, loss of equipment or otherwise negatively impacting the projected economic performance of our prospects. If any of these risks occur, we could incur substantial losses as a result of:
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injury or loss of life;
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severe damage or destruction of property, natural resources and equipment;
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pollution and other environmental damage;
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investigatory and clean-up responsibilities;
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regulatory investigation and penalties or lawsuits;
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limitation on or suspension of our operations; and
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repairs and remediation costs to resume operations.
The magnitude of these risks may increase due to the increase in lateral length, larger multi-stage hydraulic fracturing stimulations for our horizontal wells and the implementation of pad development because of the larger amounts of liquids, chemicals and proppants involved.
In addition, our hydraulic fracturing operations require significant quantities of water. Regions in which we operate have recently experienced drought conditions. Any diminished access to water for use in hydraulic fracturing, whether due to usage restrictions or drought or other weather conditions, could curtail our operations or otherwise result in delays in operations or increased costs related to finding alternative water sources.
Failure or loss of equipment, as the result of equipment malfunctions, cyber-attacks or natural disasters, could result in property damages, personal injury, environmental pollution and other damages for which we could be liable. Catastrophic occurrences giving rise to litigation, such as a well blowout, explosion or fire at a location where our equipment and services are used, may result in substantial claims for damages. Ineffective containment of a drilling well blowout or pipeline rupture could result in extensive environmental pollution and substantial remediation expenses, as well as governmental fines and penalties. If our production is interrupted significantly, our efforts at containment are ineffective or litigation arises as the result of a catastrophic occurrence, our cash flows, and in turn, our results of operations, could be materially and adversely affected.
In connection with our operations, we generally require our contractors, which include the contractor, its parent, subsidiaries and affiliate companies, its subcontractors, their agents, employees, directors and officers, to agree to indemnify us for injuries and deaths of their employees, contractors, subcontractors, agents and directors, and any property damage suffered by the contractors. There may be times, however, that we are required to indemnify our contractors for injuries and other losses resulting from the events described above, which indemnification claims could result in substantial losses to us. Contractor or customer contracts may also contain inadequate indemnity clauses, exposing us to unexpected losses or an unfavorable litigation position, and could, in turn, have a material adverse effect on our business, financial condition, results of operations and cash flows.
While we may maintain insurance against some potential losses or liabilities arising from our operations, our insurance does not protect us against all operational risks. The occurrence of any of the foregoing events and any costs or liabilities incurred as a result of such events, if uninsured or in excess of our insurance coverage or not indemnified, could reduce revenue, income and cash flows and the funds available to us for our exploration, development and production activities and could, in turn, have a material adverse effect on our business, financial condition, results of operations and cash flows.
Our identified drilling locations are scheduled out over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling.
Our management has specifically identified and scheduled drilling locations as an estimation of our future multi-year drilling activities on our existing acreage. These drilling locations represent a significant part of our growth strategy. Our ability to drill and develop these locations is subject to a number of uncertainties, including oil and natural gas prices, the availability of capital, costs, drilling results, regulatory approvals, available transportation capacity, and other factors. If future drilling results in these projects do not establish sufficient reserves to achieve an economic return, we may curtail drilling in these projects.
Because of these uncertainties, we do not know if the numerous potential drilling locations we have identified will ever be drilled or if we will be able to produce oil, natural gas or NGLs from these or any other potential drilling locations. In addition, unless production is established within the spacing units covering the undeveloped acres on which some of the locations are identified, the leases for such acreage will expire. As such, our actual drilling activities may materially differ from those presently identified. Low oil prices, reduced capital spending and numerous other factors, many of which are beyond our control, could result in our failure to establish production on undeveloped acreage, and, if we are not able to renew leases before they expire, any proved undeveloped reserves associated with such leases will be removed from our proved reserves. Our actual drilling activities may materially differ from those presently identified, which could adversely affect our business, results of operations, financial condition and cash flows.
Our proved undeveloped reserves may not be ultimately developed or produced. The development of our proved undeveloped reserves may take longer and may require higher levels of capital expenditures than we currently anticipate.
At December 31, 2022, approximately 87.9% of our total estimated plus probable proved reserves (by volume) were undeveloped and may not be ultimately developed or produced. Recovery of undeveloped reserves requires significant capital expenditures and successful drilling operations. Our reserve estimates assume we can and will make these expenditures and conduct these operations successfully. These assumptions, however, may not prove to be accurate. We cannot be certain that the estimated costs of the development of these reserves are accurate, that development will occur as scheduled, or that the results of such development will be as estimated. If we choose not to spend the capital to develop these reserves, or if we are not otherwise able to successfully develop these reserves, we will be required to remove the associated volumes from our reported proved reserves. In addition, under the SEC’s reserve rules, because proved undeveloped reserves may be booked only if they relate to wells scheduled to be drilled within five years of the date of booking, we may be required to remove any proved undeveloped reserves that are not developed within this five-year time frame. A removal of such reserves could adversely affect our business and financial condition.
The potential adoption of federal, state, tribal and local legislative and regulatory initiatives related to hydraulic fracturing could result in operating restrictions or delays in the completion of oil and gas wells.
Hydraulic fracturing is an essential and common practice in the oil and gas industry used to stimulate production of natural gas and/or oil from dense subsurface rock formations. We routinely apply hydraulic fracturing techniques on almost all of our U.S. onshore oil and natural gas properties. Hydraulic fracturing involves using water, sand or other proppant materials, and certain chemicals to fracture the hydrocarbon-bearing rock formation to allow flow of hydrocarbons into the wellbore.
As explained in more detail below, the hydraulic fracturing process is typically regulated by state oil and natural gas agencies, although the EPA, the BLM and other federal regulatory agencies have taken steps to review or impose federal regulatory requirements. Certain states in which we operate, have adopted, and other states are considering adopting, regulations that could impose more stringent permitting, public disclosure and well construction requirements on hydraulic fracturing operations or otherwise seek to ban fracturing activities altogether. Certain municipalities have already banned hydraulic fracturing, and courts have upheld those moratoria in some instances. In the past several years, dozens of states have approved or considered additional legislative mandates or administrative rules on hydraulic fracturing.
At the federal level, the EPA has taken numerous actions. The adoption of new federal rules or regulations relating to hydraulic fracturing could require us to obtain additional permits or approvals or to install expensive pollution control equipment for our operations, which in turn could lead to increased operating costs, delays and curtailment in the pursuit of exploration, development or production activities, which in turn could materially adversely affect our operations.
In December 2016, the EPA released its final report on the potential impacts of hydraulic fracturing on drinking water resources. The final report concluded that "water cycle" activities associated with hydraulic fracturing may impact drinking water resources "under some circumstances," noting that the following hydraulic fracturing water cycle activities and local- or regional-scale factors are more likely than others to result in more frequent or more severe impacts: water withdrawals for fracturing in times or areas of low water availability; surface spills during the management of fracturing fluids, chemicals or produced water; injection of fracturing fluids into wells with inadequate mechanical integrity; injection of fracturing fluids directly into groundwater resources; discharge of inadequately treated fracturing wastewater to surface waters; and disposal or storage of fracturing wastewater in unlined pits. Since the report did not find a direct link between hydraulic fracturing itself and contamination of groundwater resources, we do not believe that this multi-year study report provides any basis for further regulation of hydraulic fracturing at the federal level.
Based on the foregoing, increased regulation and attention given to the hydraulic fracturing process from federal agencies, various states and local governments could lead to greater opposition, including litigation, to oil and gas production activities using hydraulic fracturing techniques. Additional legislation or regulation could also lead to operational delays or increased operating costs in the production of oil and natural gas, including from the developing shale plays, or could make it more difficult to perform hydraulic fracturing. The adoption of any federal, state or local laws or the implementation of regulations regarding hydraulic fracturing could potentially cause a decrease in the completion of new oil and gas wells and increased compliance costs and time, which could adversely affect our business, financial condition, results of operations and cash flows.
Our ability to produce oil and natural gas economically and in commercial quantities could be impaired if we are unable to acquire adequate supplies of water for our drilling operations or are unable to dispose of or recycle the water we use economically and in an environmentally safe manner.
Development activities require the use of water. For example, the hydraulic fracturing process that we employ to produce commercial quantities of natural gas and oil from many reservoirs requires the use and disposal of significant quantities of water in addition to the water we use to develop our waterflood in the GMBU. In certain regions, there may be insufficient local capacity to provide a source of water for drilling activities. In these cases, water must be obtained from other sources and transported to the drilling site, adding to the operating cost. Our inability to secure sufficient amounts of water, or to dispose of or recycle the water used in our operations, could adversely impact our operations in certain areas. Moreover, the imposition of new environmental initiatives and regulations could include restrictions on our ability to conduct certain operations, such as hydraulic fracturing or disposal of waste, including, but not limited to, produced water, drilling fluids and other materials associated with the exploration, development or production of NGLs, natural gas and oil. In recent history, public concern surrounding increased seismicity has heightened focus on our industry’s use of water in operations, which may cause increased costs, regulations or environmental initiatives impacting our use or disposal of water. See "Legislation or regulatory initiatives intended to address seismic activity in Oklahoma and elsewhere could increase our costs of compliance or lead to operational delays, which could have a material adverse effect on our business, results of operations, cash flows or financial condition" for more information on action taken by certain states to regulate hydraulic fracturing activity with respect to induced seismicity. Furthermore, future environmental regulations governing the withdrawal, storage and use of surface water or groundwater necessary for hydraulic fracturing of wells could cause delays, interruptions or termination of operations, which may result in increased operating costs and have an effect on our business, results of operations, cash flows or financial condition.
The marketability of our production is dependent upon transportation and processing facilities over which we may have no control.
The marketability of our production depends in part upon the availability, proximity and capacity of pipelines, natural gas gathering systems and processing facilities. We deliver oil and natural gas through gathering systems and pipelines that we do not own. The lack of available capacity on these systems and facilities could reduce the price offered for our production or result in the shut-in of producing wells or the delay or discontinuance of development plans for properties. Although we have some contractual control over the transportation of our production through some firm transportation arrangements, third-party systems and facilities may be temporarily unavailable due to market conditions or mechanical or other reasons, or may not be available to us in the future at a price that is acceptable to us. New regulations on the transportation of oil by rail, like those finalized by the U.S. Department of Transportation (DOT) in 2015, may increase our transportation costs. In addition, federal and state regulation of natural gas and oil production, processing and transportation, tax and energy policies, changes in supply and demand, pipeline pressures, damage to or destruction of pipelines, infrastructure or capacity constraints and general economic conditions could adversely affect our ability to produce, gather and transport natural gas. Any significant change in market factors or other conditions affecting these infrastructure systems and facilities, as well as any delays in constructing new infrastructure systems and facilities, could harm our business and, in turn, our financial condition, results of operations and cash flows.
We may be involved in legal proceedings that could result in substantial liabilities.
Like many companies in the oil and gas industry, we are from time to time involved in various legal and other proceedings, such as title, royalty or contractual disputes, regulatory compliance matters and personal injury or property damage matters, in the ordinary course of our business. Such legal proceedings are inherently uncertain and their results cannot be predicted. Regardless of the outcome, such proceedings could have an adverse impact on us because of legal costs, diversion of management and other personnel and other factors. In addition, it is possible that a resolution of one or more such proceedings could result in liability, penalties or sanctions, as well as judgments, consent decrees or orders requiring a change in our business practices, which could materially and adversely affect our business, results of operations, cash flow and financial condition. Accruals for such liability, penalties or sanctions may be insufficient. Judgments and estimates to determine accruals or range of losses related to legal and other proceedings could change from one period to the next, and such changes could be material.
We are subject to complex laws and regulatory actions that can affect the cost, manner, feasibility or timing of doing business.
Existing and potential regulatory actions could increase our costs and reduce our liquidity, delay our operations or otherwise alter the way we conduct our business. Exploration and development and the production and sale of oil and natural gas are subject to extensive federal, state, provincial, tribal, local and international regulation. We may be required to make large expenditures to comply with environmental, natural resource protection, and other governmental regulations. Matters subject to regulation include the following:
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restrictions for the protection of wildlife that regulate the time, place and manner in which we conduct operations;
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the amounts, types and manner of substances and materials that may be released into the environment;
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response to unexpected releases into the environment;
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reports and permits concerning exploration, drilling, production and other operations;
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the placement and spacing of wells;
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cement and casing strength;
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unitization and pooling of properties;
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calculating royalties on oil and gas produced under federal and state leases; and
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taxation.
Under these laws, we could be liable for personal injuries, property damage, oil spills, discharge of hazardous materials into the environment, remediation and clean-up costs, natural resource risk mitigation, damages and other environmental or habitat damages. We also could be required to install and operate expensive pollution controls, engage in environmental risk management, incur increased waste disposal costs, or limit or even cease activities on lands located within wilderness, wetlands or other environmentally or politically sensitive areas.
In addition, failure to comply with applicable laws also may result in the suspension or termination of our operations and subject us to administrative, civil and criminal penalties as well as the imposition of corrective action orders. Any such liabilities, penalties, suspensions, terminations or regulatory changes could have a material adverse effect on our business, financial condition, results of operations or cash flows.
The matters described above and other potential legislative proposals, along with any applicable legislation introduced and passed in Congress or new rules or regulations promulgated by state or the US federal government, could increase our costs, reduce our liquidity, delay our operations or otherwise alter the way we conduct our business, negatively impacting our financial condition, results of operations and cash flows.
Although it is not possible at this time to predict whether proposed legislation or regulations will be adopted as initially written, if at all, or how legislation or new regulation that may be adopted would impact our business, any such future laws and regulations could result in increased compliance costs or additional operating restrictions. Additional costs or operating restrictions associated with legislation or regulations could have a material adverse effect on our results of operations and cash flows, in addition to the demand for the oil and natural gas that we produce.
Climate change laws and regulations restricting emissions of "greenhouse gases" could result in increased operating costs and reduced demand for the oil and natural gas that we produce while potential physical effects of climate change could disrupt our production and cause us to incur significant costs in preparing for or responding to those effects.
In response to findings that emissions of carbon dioxide, methane and other greenhouse gases (GHGs) present an endangerment to public health and the environment, the EPA has adopted regulations under existing provisions of the federal Clean Air Act that, among other things address GHG emissions for certain sources.
Although it is not possible at this time to predict how legislation or new regulations that may be adopted to address GHG emissions would impact our business, any such future laws and regulations imposing reporting obligations on, or limiting emissions of GHGs from, our equipment and operations could require us to incur costs to reduce emissions of GHGs associated with our operations. Severe limitations on GHG emissions could also adversely affect demand for the oil and natural gas we produce and lower the value of our reserves, which in turn could have a material adverse effect on our business, financial condition, results of operations or cash flows. Moreover, incentives to conserve energy or use alternative energy sources as a means of addressing climate change could reduce demand for natural gas, oil and NGL. Finally, it should be noted that some scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods, droughts and other extreme climatic events; if any such effects were to occur, they could have an adverse effect on our exploration and production operations.
Certain U.S. federal income tax deductions currently available with respect to natural gas and oil exploration and development may be eliminated as a result of future legislation.
In past years, legislation has been proposed that would, if enacted into law, make significant changes to U.S. tax laws, including to certain key U.S. federal income tax provisions currently available to oil and gas companies. Such legislative changes have included, but not been limited to:
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the repeal of the percentage depletion allowance for oil and natural gas properties;
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the elimination of current deductions for intangible drilling and development costs;
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the elimination of the deduction for certain domestic production activities; and
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an extension of the amortization period for certain geological and geophysical expenditures.
Although these provisions were largely unchanged in the Tax Act, which was signed on December 22, 2017, Congress could consider, and could include, some or all of these proposals as part of future tax reform legislation, to accompany lower federal income tax rates. Moreover, other more general features of any additional tax reform legislation, including changes to cost recovery rules, may be developed that also would change the taxation of oil and gas companies. It is unclear whether these or similar changes will be enacted in future legislation and, if enacted, how soon any such changes could take effect. The passage of any legislation as a result of these proposals or any similar changes in U.S. federal income tax laws could eliminate or postpone certain tax deductions that currently are available with respect to oil and gas development or increase costs, and any such changes could have an adverse effect on the Company’s financial position, results of operations and cash flows.
Competition for, or the loss of, our senior management or experienced technical personnel may negatively impact our operations or financial results.
To a large extent, we depend on the services of our senior management and technical personnel and the loss of any key personnel could have a material adverse effect on our business, financial condition, results of operations and cash flows. Our continued drilling success and the success of other activities integral to our operations will depend, in part, on our ability to attract and retain a seasoned management team and experienced explorationists, engineers, geologists and other professionals. In the past, competition for these professionals was strong, and in a continuing price recovery environment may become strong again, which could result in future retention and attraction issues.
Competition in the oil and gas industry is intense.
We operate in a highly competitive environment for acquiring properties and marketing oil and natural gas. Our competitors include multinational oil and gas companies, major oil and gas companies, independent oil and gas companies, individual producers, financial buyers as well as participants in other industries supplying energy and fuel to consumers. During these periods, there is often a shortage of drilling rigs and other oilfield services. Many of our competitors have greater and more diverse resources than we do. In addition, high commodity prices, asset valuations and stiff competition for acquisitions have in the past, and may in the future, significantly increase the cost of available properties. We compete for the personnel and equipment required to explore, develop and operate properties. Our competitors also may have established long-term strategic positions and relationships in areas in which we may seek new entry. As a consequence, our competitors may be able to address these competitive factors more effectively than we can. If we are not successful in our competition for oil and gas reserves or in our marketing of production, our financial condition, cash flows and results of operations may be adversely affected.
Shortages of oilfield equipment, services, supplies and qualified field personnel could adversely affect our financial condition, results of operations and cash flows.
Historically, there have been shortages of drilling rigs, hydraulic fracturing stimulation equipment and crews, and other oilfield equipment as demand for that equipment has increased along with the number of wells being drilled. The demand for qualified and experienced field personnel to drill wells, conduct hydraulic fracturing stimulations and conduct field operations can fluctuate significantly, often in correlation with natural gas and oil prices, causing periodic shortages. These factors have caused significant increases in costs for equipment, services and personnel. Higher oil, natural gas, and NGL prices generally stimulate demand and result in increased prices for drilling rigs and crews, hydraulic fracturing stimulation equipment and crews and associated supplies, equipment, services and raw materials. Similarly, lower oil and natural gas prices generally result in a decline in service costs due to reduced demand for drilling and completion services.
Decreased levels of drilling activity in the oil and gas industry in recent periods have led to declining costs of some oilfield equipment, services and supplies. However, if the current oil and gas market changes, and commodity prices continue to recover, we may face shortages of field personnel, drilling rigs, hydraulic fracturing stimulation equipment and crews or other equipment or supplies, which could delay or adversely affect our exploration and development operations and have a material adverse effect on our business, financial condition, results of operations or cash flows, or restrict operations.
We may not be insured against all of the operating risks to which our business is exposed.
Our operations are subject to all of the risks normally incident to the exploration for and the production of oil and natural gas, such as well blowouts, explosions, oil spills, releases of gas or well fluids, fires, pollution and adverse weather conditions, which could result in substantial losses to us. See “The oil and gas business involves many operating risks that can cause substantial losses." Exploration and production activities are also subject to risk from political developments such as terrorist acts, piracy, civil disturbances, war, expropriation or nationalization of assets, which can cause loss of or damage to our property. We maintain insurance against many, but not all, potential losses or liabilities arising from our operations in accordance with what we believe are customary industry practices and in amounts and at costs that we believe to be prudent and commercially practicable. Our insurance will include deductibles that must be met prior to recovery, as well as sub-limits and/or self-insurance. Additionally, our insurance is subject to exclusions and limitations. Our insurance does not cover every potential risk associated with our operations, including the potential loss of significant revenues. We can provide no assurance that our insurance coverage will adequately protect us against liability from all potential consequences, damages and losses.
We currently have insurance policies that include coverage for general liability, excess liability, physical damage to our oil and gas properties, operational control of wells, oil pollution, third- party liability, workers’ compensation and employers’ liability and other coverages. Consistent with insurance coverage generally available to the industry, our insurance policies provide limited coverage for losses or liabilities relating to pollution and other environmental issues, with broader coverage for sudden and accidental occurrences. For example, we maintain operators extra expense coverage provided by third-party insurers for obligations, expenses or claims that we may incur from a sudden incident that results in negative environmental effects, including obligations, expenses or claims related to seepage and pollution, cleanup and containment, evacuation expenses and control of the well (subject to policy terms and conditions). In the specific event of a well blowout or out-of-control well resulting in negative environmental effects, such operators extra expense coverage would be our primary source of coverage, with the general liability and excess liability coverage referenced above also providing certain coverage.
In the event we make a claim under our insurance policies, we will be subject to the credit risk of the insurers. Volatility and disruption in the financial and credit markets may adversely affect the credit quality of our insurers and impact their ability to pay claims.
Further, we may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the risks presented. Some forms of insurance may become unavailable in the future or unavailable on terms that we believe are economically acceptable. No assurance can be given that we will be able to maintain insurance in the future at rates that we consider reasonable, and we may elect to maintain minimal or no insurance coverage. If we incur substantial liability from a significant event and the damages are not covered by insurance or are in excess of policy limits, then we would have lower revenues and funds available to us for our operations, that could, in turn, have a material adverse effect on our business, financial condition, results of operations and cash flows.
We may not realize an adequate return on wells that we drill.
Drilling for oil and gas involves numerous risks, including the risk that we will not encounter commercially productive oil or gas reservoirs. The wells we drill or participate in may not be productive, and we may not recover all or any portion of our investment in those wells. The seismic data and other technologies we use do not allow us to know conclusively prior to drilling a well that crude oil or natural gas is present or may be produced economically. The costs of drilling, completing, and operating wells are often uncertain, and drilling operations may be curtailed, delayed, or canceled as a result of a variety of factors including, without limitation:
●
unexpected drilling conditions;
●
pressure or irregularities in formations;
●
equipment failures or accidents;
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fires, explosions, blowouts, and surface cratering;
●
marine risks such as capsizing, collisions, or adverse weather conditions; and
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increase in the cost of, or shortages or delays in the availability of, drilling rigs and equipment.
Future drilling activities may not be successful, and, if unsuccessful, this failure could have an adverse effect on our future results of operations and financial condition. While all drilling, whether developmental or exploratory, involves these risks, exploratory drilling involves greater risks of dry holes or failure to find commercial quantities of hydrocarbons.
Oil and gas prices fluctuate due to a number of uncontrollable factors, creating a component of uncertainty in our development plans and overall operations. Declines in prices adversely affect our financial results and rate of growth in proved reserves and production.
Oil and gas markets are very volatile, and we cannot predict future oil and natural gas prices. The prices we receive for our oil and natural gas production heavily influence our revenue, profitability, access to capital and future rate of growth. The prices we receive for our production depend on numerous factors beyond our control. These factors include, but are not limited to, changes in global supply and demand for oil and gas, the actions of the Organization of Petroleum Exporting Countries, the level of global oil and gas exploration and production activity, weather conditions, technological advances affecting energy consumption, domestic and foreign governmental regulations and tax policies, proximity and capacity of oil and gas pipelines and other transportation facilities.
Discoveries or acquisitions of additional reserves are needed to avoid a material decline in reserves and production.
The production rate from oil and gas properties generally declines as reserves are depleted, while related per-unit production costs generally increase as a result of decreasing reservoir pressures and other factors. Therefore, unless we add reserves through exploration and development activities or, through engineering studies, identify additional behind-pipe zones, secondary recovery reserves, or tertiary recovery reserves, or acquire additional properties containing proved reserves, our estimated proved reserves will decline materially as reserves are produced. Future oil and gas production is, therefore, highly dependent upon our level of success in acquiring or finding additional reserves on an economic basis. Furthermore, if oil or gas prices increase, our cost for additional reserves could also increase.
Our business involves many operating risks that may result in substantial losses for which insurance may be unavailable or inadequate.
Our operations will be subject to hazards and risks inherent in drilling for oil and gas, such as fires, natural disasters, explosions, formations with abnormal pressures, casing collapses, uncontrollable flows of underground gas, blowouts, surface cratering, pipeline ruptures or cement failures, and environmental hazards such as natural gas leaks, oil spills and discharges of toxic gases. Any of these risks can cause substantial losses resulting from injury or loss of life, damage to or destruction of property, natural resources and equipment, pollution and other environmental damages, regulatory investigations and penalties, suspension of our operations and repair and remediation costs. In addition, our liability for environmental hazards may include conditions created by the previous owners of properties that we purchase or lease. We expect to maintain insurance coverage against some, but not all, potential losses. Losses could occur for uninsurable or uninsured risks, or in amounts in excess of existing insurance coverage. The occurrence of an event that is not fully covered by insurance could harm our financial condition and results of operation.
Our industry is subject to extensive environmental regulation that may limit our operations and negatively impact our production. As a result of increased enforcement of existing regulations and potential new regulations following the Gulf of Mexico oil spill, the costs for complying with government regulation could increase.
Extensive federal, state, and local environmental laws and regulations in the United States affect all of our operations. Environmental laws to which we are subject in the U.S. include, but are not limited to, the Clean Air Act and comparable state laws that impose obligations related to air emissions, the Resource Conservation and Recovery Act of 1976 ("RCRA"), and comparable state laws that impose requirements for the handling, storage, treatment or disposal of solid and hazardous waste from our facilities, the Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA") and comparable state laws that regulate the cleanup of hazardous substances that may have been released at properties currently or previously owned or operated by us or at locations to which our hazardous substances have been transported for disposal, and the Clean Water Act, and comparable state laws that regulate discharges of wastewater from our facilities to state and federal waters. Failure to comply with these laws and regulations or newly adopted laws or regulations may trigger a variety of administrative, civil and criminal enforcement measures, including the assessment of monetary penalties, the imposition of remedial requirements, and the issuance of orders enjoining future operations or imposing additional compliance requirements on such operations. Certain environmental laws, including CERCLA and analogous state laws, impose strict, joint and several liability for costs required to clean up and restore sites where hazardous substances or hydrocarbons have been disposed or otherwise released. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances, hydrocarbons or other waste products into the environment. Environmental legislation may require that we do the following:
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acquire permits before commencing drilling;
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restrict spills, releases or emissions of various substances produced in association with our operations;
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limit or prohibit drilling activities on protected areas such as wetlands or wilderness areas;
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take reclamation measures to prevent pollution from former operations;
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take remedial measures to mitigate pollution from former operations, such as plugging abandoned wells and remedying contaminated soil and groundwater; and
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take remedial measures with respect to property designated as a contaminated site.
There is inherent risk of incurring environmental costs and liabilities in connection with our operations due to our handling of natural gas and other petroleum products, air emissions and water discharges related to our operations, and historical industry operations and waste disposal practices. The costs of any of these liabilities are presently unknown but could be significant. We may not be able to recover all or any of these costs from insurance. In addition, we are unable to predict what impact the Gulf oil spill will have on independent oil and gas companies such as our company.
The effects of future environmental legislation on our business are unknown but could be substantial.
Environmental legislation is evolving in a manner expected to result in stricter standards and enforcement, larger fines and liability and potentially increased capital expenditures and operating costs. Changes in, or enforcement of, environmental laws may result in a curtailment of our production activities, or a material increase in the costs of production, development drilling or exploration, any of which could have a material adverse effect on our financial condition and results of operations or prospects. In addition, many countries, as well as several states in the United States have agreed to regulate emissions of "greenhouse gases." Methane, a primary component of natural gas, and carbon dioxide, a byproduct of burning natural gas, are greenhouse gases. Regulation of greenhouse gases could adversely impact some of our operations and demand for products in the future.
Should we fail to comply with all applicable FERC administered statutes, rules, regulations and orders, we could be subject to substantial penalties and fines.
Under the Energy Policy Act of 2005, the Federal Energy Regulatory Commission, or FERC, has authority to impose penalties for violations of the Natural Gas Act, up to $1 million per day for each violation and disgorgement of profits associated with any violation. FERC has recently proposed and adopted regulations that may subject our facilities to reporting and posting requirements. Additional rules and legislation pertaining to these and other matters may be considered or adopted by FERC from time to time. Failure to comply with FERC regulations could subject us to civil penalties.
Proposed federal, state, or local regulation regarding hydraulic fracturing could increase our operating and capital costs.
Several proposals are before the U.S. Congress that, if implemented, would either prohibit or restrict the practice of hydraulic fracturing or subject the process to regulation under the Safe Drinking Water Act. Several states are considering legislation to regulate hydraulic fracturing practices that could impose more stringent permitting, transparency, and well construction requirements on hydraulic fracturing operations or otherwise seek to ban fracturing activities altogether. In addition, some municipalities have significantly limited or prohibited drilling activities and/or hydraulic fracturing, or are considering doing so. We routinely use fracturing techniques in the U.S. to expand the available space for natural gas and oil to migrate toward the wellbore. It is typically done at substantial depths in very tight formations.
Although it is not possible at this time to predict the final outcome of the legislation regarding hydraulic fracturing, any new federal, state, or local restrictions on hydraulic fracturing that may be imposed in areas in which we conduct business could result in increased compliance costs or additional operating restrictions in the U.S.
We may face various risk associated with the long term trend toward increased activism against oil and gas exploration and development activities.
Opposition toward oil and gas drilling and development activity has been growing globally. Companies in the oil and gas industry are often the target of activist efforts from both individuals and non-governmental organizations regarding safety, environmental compliance and business practices. Anti-development activists are working to, among other things, reduce access to federal and state government lands and delay or cancel certain projects such as the development of oil or gas shale plays. For example, environmental activists continue to advocate for increased regulations or bans on shale drilling and hydraulic fracturing in the United States, even in jurisdictions that are among the most stringent in their regulation of the industry. Future activist efforts could result in the following:
•
delay or denial of drilling permits;
•
shortening of lease terms or reduction in lease size;
•
restrictions on installation or operation of production, gathering or processing facilities;
•
restrictions on the use of certain operating practices, such as hydraulic fracturing, or the disposal of related waste materials, such as hydraulic fracturing fluids and produced water;
•
increased severance and/or other taxes;
•
cyber-attacks;
•
legal challenges or lawsuits;
•
negative publicity about our business or the oil and gas industry in general;
•
increased costs of doing business;
•
reduction in demand for our products; and
•
other adverse effects on our ability to develop our properties and expand production.
We may need to incur significant costs associated with responding to these initiatives. Complying with any resulting additional legal or regulatory requirements that are substantial could have a material adverse effect on our business, financial condition, cash flows and results of operations.
We may be subject to risks in connection with acquisitions and divestitures.
As part of our business strategy, we have made and will likely continue to make acquisitions of oil and gas properties and to divest non-strategic assets. Suitable acquisition properties or suitable buyers of our non-strategic assets may not be available on terms and conditions we find acceptable or not at all.
Acquisitions pose substantial risks to our business, financial condition, cash flows and results of operations. These risks include that the acquired properties may not produce revenues, reserves, earnings or cash flows at anticipated levels. Also, the integration of properties we acquire could be difficult. In pursuing acquisitions, we compete with other companies, many of which have greater financial and other resources. The successful acquisition of properties requires an assessment of several factors, including:
•
recoverable reserves;
•
exploration potential;
•
future oil and natural gas prices and their relevant differentials;
•
operating costs and production taxes; and
•
potential environmental and other liabilities.
These assessments are complex and the accuracy of these assessments is inherently uncertain. In connection with these assessments, we perform a review of the subject properties that we believe to be generally consistent with industry practices. Our review will not reveal all existing or potential problems, nor will it permit us to become sufficiently familiar with the properties to fully assess their deficiencies and capabilities.
In addition, our divestitures may pose significant residual risks to the Company, such as divestitures where we retain certain liabilities or we have legal successor liability due to the bankruptcy or dissolution of the purchaser. Generally, uneconomic or unsuccessful acquisitions and divestitures may divert management’s attention and financial resources away from our existing operations, which could have a material adverse effect on our financial condition, results of operations and cash flow.
We depend on computer and telecommunications systems, and failures in our systems or cyber security attacks could significantly disrupt our business operations.
The oil and gas industry has become increasingly dependent upon digital technologies to conduct day-to-day operations including certain exploration, development and production activities. We have not entered into agreements with third parties for hardware, software, telecommunications and other information technology services in connection with our business. In addition, we have not developed proprietary software systems, management techniques and other information technologies incorporating software licensed from third parties. We depend on digital technology to estimate quantities of oil and natural gas reserves, process and record financial and operating data, analyze seismic and drilling information, and communicate with our employees and third party partners. Our business partners, including vendors, service providers, purchasers of our production and financial institutions, are also dependent on digital technology. It is possible we could incur interruptions from cyber security attacks, computer viruses or malware. We believe that we have positive relations with our related vendors and maintain adequate anti-virus and malware software and controls; however, any cyber incidents or interruptions to our arrangements with third parties, to our computing and communications infrastructure or our information systems could lead to data corruption, communication interruption, unauthorized release, gathering, monitoring, misuse or destruction of proprietary or other information, or otherwise significantly disrupt our business operations. As cyber threats continue to evolve, we may be required to expend significant additional resources to continue to modify or enhance our protective measures or to investigate and remediate any information security vulnerabilities.
Hurricanes, typhoons, tornadoes, earthquakes and other natural disasters could have a material adverse effect on our business, financial condition, results of operations and cash flow.
Hurricanes, typhoons, tornadoes, earthquakes and other natural disasters can potentially destroy thousands of business structures and homes and, if occurring in the Gulf Coast region of the United States, could disrupt the supply chain for oil and gas products. Disruptions in supply could have a material adverse effect on our business, financial condition, results of operations and cash flow. Damages and higher prices caused by hurricanes, typhoons, tornadoes, earthquakes and other natural disasters could also have an adverse effect on our business, financial condition, results of operations and cash flow due to the impact on the business, financial condition, results of operations and cash flow of our customers.
Delays in obtaining licenses, permits, and other government authorizations required to conduct our operations could adversely affect our business.
Our operations require licenses, permits, and in some cases renewals of licenses and permits from various governmental authorities. Our ability to obtain, sustain or renew such licenses and permits on acceptable terms is subject to changes in regulations and policies and to the discretion of the applicable government agencies, among other factors. Our inability to obtain, or our loss of or denial of extension, to any of these licenses or permits could hamper our ability to produce income, revenues or cash flows from our operations.
We may incur losses as a result of title defects in the properties in which we invest.
The existence of a material title deficiency can render a lease worthless and can adversely affect our results of operations and financial condition. While we typically obtain title opinions prior to commencing drilling operations on a lease or in a unit, the failure of title may not be discovered until after a well is drilled, in which case we may lose the lease and the right to produce all or a portion of the interest under the property.
As we continue to expand our operations in Oklahoma, we may operate within the boundaries of Native American reservations and become subject to certain tribal laws and regulations.
An entirely separate and distinct set of laws and regulations applies to operators and other parties within the boundaries of Native American reservations in the United States. Various federal agencies within the U.S. Department of the Interior, particularly the Bureau of Indian Affairs, the Office of Natural Resources Revenue and Bureau of Land Management (BLM), and the EPA, together with each Native American tribe, promulgate and enforce regulations pertaining to oil and gas operations on Native American reservations. These regulations include lease provisions, environmental standards, tribal employment contractor preferences and numerous other matters.
Native American tribes are subject to various federal statutes and oversight by the Bureau of Indian Affairs and BLM. However, each Native American tribe is a sovereign nation and has the right to enact and enforce certain other laws and regulations entirely independent from federal, state and local statutes and regulations, as long as they do not supersede or conflict with such federal statutes. These tribal laws and regulations include various fees, taxes, requirements to employ Native American tribal members or use tribal owned service businesses and numerous other conditions that apply to lessees, operators and contractors conducting operations within the boundaries of a Native American reservation. Further, lessees and operators within a Native American reservation are often subject to the Native American tribal court system, unless there is a specific waiver of sovereign immunity by the Native American tribe allowing resolution of disputes between the Native American tribe and those lessees or operators to occur in federal or state court.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS.
None.

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ITEM 2. PROPERTIES
ITEM 2. DESCRIPTION OF PROPERTY.
Corporate Office
Our principal executive office is located at 4162 Meyerwood Drive, Houston, TX 77025. The Company neither owns nor leases any real or personal property. The Chief Financial Officer allows the use of his residence as an office for the Company at no charge.

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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS.
On July 6, 2020, Premier filed a mechanic’s lien against the interests of Pure, ZQH and the Company in the Project, alleging past unpaid invoices on the part of ZQH and Pure and also alleging that the Company’s ownership is 75% rather than 87.5%. No documentation has been provided to Alpha by ZQH, Pure, or Premier of any unpaid invoices. The Company has subsequently determined that the assignment appears to represent no actual, tangible assets. The Company has notified ZQH and Pure of these findings and informed them of our decision to not pursue the Project. ZQH and Pure have hired legal counsel to examine the question of whether Alpha can legally withdraw from the PSA even with no actual asset.

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES.
Not applicable to our operations.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5. MARKET FOR COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND SMALL BUSINESS ISSUER PURCHASE OF EQUITY SECURITIES.
Market Information.
Our common stock is quoted on the Pink Open Markets under the symbol APHE.
Dividends.
We have not paid cash dividends on our common stock and do not plan to pay such dividends in the foreseeable future. Our Board of Directors will determine our future dividend policy on the basis of many factors, including results of operations, capital requirements, general business conditions, and state law regulating the payment of dividends.
Shareholders.
As of March 31, 2022, there were 18,824,106 shares of common stock outstanding held by 67 shareholders of record, and no shares of preferred stock outstanding.
Transfer Agent.
The Transfer Agent for the Company’s Common Stock is Equity Stock Transfer, 237 West 37th Street, Suite 601, New York, New York 10018.
Recent Sales of Unregistered Securities.
We have no recent sales of unregistered securities

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ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. SELECTED FINANCIAL DATA.
None.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
This discussion should be read in conjunction with the other sections contained herein, including the risk factors and the consolidated financial statements and the related exhibits contained herein. The various sections of this discussion contain a number of forward-looking statements, all of which are based on our current expectations and could be affected by the uncertainties and risk factors described throughout this Report as well as other matters over which we have no control. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of certain factors, including but not limited to those set forth in this Report. See “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements.”
Company Overview
The Company was incorporated in September 2013. Our business model is to engage in the business of oil and gas development. the acquisition cost in 22 to 30 months.
Going Concern
The future of our company is dependent upon its ability to obtain financing and upon future profitable operations. Management has plans to seek additional capital through a private placement and public offering of its common stock, if necessary. Our auditors have expressed a going concern opinion which raises substantial doubt about the Company’s ability to continue as a going concern.
The Company's financial statements are prepared using accounting principles generally accepted in the United States of America (U.S. GAAP) applicable to a going concern, which contemplates the realization of assets and liquidation of liabilities in the normal course of business. However, the Company does not have significant cash or other current assets, nor does it have an established source of revenues sufficient to cover its operating costs and to allow it to continue as a going concern. These conditions raise substantial doubt about the company’s ability to continue as a going concern.
Under the going concern assumption, an entity is ordinarily viewed as continuing in business for the foreseeable future with neither the intention nor the necessity of liquidation, ceasing trading, or seeking protection from creditors pursuant to laws or regulations. Accordingly, assets and liabilities are recorded on the basis that the entity will be able to realize its assets and discharge its liabilities in the normal course of business.
The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish the plan described in the Business paragraph and eventually attain profitable operations. The accompanying financial statements do not include any adjustments that may be necessary if the Company is unable to continue as a going concern.
During the next year, the Company’s foreseeable cash requirements will relate to continual development of the operations of its business, maintaining its good standing and making the requisite filings with the Securities and Exchange Commission, and the payment of expenses associated with research and development. The Company may experience a cash shortfall and be required to raise additional capital.
Historically, it has mostly relied upon internally generated funds and funds from the sale of shares of stock to finance its operations and growth. Management may raise additional capital through future public or private offerings of the Company’s stock or through loans from private investors, although there can be no assurance that it will be able to obtain such financing. The Company’s failure to do so could have a material and adverse effect upon it and its shareholders.
Results of Operations
For the Year Ended December 31, 2021 Compared to the Year Ended December 31, 2020
During the years ended December 31, 2021 and 2020, the Company had minimal revenues from its operating activities. In part, because such activities were focused on identifying potential opportunities and properties.
During the year ended December 31, 2021, the Company recognized a net loss of $1,070,738 compared to $1,986,978 for the year ended December 31, 2020. The decrease of $916,240 was primarily a result of a decrease in impairment expense of $1,000,000, a decrease in interest expense of $107,768, decrease in board of director fees of $16,000 which were offset with gain on settlement of accounts payable of $120,250, increase in loss on change in fair value of derivative liabilities of $8,081 and an increase in general and administrative costs of $314,183.
Liquidity and Capital Resources
As of December 31, 2021, the Company had current assets of $23,967 and total noncurrent assets of $145,791 consisting of acquisition costs. As of December 31, 2021, the Company had total current liabilities of $2,625,072 which includes $270,250 in accounts payable, $228,668 in related parties payable, $145,041 in derivative liability, $77,563 in interest payable, $628,550 in short term advances from related parties, $65,000 in notes payable related party and $1,210,000 in a convertible note payable. The Company had a working capital deficit of $2,601,105.
During the year ended December 31, 2021, the Company used cash of $356,892 in our operations compared to $109,394 during the year ended December 31, 2020. During the year ended December 31, 2021, the Company used $95,791 in investing activities compared to $30,000 used by investing activities during the year ended December 31, 2020. During the year ended December 31, 2021, the Company received funds of $452,900 from our financing activities compared to $139,394 during the year ended December 31, 2020. Net change in cash was $217 during the year ended December 31, 2021 compared to a decrease of $0 for the year ended December 31, 2020.
At various times during the year ended December 31, 2021 and 2020, the Company received advances, short term notes and advances on convertible line payable related parties for operating expenses. During the year ended December 31, 2021, the Company received proceeds from convertible loan payable - related party of $20,000 and advances from related party of $427,900 and proceeds from the sale of common stock of $5,000. During the year ended December 31, 2020, the Company made payments on convertible line payable of $4,250, payments on short term notes of $100,000 and repayments on short term advances from related parties of $856. The Company also received proceeds from the sale of common stock of $75,000, proceeds from convertible loan payable of $8,500, advances from related party of $96,000 and note payable -related party of $65,000 during the year ended December 31, 2020.
In summary, our cash flows were as follows:
Fiscal Year Ended December 31,
Net cash used in operating activities
$ (356,892 )
$ (109,394 )
Net cash used in investing activities
(95,791 )
(30,000 )
Net cash provided by financing activities
452,900
139,394
Net change in cash and cash equivalents
-
Cash and cash equivalents, beginning of year
-
-
Cash and cash equivalents, end of year
$
$ -
Short Term
On a short-term basis, the Company has not generated revenues sufficient to cover operations. Based on prior history, the Company will continue to have insufficient revenue to satisfy current and recurring liabilities as the Company continues exploration activities.
Capital Resources
Other than the targeted acquisitions, the Company has no material commitments for capital expenditures within the next year, however if operations are commenced, substantial capital will be needed to pay for participation, investigation, exploration, acquisition and working capital.
Need for Additional Financing
The Company does not have capital sufficient to meet its cash needs. The Company will have to seek loans or equity placements to cover such cash needs. Once exploration commences, its needs for additional financing is likely to increase substantially.
No commitments to provide additional funds have been made by the Company's management or other stockholders. Accordingly, there can be no assurance that any additional funds will be available to us to allow us to cover the Company's expenses as they may be incurred.
The Company will need substantial additional capital to support its proposed future petroleum exploration operations. The Company has minimal revenues. The Company has no committed source for any funds as of the date hereof. No representation is made that any funds will be available when needed. In the event funds cannot be raised when needed, the Company may not be able to carry out its business plan, may never achieve sales or royalty income, and could fail in business as a result of these uncertainties.
Decisions regarding future participation in exploration wells or geophysical studies or other activities will be made on a case-by-case basis. The Company may, in any particular case, decide to participate or decline participation. If participating, the Company may pay its proportionate share of costs to maintain the Company's proportionate interest through cash flow or debt or equity financing. If participation is declined, the Company may elect to farm-out, non-consent, sell or otherwise negotiate a method of cost sharing in order to maintain some continuing interest in the prospect.
Off Balance Sheet Arrangements
None
Critical Accounting Policies
The discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of these consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an on-going basis, we evaluate our estimates based on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. Management determined there were no critical accounting estimates.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Report of Independent Registered Public Accounting Firm (PCAOB ID: 206)
Consolidated Balance Sheets as of December 31, 2021 and 2020
Consolidated Statements of Operations for the years ended December 31, 2021 and 2020
Consolidated Statements of Stockholders' Deficit for the years ended December 31, 2021 and 2020
Consolidated Statements of Cash Flows for the years ended December 31, 2021 and 2020
Notes to Consolidated Financial Statements
-
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and Board of Directors of
Alpha Energy, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Alpha Energy, Inc. and its subsidiary (collectively, the “Company”) as of December 31, 2021 and 2020, and the related consolidated statements of operations, stockholders’ deficit, and cash flows for the years then ended, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of their operations and their cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.
Going Concern Matter
The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has suffered recurring losses from operations and has a net capital deficiency that raises substantial doubt about its ability to continue as a going concern. Management's plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the 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 audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The 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 audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
Critical audit matters are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters.
/s/ MaloneBailey, LLP
www.malonebailey.com
We have served as the Company's auditor since 2020.
Houston, Texas
March 31, 2022
ALPHA ENERGY, INC.
CONSOLIDATED BALANCE SHEETS
December 31, 2021
December 31, 2020
Assets
Current Assets:
Cash
$ 217 $ -
Prepaids and other current assets
23,750 30,000
Total current assets
23,967 30,000
Noncurrent Assets:
Oil and gas properties, unproved, full cost
145,791 70,000
Total Assets
$ 169,758 $ 100,000
Liabilities and Stockholders' Deficit
Current Liabilities:
Accounts payable and accrued expenses
$ 270,250 $ 585,732
Accounts payable and accrued expenses - related parties
228,668 120,568
Interest payable
77,563 31,295
Short term advances from related parties
628,550 116,000
Note payable - related party
65,000 65,000
Short term note
- 1,160,000
Convertible note payable
1,210,000 -
Derivative liability
145,041 96,369
Total current liabilities
2,625,072 2,174,964
Convertible credit line payable - related party, net of discount of $11,100 and $2,754, respectively
157,228 145,574
Asset retirement obligation
918 862
Total Liabilities
2,783,218 2,321,400
Commitments and contingencies
Stockholders' Deficit:
Preferred stock, 10,000,000 shares authorized:
Series A convertible preferred stock, $0.001 par value, 2,000,000 shares authorized and 0 shares issued and outstanding
- -
Common stock, $0.001 par value, 65,000,000 shares authorized and 18,824,106 and 18,145,428 shares issued and outstanding, respectively
18,824 18,145
Additional paid-in capital
2,739,634 2,061,635
Accumulated deficit
(5,371,918 )
(4,301,180 )
Total Stockholders' Deficit
(2,613,460 )
(2,221,400 )
Total Liabilities and Stockholders' Deficit
$ 169,758 $ 100,000
See accompanying notes to the consolidated financial statements.
ALPHA ENERGY, INC
CONSOLIDATED STATEMENTS OF OPERATIONS
Year Ended
December 31, 2021
Year Ended
December 31, 2020
Oil and gas sales
$ 3,839 $ 1,217
Lease operating expenses
15,652 2,915
Gross loss
(11,813 )
(1,698 )
Operating expenses:
Professional services
96,916 87,267
Board of director fees
192,000 208,000
General and administrative
725,832 436,649
Gain on settlement of accounts payable
(120,250 ) -
Impairment loss
- 1,000,000
Total operating expenses
894,498 1,731,916
Loss from operations
(906,311 )
(1,733,614 )
Other income (expense):
Interest expense
(131,117 )
(238,885 )
Gain on extinguishment of debt
- 10,750
Loss on change in fair value of derivative liabilities
(33,310 )
(25,229 )
Total other income (expense)
(164,427 )
(253,364 )
Net loss
$ (1,070,738 )
$ (1,986,978 )
Loss per share:
Basic and diluted
$ (0.06 )
$ (0.11 )
Weighted average shares outstanding:
Basic and diluted
18,329,925 17,966,907
See accompanying notes to the consolidated financial statements.
ALPHA ENERGY, INC.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ DEFICIT
FOR THE YEARS ENDED DECEMBER 31, 2021 AND 2020
Common Stock
Additional
Accumulated
Total Stockholders’
Shares
Amount
Paid-in Capital
Deficit
Deficit
Balance, December 31, 2019
17,822,428 $ 17,822 $ 1,738,958 $ (2,314,202 )
$ (557,422 )
Stock issued for cash
75,000 75 74,925 - 75,000
Stock issued for settlement of accounts payable
5,000 5 4,995 - 5,000
Stock issued as lease acquisition cost for unproved properties
10,000 10 9,990 - 10,000
Stock-based compensation
233,000 233 232,767 - 233,000
Net loss
- - - (1,986,978 )
(1,986,978 )
Balance, December 31, 2020
18,145,428 18,145 2,061,635 (4,301,180 )
(2,221,400 )
Stock issued for cash
5,000 5 4,995 - 5,000
Stock issued for settlement of liabilities
451,678 452 451,226 - 451,678
Stock-based compensation
222,000 222 221,778 - 222,000
Net loss
- - - (1,070,738 )
(1,070,738 )
Balance, December 31, 2021
18,824,106 $ 18,824 $ 2,739,634 $ (5,371,918 )
$ (2,613,460 )
See accompanying notes to the consolidated financial statements.
ALPHA ENERGY, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended
December 31, 2021
Year Ended
December 31, 2020
Cash Flows from Operating Activities:
Net loss
$ (1,070,738 )
$ (1,986,978 )
Adjustments to reconcile net loss to net cash used in operating activities:
Stock-based compensation
262,000 233,000
Bad debt expense
25,000 -
-Amortization of debt discount
7,016 20,493
Loss on change in fair value of derivative liabilities
33,310 25,229
Gain on extinguishment of debt
- (10,750 )
Gain on settlement of accounts payable
(120,250 )
-
Impairment loss
- 1,000,000
Write off of option contract associated with oil and gas properties
85,500 -
Asset retirement obligation expense
56 76
Default interest added to note payable
50,000 200,000
Changes in operating assets and liabilities:
Prepaids and other current assets
(18,750 )
(30,000 )
Accounts payable
235,596 304,263
Accounts payable-related party
108,100 116,881
Interest payable
46,268 18,392
Net cash used in operating activities
(356,892 )
(109,394 )
Cash Flows from Investing Activities:
Deposit for purchase of oil and gas properties
(95,791 )
(30,000 )
Net cash used in investing activities
(95,791 )
(30,000 )
Cash Flows from Financing Activities:
Proceeds from convertible credit line payable - related party
20,000 8,500
Payment on convertible credit line payable - related party
- (4,250 )
Advances from related parties
427,900 96,000
Proceeds from note payable - related party
- 65,000
Payments on short term note
- (100,000 )
Payments on short term advances from related parties
- (856 )
Proceeds from sale of common stock
5,000 75,000
Net cash provided by financing activities
452,900 139,394
Net change in cash and cash equivalents
217 -
Cash and cash equivalents, at beginning of period
- -
Cash and cash equivalents, at end of period
$ 217 $ -
Supplemental disclosures of cash flow information:
Cash paid for interest
$ 27,834 $ -
Cash paid for income taxes
$ - $ -
Supplemental disclosure of non-cash investing and financing activities:
Unpaid oil and gas assets acquired
$ 65,500 $ 1,020,000
Debt discount on convertible credit line payable related party
$ 15,362 $ 5,581
Expenses paid on behalf of the Company by related party
$ 19,150 $ 13,959
Stock issued for settlement of liabilities
$ 451,678 $ 5,000
Stock issued as lease acquisition cost for unproved properties
$ - $ 10,000
Accrued interest added to note principal
$ - $ 10,000
See accompanying notes to the consolidated financial statements.
ALPHA ENERGY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1 - NATURE OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Organization, Nature of Business and Trade Name
The Company was incorporated in the State of Colorado on September 26, 2013 for the purpose of acquiring and executing on oil and gas leases. The Company has realized limited revenues from its planned business activities.
A summary of significant accounting policies of Alpha Energy, Inc. (“we”, “our”, the Company) is presented to assist in understanding the Company’s financial statements. The accounting policies presented in these footnotes conform to accounting principles generally accepted in the United States of America and have been consistently applied in the preparation of the accompanying financial statements. These consolidated financial statements and notes are representations of the Company’s management who are responsible for their integrity and objectivity.
Principles of Consolidation
Our consolidated financial statements include our accounts and the accounts of our 100% owned subsidiary, Alpha Energy Texas Operating, LLC. All intercompany transactions and balances have been eliminated. Our consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”).
Basis of Presentation and Use of Estimates
The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reported period. Actual results could differ from those estimates. Management further acknowledges that it is solely responsible for adopting sound accounting practices, establishing and maintaining a system of internal accounting control and preventing and detecting fraud. The Company’s system of internal accounting control is designed to assure, among other items, that (1) recorded transactions are valid; (2) all valid transactions are recorded and (3) transactions are recorded in the period in a timely manner to produce financial statements which present fairly the financial condition, results of operations and cash flows of the company for the respective periods being presented.
Revenue and Cost Recognition
Effective January 1, 2018, we adopted ASU 2014-09, Revenue from Contracts with Customers (Topic 606). Under the new standard, we recognize revenues when the following criteria are met: (i) persuasive evidence of a contract with a customer exists, (ii) identifiable performance obligations under the contract exist, (iii) the transaction price is determinable for each performance obligation, (iv) the transaction price is allocated to each performance obligation, and (v) the performance obligations are satisfied. We derive all of our revenues from oil and gas production.
The Company records revenues from the sales of natural gas and crude oil when the production is produced and sold, and also when collectability is ensured. The Company may in the future have an interest with other producers in certain properties, in which case the Company will use the sales method to account for gas imbalances. Under this method, revenue is recorded on the basis of natural gas actually sold by the Company. The Company also reduces revenue for other owners’ natural gas sold by the Company that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company’s remaining over- and under-produced gas balancing positions are considered in the Company’s proved oil and natural gas reserves. The Company had no gas imbalances at December 31, 2021 or 2020. The Company recorded revenues of $3,839 and $1,217 and costs of revenues totaling $15,652 and $2,915 during the years ended December 31, 2021 and 2020 respectively.
F-
Basic and Diluted Earnings per share
Net loss per share is provided in accordance with FASB ASC 260-10, "Earnings (Loss) per Share". Basic loss per share is computed by dividing net loss attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted loss per share gives effect to all dilutive potential common shares outstanding during the period. Dilutive loss per share excludes all potential common shares if their effect is anti-dilutive. For the years ended December 31, 2021 and 2020, there were 168,328 and 148,328 shares issuable from convertible credit line payable which were considered for their dilutive effects but concluded to be anti-dilutive, respectively.
Fair Value of Financial Instruments
The Company applies fair value accounting for all financial assets and liabilities and non-financial assets and liabilities that are recognized or disclosed at fair value in the financial statements on a recurring basis. The Company defines fair value as the price that would be received from selling an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. When determining the fair value measurements for assets and liabilities, which are required to be recorded at fair value, the Company considers the principal or most advantageous market in which the Company would transact and the market-based risk measurements or assumptions that market participants would use in pricing the asset or liability, such as risks inherent in valuation techniques, transfer restrictions and credit risk. Fair value is estimated by applying the following hierarchy, which prioritizes the inputs used to measure fair value into three levels and bases the categorization within the hierarchy upon the lowest level of input that is available and significant to the fair value measurement:
Level 1 - Quoted prices in active markets for identical assets or liabilities.
Level 2 - Observable inputs other than quoted prices in active markets for identical assets and liabilities, quoted prices for identical or similar assets or liabilities in inactive markets, or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities.
Level 3 - Inputs that are generally unobservable and typically reflect management’s estimate of assumptions that market participants would use in pricing the asset or liability.
The carrying amount of the Company’s financial instruments consisting of accounts payable, notes payable and convertible notes approximates fair value due either to length of maturity or interest rates that approximate prevailing market rates unless otherwise disclosed in these financial statements.
Derivative Financial Instruments
Fair value accounting requires bifurcation of embedded derivative instruments such as conversion features in convertible debt or equity instruments and measurement of their fair value for accounting purposes. In assessing the convertible debt instruments, management determines if the convertible debt host instrument is conventional convertible debt and further if there is a beneficial conversion feature requiring measurement. If the instrument is not considered conventional convertible debt under ASC 470, the Company will continue its evaluation process of these instruments as derivative financial instruments under ASC 815. The Company applies the guidance in ASC 815-40-35-12 to determine the order in which each convertible instrument would be evaluated for derivative classification. The Company’s sequencing policy is to evaluate for reclassification contracts with the earliest maturity date first. Once determined, derivative liabilities are adjusted to reflect fair value at each reporting period end, with any increase or decrease in the fair value being recorded in results of operations as an adjustment to fair value of derivatives.
Oil and natural gas properties
We account for our oil and natural gas producing activities using the full cost method of accounting as prescribed by the United States Securities and Exchange Commission (SEC). Under this method, subject to a limitation based on estimated value, all costs incurred in the acquisition, exploration, and development of proved oil and natural gas properties, including internal costs directly associated with acquisition, exploration, and development activities, the costs of abandoned properties, dry holes, geophysical costs, and annual lease rentals are capitalized within a cost center. Costs of production and general and administrative corporate costs unrelated to acquisition, exploration, and development activities are expensed as incurred.
Costs associated with unevaluated properties are capitalized as oil and natural gas properties but are excluded from the amortization base during the evaluation period. When we determine whether the property has proved recoverable reserves or not, or if there is an impairment, the costs are transferred into the amortization base and thereby become subject to amortization.
We assess all items classified as unevaluated property on at least an annual basis for inclusion in the amortization base. We assess properties on an individual basis or as a group if properties are individually insignificant. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate that there would be impairment, or if proved reserves are assigned to a property, the cumulative costs incurred to date for such property are transferred to the amortizable base and are then subject to amortization.
F-
Capitalized costs are included in the amortization base, including estimated asset retirement costs, plus the estimated future expenditures to be incurred in developing proved reserves, net of estimated salvage values. Sales or other dispositions of oil and natural gas properties are accounted for as adjustments to capitalized costs, with no gain or loss recorded unless the ratio of cost to prove reserves would significantly change.
Concentrations of Risk
The Company has 100 % interest in two separate oil and gas leases, all of which are located in the state of Colorado. Environmental and regulatory factors within the state beyond the control of the Company may limit the Company’s future production of all its leases.
The Company has a single buyer for the gas produced from one of its leases. The loss of this buyer would have a material adverse impact on our business.
Impairment
The net book value of all capitalized oil and natural gas properties within a cost center, less related deferred income taxes, is subject to a full cost ceiling limitation which is calculated quarterly. Under the ceiling limitation, costs may not exceed an aggregate of the present value of future net revenues attributable to proven oil and natural gas reserves discounted at 10 percent using current prices, plus the lower of cost or market value of unproved properties included in the amortization base, plus the cost of unevaluated properties, less any associated tax effects. Any excess of the net book value, less related deferred tax benefits, over the ceiling is written off as expense. Impairment expense recorded in one period may not be reversed in a subsequent period even though higher oil and gas prices may have increased the ceiling applicable to the subsequent period. On June 25, 2020, the Company entered into a Purchase and Sale Agreement with Pure Oil & Gas, Inc. (“Pure”) and ZQH Holding, LLC (“ZQH”) to acquire oil and gas assets in Rogers County Oklahoma (the “Project”) in consideration of a purchase price of $1,000,000. During the year ended December 31, 2020, the Company fully impaired the Project due to the lack of funds for development.
Asset retirement obligation
We record the fair value of an asset retirement cost, and corresponding liability as part of the cost of the related long-lived asset and the cost is subsequently allocated to expense using a systematic and rational method. We record an asset retirement obligation to reflect our legal obligations related to future plugging and abandonment of our oil and natural gas wells and gathering systems. We estimate the expected cash flow associated with the obligation and discount the amount using a credit-adjusted, risk-free interest rate. At least annually, we reassess the obligation to determine whether a change in the estimated obligation is necessary. We evaluate whether there are indicators that suggest the estimated cash flows underlying the obligation have materially changed. Should those indicators suggest, the estimated obligation may have materially changed on an interim basis (quarterly), we will update our assessment accordingly. Additional retirement obligations increase the liability associated with new oil and natural gas wells and gathering systems as these obligations are incurred. The Company had accrued an asset retirement obligation liability totaling $918 and $862 as of December 31, 2021 and 2020, respectively.
Income Taxes
The Company accounts for income taxes under ASC 740 "Income Taxes" which codified SFAS 109, "Accounting for Income Taxes" and FIN 48 “Accounting for Uncertainty in Income Taxes - an Interpretation of FASB Statement No.109.” Under the asset and liability method of ASC 740, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the consolidated financial statements carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. Under ASC 740, the effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period the enactment occurs. A valuation allowance is provided for certain deferred tax assets if it is more likely than not that the Company will not realize tax assets through future operations.
F-
Related Parties
The Company follows ASC 850, Related Party Disclosures, for the identification of related parties and disclosure of related party transactions.
Recent Accounting Pronouncements
The Company does not believe that any other recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the accompanying financial statements.
Reclassification
Certain reclassifications may have been made to our prior year’s financial statements to conform to our current year presentation. These reclassifications had no effect on our previously reported results of operations or accumulated deficit.
NOTE 2 - GOING CONCERN
The Company's financial statements are prepared using accounting principles generally accepted in the United States of America applicable to a going concern, which contemplates the realization of assets and liquidation of liabilities in the normal course of business. However, the Company does not have significant cash or other current assets, nor does it have an established source of revenues sufficient to cover its operating costs and to allow it to continue as a going concern. These conditions raise substantial doubt about the Company’s ability to continue as a going concern for a period of twelve months from the date of issuance of these financial statements.
Under the going concern assumption, an entity is ordinarily viewed as continuing in business for the foreseeable future with neither the intention nor the necessity of liquidation, ceasing trading, or seeking protection from creditors pursuant to laws or regulations. Accordingly, assets and liabilities are recorded on the basis that the entity will be able to realize its assets and discharge its liabilities in the normal course of business.
The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish its business plans and eventually attain profitable operations. The accompanying financial statements do not include any adjustments that may be necessary if the Company is unable to continue as a going concern.
During the next year, the Company’s foreseeable cash requirements will relate to continual development of the operations of its business, maintaining its good standing, making the requisite filings with the Securities and Exchange Commission, and the payment of expenses associated with oil and gas exploration. The Company may experience a cash shortfall and be required to raise additional capital.
Historically, it has mostly relied upon internally generated funds and funds from the sale of shares of stock to finance its operations and growth. Management may raise additional capital through future public or private offerings of the Company’s stock or through loans from private investors, although there can be no assurance that it will be able to obtain such financing. The Company’s failure to do so could have a material and adverse effect upon it and its shareholders.
F-
NOTE 3 - OIL AND GAS PROPERTIES
The Company entered into a Letter of Intent with Chicorica, LLC on December 13, 2018 and extended the agreement through March 4, 2022. On March 1, 2022, the Company entered into an extension agreement with Chicorica to extend the Closing through August 5, 2022. In return, the Company must pay $30,000 by April 1, 2022, $35,000 by July 8, 2022 and $30,000 by August 5, 2022.
On June 25, 2020, the Company entered into a Purchase and Sale Agreement with Pure Oil & Gas, Inc. (“Pure”) and ZQH Holding, LLC (“ZQH”) to acquire oil and gas assets in Rogers County Oklahoma (the “Project”) in consideration of a purchase price of $1,000,000. Pursuant to the agreement, the Company has taken assignment of all of ZQH and Pure's working interest in the Project and has recognized a note payable to ZQH and Pure as of December 31, 2020 of $1,060,000 consisting of the purchase price of $1,000,000 and the principal and accrued interest on an existing note totaling to $60,000. (See Note 7). The Company, ZQH, and Pure agreed that the sellers' combined working interest in the Project is 87.5%. Pursuant to the Agreement, the Company has taken assignment of all of ZQH and Pure's Working Interest in the Project. The current operator of the Project and owner of the residual Working Interest is Premier Gas Company, LLC (“Premier”). As of December 31, 2020, the Company fully impaired the Project due to the lack of funds for development.
On July 6, 2020, Premier filed a mechanic’s lien in Rogers County alleging past unpaid invoices and also claiming incorrectly that Alpha’s ownership is 75% rather than 87.5%. No documentation has been provided Alpha of any past due invoices by Premier, Pure, or ZQH, and we intend to contest the lien vigorously.
The Company notes that the Project is included in the lands in eastern Oklahoma affected by a decision of the U.S. Supreme Court issued on July 9, 2020. In McGirt v. Oklahoma the Supreme Court held that a large portion of eastern Oklahoma reserved for the Creek Nation in the 19th century remains Indian Country for purposes of the federal Major Crimes Act. The impact of this decision on title to the lands and leases included in the Project is uncertain at this point, and the Company will continue to monitor developments concerning the effects of this decision. The Company has subsequently determined that the assignment appears to represent no actual, tangible assets. The Company has notified ZQH and Pure of these findings and informed them of our decision to not pursue the Project. ZQH and Pure have hired legal counsel to examine the question of whether Alpha can legally withdraw from the PSA even with no actual asset.
On June 30, 2020, the Company entered into an option Agreement with Progressive Well Service, LLC (“Progressive”) to acquire oil and gas assets in Lincoln and Logan Counties in Central Oklahoma (the “Coral Project”, called the “Logan 1 Project” in the Agreement). The agreement gives the Company until December 31, 2020 to exercise its option (the “Option Period”). During the Option Period, Progressive may not sell the Coral Project to any third party. In return for this exclusivity, the Company issued 10,000 shares of its common stock with a fair value of $10,000, such shares to bear a legend restricting sale during the Option Period. At closing the Company shall make a cash payment of $600,000 (less Monthly Extension Payments) to Progressive (the “Project Payment”) and guarantee to Progressive a further payment of 3% of the net revenue stream from any new wells drilled in the Coral Project (the “Production Payment”) until Progressive has received an additional $350,000. Since December 2020, the Company and Progressive have entered into various Extension Agreements, the current one being dated June 30th, 2021 (the “Extension Agreement”). The Extension Agreement extends the period by which Closing must occur through November 30, 2021, in return for which the Company makes a monthly payment of ten thousand dollars ($10,000), which sum is to be applied toward the Project Payment. On November 30, 2021, the Company and Progressive verbally agreed to extend the closing to February 2022. On March 9, 2022, the Company closed on the acquisition of 34 well bores and related assets under the PSA. We are entitled to receive the proceeds of production from January 1, 2022 under the terms of the PSA and Progressive is required to operate the properties and transfer ownership and royalty decks to Company following a one-month transition period. Under the PSA we are obligated to make a further payment of three (3%) percent of the net revenue from new wells drilled until Progressive receives an additional $350,000.
On September 8, 2020, the Company entered into an Option Agreement with Kadence Petroleum, LLC. (“Kadence”) to acquire oil and gas assets in Logan County in Central Oklahoma, called the “Logan 2 Project” in the Agreement). The Agreement gives the Company until February 8, 2021 to exercise its option (the “Option Period”). During the Option Period, Kadence may not sell the Logan 2 Project to any third party. In return for this exclusivity, the Company will pay $10,000 per month. The Company paid $10,000 to Brian Tribble, Managing Member of Kadence, through AEI Acquisition, LLC revolving credit note, on September 18, 2020. At closing, Alpha shall tender to Kadence a cash payment of $350,000 (the “Project Payment”). Alpha shall agree at Closing to make a monthly payment equal to 3% of the net revenue stream from any new wells (not workovers, restarts, or recompletions) drilled in the Project area after the Closing until such time as Kadence shall have accrued $800,000 from such new wells (the “Production Payment”). Together, the Option Payment, Production Payment, and Project Payment shall satisfy the Purchase Price. On March 3, 2021, the Company amended the agreement until May 1, 2021, with a $10,000 monthly payment in January through April 2021. The Company had advanced $85,500 in option payments through September 30, 2021. The agreement is cancelled, and the Company wrote off the $85,500 as of September 30, 2021.
F-
Oil and gas properties at December 31, 2021 and 2020 consisted of the following:
Balance
Balance
Account
12/31/2020
Additions
Impairment
12/31/2021
Leasehold Improvements - Chico Rica, LLC
$ 10,000 $ - $ - $ 10,000
Leasehold Improvements - Undeveloped
- 15,791 - 15,791
Lease Acquisition Costs - Logan County Project I
10,000 110,000 - 120,000
Lease Acquisition Costs - Logan County Project II
50,000 35,500 85,500 -
Total oil and gas related assets
$ 70,000 $ 161,291 $ 85,500 $ 145,791
NOTE 4 - INCOME TAXES
The Company provides for income taxes under FASB ASC 740, Accounting for Income Taxes. FASB ASC 740 requires the use of an asset and liability approach in accounting for income taxes. Deferred tax assets and liabilities are recorded based on the differences between the financial statement and tax bases of assets and liabilities and the tax rates in effect currently.
FASB ASC 740 requires the reduction of deferred tax assets by a valuation allowance, if, based on the weight of available evidence, it is more likely than not that some or all of the deferred tax assets will not be realized. In the Company’s opinion, it is uncertain whether they will generate sufficient taxable income in the future to fully utilize the net deferred tax asset. Accordingly, a valuation allowance equal to the deferred tax asset has been recorded.
The total deferred tax asset was approximately $626,000 and $424,000 as of December 31, 2021 and 2020, respectively which is calculated by multiplying a 25.63% estimated tax rate by the cumulative net operating loss (NOL) of approximately $2,440,000 and $1,655,000, respectively.
Due to the enactment of the Tax Reform Act of 2017, we have calculated our deferred tax assets using an estimated corporate tax rate of 25.63%. US Tax codes and laws may be subject to further reform or adjustment which may have a material impact to the Company’s deferred tax assets and liabilities.
The Company is subject to United States federal income taxes at an approximate rate of 21% and state income taxes at an approximate rate of 4.63%. The reconciliation of the provision for income taxes at the United States federal statutory rate compared to the Company’s income tax expense as reported is as follows:
The net deferred tax assets consist of the following:
Deferred income tax assets
Net operating loss carry forward
$ 626,000 $ 424,000
Valuation allowance
(626,000 )
(424,000 )
Net deferred income tax asset
$ - $ -
A reconciliation of income taxes computed at the statutory rate is as follows:
Tax benefit at effective rate
$ 202,000 $ 202,000
Change in valuation allowance
(202,000 )
(202,000 )
Provision for income taxes
$ - $ -
The Company has an operating loss carry forward of approximately $2,440,000.
NOTE 5 - COMMON STOCK
The Company is authorized to issue up to 10,000,000 shares of $0.001 par value preferred stock and 65,000,000 shares of $0.001 par value common stock. The Board of Directors authorized the issuance of up to 2,000,000 share of Series A convertible preferred stock with a par value of $0.001.
The Company compensates its each director with 4,000 shares of common stock each month. During the years ended December 31, 2021 and 2020, the Company issued 192,000 and 208,000 shares of common stock valued at $192,000 and $208,000, respectively, as board of director compensation.
The Company pays its CFO a yearly bonus of 25,000 shares of common stock. During the years ended December 31, 2021 and 2020, the Company issued 25,000 shares of common stock to the CFO with a fair value of $25,000.
F-
The Company issued its CFO 361,678 shares of common stock on December 31, 2021 valued at $1.00 per share, to settle $361,678 of accrued officer compensation.
During the year ended December 31, 2021, the Company reclassified 40,000 shares issued for services in a prior year, which are currently in dispute, to accounts payable.
During the year ended December 31, 2021, the Company issued 90,000 shares of common stock with a fair value of $90,000 to settle accounts payable of $210,250. The Company recognized a gain of $120,250 on settlement of accounts payable.
During the years ended December 31, 2021 and 2020, the Company sold 5,000 and 75,000 shares of the common stock for total proceeds of $5,000 and $75,000, respectively.
On April 1, 2021, the Company entered into a month-to-month consulting agreement with Kelloff Oil & Gas, LLC for consulting services that includes cash compensation of $10,000 and the issuance of 5,000 shares of common stock per month. The Company may terminate the agreement at any moment with a ten-day notice. During the year ended December 31, 2021, the Company issued 45,000 common shares and recognized $45,000 of stock-based compensation related to the agreement.
During the year ended December 31, 2020, the Company issued 10,000 shares of common stock with a fair value of $10,000 for lease acquisition cost for unproved properties.
During the year ended December 31, 2020, the Company issued 5,000 shares of common stock with a fair value of $5,000 to settle outstanding accounts payable balance.
On August 6, 2020 the Board authorized an additional 550,000 shares of common stock for sale at $1.00 per share bringing the total to 1,300,000 shares.
NOTE 6 - RELATED PARTY TRANSACTIONS
The Company received advances from related parties totaling $427,900 and $96,000 and repaid $0 and $856 during the years ended December 31, 2021 and 2020, respectively. During the years ended December 31, 2021 and 2020, related parties paid $19,150 and $13,959 of expense on behalf of the Company, and $65,500 and $1,020,000 for unpaid oil and gas assets acquired. The advances from related parties are not convertible to common stock, bear no interest and are due on demand. As of December 31, 2021 and 2020, there was $628,550 and $116,000 of short-term advances due to related parties, respectively.
As of December 31, 2021 there was $228,668 of accounts payable related parties which consisted of $208,484 due to Leaverite Exploration for Interim President Jay Leaver, $4,394 due to CFO John Lepin, $10,000 due Kelloff Oil &Gas, LLC for Vice President Joe Kelloff and $5,790 due to Staley Engineering LLC for consulting services.
As of December 31, 2020 there was $120,568 of accounts payable related parties which consisted of $110,894 due to Leaverite Exploration for Interim President Jay Leaver, $3,884 due to CFO John Lepin and $5,790 due to Staley Engineering LLC for consulting services.
On December 3, 2020, the Company executed a promissory note for $65,000 with the President of the Company. The unsecured note matures three years from date of issue and bears interest at 5.00% per annum. As of December 31, 2021 and 2020, the note payable related party balance was $65,000 with accrued interest of $13,003 and $0, respectively.
The Chief Financial Officer allows the use of his residence as an office for the Company at no charge.
A board member of the Company acts as corporate council to Company at no charge, other than board of director fees.
F-
NOTE 7- NOTES PAYABLE AND CONVERTIBLE NOTE PAYABLE
On March 30, 2019, the Company executed a promissory note for $50,000 to ZQH (75%) and Pure (25%). The due date of the note is April 30, 2019 and has an interest rate of $50 per day. The note is for an escrow payment made directly to Premier Gas Company, LLC to hold the Purchase and Sale Agreement dated January 29, 2019. The note is secured by 50,000 shares of the Company’s common stock at $1 per share. On June 25, 2020, the Company entered into a Purchase and Sale Agreement (“PSA”) with Pure and ZQH to acquire oil and gas assets in Oklahoma (the “Rogers Project”) in consideration of a purchase price of $1,000,000. In connection with the purchase, the $50,000 note and accrued interest of $10,000 was added to the purchase price resulting in a total note payable balance of $1,060,000. During the year ended December 31, 2020, $10,750 of accrued interest which was previously outstanding was discharged and recorded as a gain on extinguishment of debt. The note payable of $1,060,000 was due to be paid on or before July 31, 2020 but remains outstanding to date. The balance of the note will increase by $50,000 per month thereafter up to a maximum amount of $200,000 through December 1, 2020. As of December 31, 2020, the Company recognized $200,000 of default interest that was added to the principal and made payments of $100,000 for a total payable of $1,160,000. If the purchase price is not fully paid on or before December 1, 2020, ZQH and Pure have the option to convert the balance outstanding into the Company’s common stock at a conversion price of $1.00 per share and the note will also be subject to a monthly interest of 1%. The Company, Pure, and ZQH have entered into various Extension Agreements, the current one of which is dated March 28th, 2021 (the “Extension Agreement”). The Extension Agreement prevents Pure and ZQH from taking stock rather than cash through June 1, 2021, in return for which Company makes a monthly interest payment to ZQH and Pure of $10,083, which represents 1% annual interest on the Purchase Price, compounded monthly. The Extension Agreement allows the Company to extend that period beyond June 1, 2021 under similar terms. No further Extension Agreement has been entered into to date. Per the extension agreement, ZQH and Pure have the option to convert all or part of the purchase price to the Company’s common stock at $1.00 per share after June 1, 2021. The Company evaluated the conversion option and concluded a beneficial conversion feature and embedded derivative were not present at the date of conversion. As a result of the conversion option on June 1, 2021, the Company reclassified the note payable to convertible note payable.
During the year ended December 31, 2021, the Company recognized $50,000 of default interest that was added to the principal of the note payable. As of December 31, 2021, the convertible note payable balance was $1,210,000 with accrued interest of $22,882. The Company is in legal discussions with ZQH to relieve the loan as the properties in the purchase agreement were not held by title.
NOTE 8- CONVERTIBLE CREDIT LINE PAYABLE - RELATED PARTY
On September 1, 2017, the Company entered into a convertible credit line agreement to borrow up to $500,000. On the same date, the outstanding balance on a note payable of $87,366 was exchanged as a draw on the credit line. The loan modification is considered substantial under ASC 470-50. The outstanding balance accrues interest at a rate of 7% per annum and the outstanding balance is convertible to common stock of the Company at the lesser of the close price of the common stock as quoted on the OTCBB on the day interest is due and payable immediately preceding the conversion or $1.50. The Company analyzed the conversion option in the convertible line of credit for derivative accounting consideration under ASC 815, Derivative and Hedging, and determined that the transaction does qualify for derivative treatment. The Company measured the derivative liability and recorded a debt discount of $87,366 upon initial measurement. During the year ended December 31, 2020, the Company received $8,500 in cash proceeds from the credit line, made $4,250 in cash payments and recognized an additional debt discount of $5,851.
On June 1, 2021, the Company entered into a new convertible credit line agreement to borrow up to $1,500,000. The new convertible line agreement supersedes the original note dated September 1, 2017 and matures on June 1, 2023. The outstanding balance accrues interest at a rate of 7% per annum and the outstanding balance is convertible to common stock of the Company at the lesser of the close price of the common stock as quoted on the OTCBB on the day interest is due and payable immediately preceding the conversion or $4.00. The Company analyzed the conversion option in the convertible line of credit for derivative accounting consideration under ASC 815, Derivative and Hedging, and determined that the transaction does qualify for derivative treatment. The Company evaluated the new convertible credit line for debt modification in accordance with ASC 470-50 and concluded that the debt qualified for debt modification as the borrowing capacity under the new credit line is greater than the borrowing capacity under the original credit line. There were no fees paid to the creditor and no unamortized deferred costs on the original credit line. Accordingly, no expense was recognized in connection with the transaction.
On August 8, 2021, the Company received $20,000 in cash proceeds from the credit line. During the year ended December 31, 2021, the Company recognized an additional debt discount of $15,362. During the years ended December 31, 2021 and 2020, the Company amortized $7,016 and $20,493 of the discount as interest expense, respectively. As of December 31, 2021, and December 31, 2020, the unamortized discount was $11,100 and $2,754, respectively. The outstanding principal balance on the convertible credit line as of December 31, 2021 and 2020 amounted to $168,328 and $148,328, respectively. See discussion of derivative liability in Note 9 - Derivative Liability.
NOTE 9 - DERIVATIVE LIABILITY
As discussed in Note 1, on a recurring basis, we measure certain financial assets and liabilities based upon the fair value hierarchy. The following table presents information about the Company’s derivative liabilities measured at fair value on a recurring basis as of December 31, 2021 and 2020:
Level 1
Level 2
Level 3
Fair Value at
December 31,
Liabilities
- - - -
Derivative Liability
- - $ 96,369 $ 96,369
F-
Level 1
Level 2
Level 3
Fair Value at
December 31,
Liabilities
- - - -
Derivative Liability
- - $ 145,041 $ 145,041
As of December 31, 2021, and 2020, the Company had a $145,041 and $96,369 derivative liability balance on the consolidated balance sheets, respectively and recorded a loss from derivative liability fair value adjustment of $33,310 and $25,229 during the years ended December 31, 2021 and 2020, respectively. The Company assessed its outstanding convertible credit line payable as summarized in Note 8 - Convertible Credit Line Payable- Related Party and determined certain convertible credit lines payable with variable conversion features contain embedded derivatives and are therefore accounted for at fair value under ASC 920, Fair Value Measurements and Disclosures and ASC 825, Financial Instruments.
Utilizing Level 3 Inputs, the Company recorded fair market value adjustments related to the derivative liability for the year ended December 31, 2020 of $25,229. An additional debt discount of $5,851 was recorded during the year ended December 31, 2020 using the following assumptions: exercise price of $1.00, 19,000 common share equivalents, and a fair value of the common stock of $1.00 per share. The fair market value adjustments as of December 31, 2020 were calculated utilizing the Black-Scholes option pricing model using the following assumptions: exercise price of $1.00, computed volatility 127%, discount rate 0.13%, 148,328 common share equivalents, and a fair value of the common stock of $1.00 per share.
Utilizing Level 3 Inputs, the Company recorded fair market value adjustments related to the derivative liability for the year ended December 31, 2021 of $33,310. An additional debt discount of $15,362 was recorded during the year ended December 31, 2021 using the following assumptions: exercise price of $1.00, 20,000 common share equivalents, and a fair value of the common stock of $1.00 per share. The fair market value adjustments as of December 31, 2021 were calculated utilizing the Black-Scholes option pricing model using the following assumptions: exercise price of $1.00, computed volatility 248.59%, discount rate 0.73%, 168,328 common share equivalents, and a fair value of the common stock of $1.00 per share.
A summary of the activity of the derivative liability is shown below:
Balance at December 31, 2019
$ 65,289
Derivative liabilities recorded
5,851
Loss on change in derivative fair value adjustment
25,229
Balance at December 31, 2020
$ 96,369
Derivative liabilities recorded
15,362
Loss on change in derivative fair value adjustment
33,310
Balance at December 31, 2021
$ 145,041
NOTE 10 - COMMITMENTS AND CONTINGENCIES
Effective November 1, 2018, the Company entered into an employment contract with the President and CFO of the Company. The President will receive an annual salary of $120,000, increasing 10% per year for five years. In addition, the employee will receive $750 per month for health insurance, will receive a year-end bonus of 25,000 shares of the Company stock and will receive a .03125% overriding royalty interest in each future producing well. As of December 31, 2021 and 2020, the Company had $0 and $212,985 accrued compensation related to this contract, respectively.
NOTE 11 - SUBSEQUENT EVENTS
On February 17, 2022, the Company entered into a Purchase and Sale Agreement (“PSA”) with Progressive. Under the terms of the PSA, the Company will acquire leases and related assets to certain oil and gas wells located in Logan County in Central Oklahoma as more fully descried in the PSA. Under the PSA the Company is obligated to make an additional cash payment of $490,000 after giving effect to one hundred and ten thousand dollars previously paid for the option and extension payments (see Note 3), and a further payment of three (3%) percent of the net revenue from new wells drilled until Progressive receives $350,000. The acquired leases under the PSA comprise approximately 2,080 gross acres of developed and undeveloped proven production in the Cherokee Uplift in central Oklahoma, including 34 well bores, six of which are active. On March 9, 2022, the Company closed on the acquisition of 34 well bores and related assets under the PSA. We are entitled to receive the proceeds of production from January 1, 2022 under the terms of the PSA and Progressive is required to operate the properties and transfer ownership and royalty decks to Company following a one-month transition period. Under the PSA we are obligated to make a further payment of three (3%) percent of the net revenue from new wells drilled until Progressive receives an additional $350,000.
F-
On February 25, 2022, the Company entered into secured senior secured convertible note for the purchase and sale of convertible promissory notes (“Convertible Note”) in the principal amount of $5,000,000. The Senior Convertible Note is convertible at any time after the date of issuance into shares of the Company’s common stock at a conversion price of $5.00 per share. Upon conversion of the convertible note into the Company’s common stock, the noteholder would be issued 1,000,000 shares of the Company’s common stock. Interest on the Convertible Note shall be paid to the investors at a rate of 7.25% per annum, paid on a quarterly basis, and the maturity date of the Convertible Note is two years after the issuance date. The Convertible Note is secured by certain oil and gas leases, lands, minerals and other properties of the Company, subject to prior liens and security interests. On the same day, the assigned advances of $413,206 from a related party were transferred to the Convertible Note. As of the date of this filing, the Company has not received in cash proceeds from the convertible note.
On February 23, 2022, the Company amended the December 3, 2020 promissory note with, Mr. Leaver, President of the Company. As amended, the principal balance of note will be $406,750, which includes the original promissory of $65,000, advances of $325,580 and $16,170 in accrued interest. Of the $325,580 in advances, $31,280 were advanced subsequent to December 31, 2021. The promissory note matures on February 23, 2025 and bears interest at 5% per annum. In February 2022, Mr. Leaver advanced the Company an additional $500,000. On February 25, 2022, Mr. Leaver assigned the $406,750 promissory note and $500,000 advance to 20 Shekels, an affiliated Company. On the same day, the assigned promissory note and advance totaling $906,750 were transferred into a secured senior secured convertible note. The convertible note bears interest at 7.25% and matures on February 25, 2024. The note is convertible into shares of the Company at $5.00 per share.
On January 28, 2019, the Company entered into a Project Sale Agreement (the “PSA”) with Visionary Resources, LLC. (“Visionary”). Visionary has developed an oil and gas exploration project in northwestern Texas (the “Battlewagon Project”). The Battlewagon Project includes several prospective areas, and the Company is interested in exploring these areas and utilizing Visionary’s geophysical and other data and expertise. The Company agreed to pay the Project Fee of two hundred thousand dollars ($200,000) by March 31, 2020. The Company and Visionary have entered into various extension agreements, the current one being dated January 4, 2021 (the “Extension Agreement”). On January 1, 2022, the Company entered an Extension Agreement with Visionary, the Company may acquire access to the intellectual property owned or licensed by Visionary for a cash payment of two hundred thousand dollars ($200,000) on or before March 4, 2022. The agreement was further extended to September 2, 2022.
Subsequent to December 31, 2021, the Company has received cash proceeds of $1,231,500 from unexecuted subscription agreements. The unexecuted agreements are to sell common stock at $1.00 per share.
F-

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
We have had no disagreements with our independent auditor on accounting or financial disclosures.

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A (T). CONTROLS AND PROCEDURES.
Our Principal Executive Officer and Principal Financial Officer, John Lepin, evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of the year end covered by this Report. Based on that evaluation, they have concluded that, as of December 31, 2021, our disclosure controls and procedures are designed at a reasonable assurance level and are not effective to provide reasonable assurance that information we are required to disclose in the reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC's rules and forms, and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
Management's Report on Internal Control Over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control, as is defined in the Securities Exchange Act of 1934. These internal controls are designed to provide reasonable assurance that the reported financial information is presented fairly, that disclosures are adequate and that the judgments inherent in the preparation of financial statements are reasonable. There are inherent limitations in the effectiveness of any system of internal controls, including the possibility of human error and overriding of controls. Consequently, an effective internal control system can only provide reasonable, not absolute, assurance with respect to reporting financial information.
Our internal control over financial reporting includes policies and procedures that: (i) pertain to maintaining records that in reasonable detail accurately and fairly reflect our transactions; (ii) provide reasonable assurance that transactions are recorded as necessary for preparation of our financial statements in accordance with generally accepted accounting principles and the receipts and expenditures of company assets are made and in accordance with our management and directors authorization; and (iii) provide reasonable assurance regarding the prevention or timely detection of unauthorized acquisition, use or disposition of assets that could have a material effect on our financial statements.
Management has undertaken an assessment of the effectiveness of our internal control over financial reporting based on the framework and criteria established in the Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO" 2013). Based upon this evaluation, management concluded that our internal controls over financial reporting were not effective as of December 31, 2021.
Based on that evaluation, management concluded that, during the period covered by this report, such internal controls and procedures were not effective due to the following material weakness identified:
☐
Lack of appropriate segregation of duties,
☐
Lack of controls over proper maintenance of records,
☐
Lack of control procedures that include multiple levels of supervision and review, and
☐
There is an overreliance upon independent financial reporting consultants for review of critical accounting areas and disclosures and material, nonstandard transactions.
This annual report does not include an attestation report of the Company’s registered public accounting firm regarding internal control over financial reporting. Management's report was not subject to attestation by the Company’s registered public accounting firm pursuant to rules of the SEC that permit the Company to provide only the management's report in this annual report.
Implemented or Planned Remedial Actions in response to the Material Weaknesses
We will continue to strive to correct the above noted weakness in internal control once we have adequate funds to do so. We believe appointing a director who qualifies as a financial expert will improve the overall performance of our control over our financial reporting.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. 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.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during the quarter ended December 31, 2021 that materially affect, or are reasonably likely to materially affect, our internal control over financial reporting.
The Company’s management, including the principal executive officer and principal financial officer, do not expect that its disclosure controls or internal controls will prevent all errors or all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. In addition, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within a company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake.

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ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
None.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.
Directors and Executive Officers
The names of our director and executive officers as of December 31, 2021 and their ages, positions, and biographies are set forth below. Our executive officers are appointed by, and serve at the discretion of, our board of directors.
Name
Age
Position
John Lepin
Director, CFO
Lacey Kellogg
Director
Richard M. Nummi
Director
Robert J. Flynn, Jr.
Director
Jay S. Leaver
President
Directors, Executive Officers, Promoters and Control Persons
John Lepin, MBA, has over 35 years of experience in accounting, taxation, and management. He has experience in all areas of oil & gas accounting, start-up operations and general management. Prior to joining Alpha Energy, Inc., he consulted with private and public companies. He started his career at Ladd Petroleum, a subsidiary of General Electric and has held controller positions with KC Resources, Royale Energy, Blue Dolphin Energy, Aurora Oil & Gas and Patara Oil & Gas and served as CFO of Grand Gulf Energy.
Lacie Kellogg. Ms. Kellogg has 32 years of accounting experience 24 of which are in the Oil and Gas industry. Her experience is in the areas of Financial Reporting both public and private, domestic and international, Operations Accounting and Software Implementation. Lacie earned her BBA from the University of Houston and has worked with Carrizo Oil and Gas, Aurora Oil & Gas, an Australian based company, and as a private consultant in the energy field. She is a member of COPAS and is active in the local chapter.
Richard M. Nummi, Eaq., has over two decades of professional compliance and regulatory experience. He has been counsel to the Securities and Exchange Commission serving as senior counsel to the office of compliance inspections and examinations where his was quite extensive. Through the years he has headed compliance departments for many financial service entities of significance including Morgan Stanley, Jefferson Pilot, Kemper and others.
Robert J. Flynn, Jr., Esq., is a graduate of Georgetown University School of Foreign Services (B.S.F.S.), a graduate of Georgetown Law Center (J.D.) and a graduate of George Washington National Law Center (L.L.M.). He is a member of the District of Columbia Bar since 1969 and has practiced law both in the District of Columbia and elsewhere since that time.
Jay S. Leaver, age 57, has over 31 years’ experience in geology, geophysics, and geochemistry relative to hydrocarbon exploration and production. He spent most of his career working with Thomasson Partner Associates, Inc. in Denver, working a wide variety of basins and being involved in discoveries in North Dakota, Utah, Colorado, and Idaho. He served as interim President of Sun River Energy, Inc. in 2009 and 2010, then as V.P. Geology through 2012. Afterward he set up an independent prospect and play generation company, Visionary Resources, LLC. He holds a B.Sc. in Geological Engineering from the Colorado School of Mines.
Family Relationships
There are no family relationships among any of our officers or directors.
Indemnification of Directors and Officers
Our Articles of Incorporation and Bylaws both provide for the indemnification of our officers and directors to the fullest extent permitted by Nevada law.
Limitation of Liability of Directors
Pursuant to the Colorado Statutes, our Articles of Incorporation exclude personal liability for our Directors for monetary damages based upon any violation of their fiduciary duties as Directors, except as to liability for any breach of the duty of loyalty, acts or omissions not in good faith or which involve intentional misconduct or a knowing violation of law, or any transaction from which a Director receives an improper personal benefit. This exclusion of liability does not limit any right which a Director may have to be indemnified and does not affect any Director's liability under federal or applicable state securities laws. We have agreed to indemnify our directors against expenses, judgments, and amounts paid in settlement in connection with any claim against a Director if he acted in good faith and in a manner, he believed to be in our best interests.
Election of Directors and Officers
Directors are elected to serve until the next annual meeting of stockholders and until their successors have been elected and qualified. Officers are appointed to serve until the meeting of the Board of Directors following the next annual meeting of stockholders and until their successors have been elected and qualified.
Involvement in Certain Legal Proceedings
No Executive Officer or Director of the Corporation has been the subject of any Order, Judgment, or Decree of any Court of competent jurisdiction, or any regulatory agency permanently or temporarily enjoining, barring suspending or otherwise limiting him/her from acting as an investment advisor, underwriter, broker or dealer in the securities industry, or as an affiliated person, director or employee of an investment company, bank, savings and loan association, or insurance company or from engaging in or continuing any conduct or practice in connection with any such activity or in connection with the purchase or sale of any securities.
No Executive Officer or Director of the Corporation has been convicted in any criminal proceeding (excluding traffic violations) or is the subject of a criminal proceeding which is currently pending.
No Executive Officer or Director of the Corporation is the subject of any pending legal proceedings.
Audit Committee and Financial Expert
We do not have an Audit Committee. Our directors perform functions of an Audit Committee, such as: recommending a firm of independent certified public accountants to audit the annual financial statements; reviewing the independent auditor's independence, the financial statements and their audit report; and reviewing management's administration of the system of internal accounting controls. The Company does not currently have a written audit committee charter or similar document.
We have no financial expert. We believe the cost related to retaining a financial expert at this time is prohibitive. Further, because of our start-up operations, we believe the services of a financial expert are not warranted.
Section 16(a) Beneficial Ownership Reporting Compliance
Section 16(a) of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), requires our executive officers and directors, and persons who beneficially own more than ten percent of an issuer's common stock, which has been registered under Section 12 of the Exchange Act, to file initial reports of ownership and reports of changes in ownership with the SEC. Based upon a review of the copies of such forms furnished to us and written representations from our executive officers and Directors, we believe that as of the date of this filing they were all current in their filings.
Corporate Governance
Nominating Committee
We do not have a Nominating Committee or Nominating Committee Charter. Our Board of Directors perform the functions associated with a Nominating Committee. We have elected not to have a Nominating Committee in that we are an initial-stages operating company with limited operations and resources.

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ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION.
Summary Compensation
Summary Compensation Table
The following table sets forth certain information concerning the annual compensation of our Principal Executive Officer and our other executive officers during the last two fiscal years.
Name &
Principal
Position
Year
Salary
Bonus
Stock
Awards
Option
Awards
Non-equity
incentive plan
compensation
Nonqualified
deferred
compensation
earnings
All Other
Compensation
Total
Compensation
John Lepin,
143,916
73,000
9,000
225,916
CFO, Director
144,000
-
73,000
-
-
-
9,000
226,000
Lacie Kellogg,
48,000
48,000
Director
-
-
48,000
-
-
-
-
48,000
Richard M. Nummi,
48,000
48,000
Director
-
-
48,000
-
-
-
-
48,000
Robert J. Flynn, Jr.,
48,000
48,000
Director
-
48,000
-
-
-
-
48,000
Outstanding Equity Awards at Fiscal Year End.
None
Board Committees
We do not currently have any committees of the Board of Directors. Additionally, due to the nature of our intended business, the Board of Directors does not foresee a need for any committees in the foreseeable future.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.
The following table sets forth, as of December 31, 2021, certain information with respect to the beneficial ownership of shares of our common stock by: (i) each person known to us to be the beneficial owner of more than five percent (5%) of our outstanding shares of common stock, (ii) each director or nominee for director of our Company, (iii) each of the executives, and (iv) our directors and executive officers as a group. Unless otherwise indicated, the address of each shareholder is c/o our company at our principal office address:
Beneficial Owner
Address
Percent of
Class (**)
Number of Shares
Beneficially Owned (*)
AEI Acquisition, LLC
2600 E. Southlake Blvd.,
Suite 120-366
Southlake, TX. 76092
84.36
%
15,880,201
John Lepin, CFO and
Chairman of the Board
4162 Meyerwood Dr
Houston, TX 77025
3.49
%
657,678
Jay Leaver, President and
Director
1.04
%
196,000
Lacie Kellogg, Director
1.57
%
296,000
Richard M. Nummi,, Director
0.89
%
168,000
Robert J. Flynn, Jr., Director
0.89
%
168,000
(*) Beneficial ownership is determined in accordance with the rules of the SEC which generally attribute beneficial ownership of securities to persons who possess sole or shared voting power and/or investment power with respect to those securities. Unless otherwise indicated, voting and investment power are exercised solely by the person named above or shared with members of such person’s household. This includes any shares such person has the right to acquire within 60 days.
(**) Percent of class is calculated on the basis of the number of shares outstanding on December 31, 2021 (18,824,106)
Changes in Control
There are no arrangements, known to the Company, including any pledge by any person of securities of the Company, the operation of which may at a subsequent date result in a change in control of the Company.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPNDENCE.
Director Independence
We currently do not have any independent directors, as the term "independent" is defined in Section 803A of the NYSE Amex LLC Company Guide. Since the OTC Markets does not have rules regarding director independence, the Board makes its determination as to director independence based on the definition of "independence" as defined under the rules of the New York Stock Exchange ("NYSE") and American Stock Exchange ("Amex").

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
(1) AUDIT FEES
The audit fees charged by Malone Bailey, LLP for the years ended December 31, 2021 and 2020 were $62,500 and $35,000, respectively.
(2) AUDIT-RELATED FEES
None.
(3) TAX FEES
None.
(4) ALL OTHER FEES
None.
(5) AUDIT COMMITTEE POLICIES AND PROCEDURES.
We do not have an audit committee. Our Board acts in total as the audit committee
(6) If greater than 50 percent, disclose the percentage of hours expended on the principal accountant's engagement to audit the registrant's financial statements for the most recent fiscal year that were attributed to work performed by persons other than the principal accountant's full-time, permanent employees.
Not applicable.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
(a)
1.
The financial statements listed in the "Index to Financial Statements" at page 30 are filed as part of this report.
2.
Financial statement schedules are omitted because they are not applicable or the required information is shown in the financial statements or notes thereto.
3.
Exhibits included or incorporated herein: See index to Exhibits.
(b) Exhibits
Exhibit
Incorporated by reference
Number
Exhibit Description
Filed
Period
Filing
3.1 Articles of Incorporation
3.2 By-Laws
10.1 Logan Purchase and Sale Agreement dated 12.31.21
10.2 Common subscription document
10.3 Senior secured for $5million raise
10.4 Senior secured CIA for $5 million raise
10.5 John Lepin salary to stock conversion
10.6 John Lepin Assignment to LLC
10.7 Reserve Report pertaining to Logan dated 1.2.2022
10.8 John Lepin BOD agreement
10.9 Richard Nummi Bod Agreement
10.10 Robert J. Flynn BOD agreement
10.11 Lacie Kellogg BOD agreement
10.12 John Lepin Employment contract
10.13 Jay Leaver Engagement Agreement
10.14 Kelloff Oil Engagement Agreement
31.1
Certificate of Principal Executive Officer and Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act
X
32.1
Certification Principal Executive Officer and Principal Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act
X
101.INS
Inline XBRL Instance Document
X
101.SCH
Inline XBRL Taxonomy Extension Schema Document
X
101.CAL
Inline XBRL Taxonomy Extension Calculation Linkbase Document
X
101.DEF
Inline XBRL Taxonomy Extension Definition Linkbase Document
X
101.LAB
Inline XBRL Taxonomy Extension Label Linkbase Document
X
101.PRE
Inline XBRL Taxonomy Extension Presentation Linkbase Document
X
Cover Page Interactive Data File (embedded within the Inline XBRL and contained in Exhibit 101)