TRULEUM, INC. - Annual Report: 2022 (Form 10-K)

ALPHA ENERGY, INC.

FORWARD-LOOKING STATEMENTS

This report contains forward-looking statements. These forward-looking statements are subject to known and unknown risks, uncertainties and other factors which may cause actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These forward-looking statements include, among others, the following:

Forward-looking statements are typically identified by use of terms such as “may”, “could”, “should”, “expect”, “plan”, “project”, “intend”, “anticipate”, “believe”, “estimate”, “predict”, “potential”, “pursue”, “target” or “continue”, the negative of such terms or other comparable terminology, although some forward-looking statements may be expressed differently. The forward-looking statements contained in this report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management’s assumptions about future events may prove to be inaccurate. Management cautions all readers that the forward-looking statements contained in this report are not guarantees of future performance, and we cannot assure any reader that such statements will be realized or the forward-looking events and circumstances will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements. You should consider the areas of risk described in connection with any forward-looking statements that may be made herein. You should also consider carefully the statements under “Risk Factors” and other sections of this report, which address additional factors that could cause our actual results to differ from those set forth in the forward-looking statements. Readers are cautioned not to place undue reliance on these forward-looking statements and readers should carefully review this report in its entirety, including the risks described in "Item 1A. - Risk Factors". Except for our ongoing obligations to disclose material information under the Federal securities laws, we undertake no obligation to release publicly any revisions to any forward-looking statements, to report events or to report the occurrence of unanticipated events. These forward-looking statements speak only as of the date of this report, and you should not rely on these statements without also considering the risks and uncertainties associated with these statements and our business.

Unless specifically set forth to the contrary, when used in this Report the terms “Alpha,” "we", "our", the "Company" and similar terms refer to Alpha Energy, Inc., a Colorado corporation. In addition, when used herein and unless specifically set forth to the contrary, “2022” refers to the year ended December 31, 2022, “2021” refers to the year ended December 31, 2021.

PART I

ITEM 1. BUSINESS.

Overview

Alpha Energy, Inc. (“our”, “we”, the Company) was incorporated in September 26, 2013 in the State of Colorado for the purpose of purchasing, developing and operating oil and natural gas leases.

On February 23, 2018, the Company formed a wholly owned subsidiary, Alpha Energy Texas Operating, LLC (“AETO”). The business of AETO is to maximize production and cash flow from our properties and use that cash flow to explore, develop, exploit and acquire oil and natural gas properties across Texas, Oklahoma and New Mexico. AETO is bonded and insured as an operator in the State of Oklahoma.

On March 9, 2022, we closed on the acquisition of working interests and net revenue interests in leases located in Logan County, Oklahoma, with 34 well bores and related assets, production equipment (tank batteries, pumping units, pipelines) and related assets under a Purchase and Sale Agreement with Progressiveentered on February 17, 2022, located in Logan County, Oklahoma. A working capital interest represents the percentage of costs that we are obligated to pay and net revenue interest represents the percentage of revenue that we will earn from production. In most cases we are responsible for 100% of the working interest and are entitled to receive between 75% and 78% of the production revenue from the Logan Project, with the remainder going to the lessor as an overriding royalty interest per standard oil and natural gas lease terms in this area. Under the Purchase and Sale Agreement, we are entitled to receive the proceeds of production from January 1, 2022 and Progressive was required to operate the properties and transfer ownership and royalty decks to Company following a one-month transition period. Under the Purchase and Sale Agreement, the Company made an additional cash payment to Progressive of $490,000.00 after giving effect to $110,000.00 previously paid in option extension payments under the Option Agreement. The Company is also obligated under the Purchase and Sale Agreement to make a further payment of 3% percent of the net revenue from new wells drilled until Progressive receives an additional $350,000, of which $0 has been paid as of December 31, 2022.

The well bores acquired consist of developed and undeveloped proven production on the Cherokee Uplift in Central Oklahoma. AETO is listed as Operator of 31 of the original 34 wellbores acquired under the terms of the Purchase and Sale Agreement. Two of the 31 wells are on the state’s “Plug or Produce” list, which are wells that are not currently active and which the state has demanded either be put into production or responsibly plugged and abandoned in accordance with applicable regulation. We have reviewed these two wells and have informed the state we will plug them in the first quarter of 2023. Five wells were producing upon acquisition of the Project. We have attempted to restart an additional ten wells so far, with five being successful and five producing uneconomic volumes of water for a total of ten wells currently producing. We have added perforations in the primary producing horizon (Mississippian Lime) in three wells and may attempt hydraulic fracture treatment on one or more of them. We attempted new perforations targeting two behind-pipe zones in one well but were not able to establish production from either zone. We have other behind pipe opportunities (which are zones in a well bore that data indicate should produce hydrocarbons but which have not yet been tested) for which we have applied for necessary Location Exceptions per regulatory requirements and we intend to exploit those opportunities upon approval. We have conducted a preliminary geologic overview of the available data for the remaining wells and identified possible behind pipe opportunities. We have engaged qualified reservoir engineers and are in the process of examining best practices and economics of accessing these zones. We intend to attempt several more recompletions in the second through fourth quarters of 2023. This will include hydraulic stimulation of existing perforations in the Mississippian Lime. Wells that are not currently producing and do not appear to be good candidates for recompletion will need to be plugged and abandoned. We anticipate being able to make such decisions by the end of 2023.

To modernize operations, we have enlisted the services of an environmental engineer to ensure that the Company has a proper Spill Prevention, Containment, and Control plan (“SPCC”) in place for each of our facilities. We have begun the process of meeting their recommendations. We are researching converting two  of our existing wells for saltwater disposal. This may permit us to operate wells that are currently uneconomic because we currently truck the produced wastewater off site for disposal in commercial facilities. A significant amount of saltwater is produced along with oil and natural gas and current methods of disposal are costly.  We also are researching a pipeline system to reduce the number of water trucks visiting the well sites every week and examining the economics of converting our active pumping units to electrical pumps. This would enable us to sell more natural gas (some of which is currently used to run the pumping equipment) and reduce the workload on our pumper personnel because we could control well production remotely.

Oil and natural gas leases provide the Company the ability to produce oil and natural gas on its production sites.  The leases customarily are for a term of three years and as long thereafter as oil and natural gas is produced; and provide for continuing royalty payments of between 1/8% – 1/4%.  The Company believes it possesses appropriate rights under all leases for its current production, however lease defects or disputes may exist or arise in the future which could result in costs to the Company to rectify or result in the Company incurring additional payments to lessors. Due to the fractionalization of the mineral interests under our leases that allow for operations and the necessity of acquiring the lease rights from hundreds of said mineral owners, we believe that no one lease is material to our strategy. 

Impact of COVID-19 Pandemic

Over the past two years the impact of COVID-19 has had adverse effects on our business by slowing down our ability to work with third parties. We have witnessed supply chain related delays and increasing costs due to pandemic related inflation.  It is difficult to predict what other adverse effects, if any, COVID-19 and related matters can have on our business, or against the various aspects of same.

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, contractors or suppliers. In addition, the ability of our employees, contractors 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. 

It is difficult to isolate the impact of the pandemic on our business, results of operations, financial condition and our future strategic plans.

We may experience long-term disruptions to our operations resulting from changes in government policy or guidance; quarantines of employees, customers and suppliers in areas affected by the pandemic and the presence of new variants of COVID-19; and closures of businesses or facilities critical to our business or supply chains. We are actively monitoring, and will continue to actively monitor, the pandemic and the potential impact on its operations, financial condition, liquidity, suppliers, industry and workforce.

For a further discussion of the impact of the COVID-19 pandemic on our business, please see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Impact of COVID-19 Pandemic”.

Our Strategy

Our long-term business strategy is:

•Pursuing accretive, opportunistic acquisitions that meet our strategic and financial objectives. We believe that there is currently a window of opportunity for us to acquire Proved Developed Producing “(PDP”) heavy assets (wells that have been drilled and equipped and are producing marketable hydrocarbons) that also possess sizable undeveloped acreage positions from distressed and/or motivated sellers at an attractive discount to PDP PV-10 valuations. PV-10 is a metric of the time value of money commonly used in oil industry transactions. It represents the net present value of an expected cash flow, discounted at 10% (i.e., the equivalent cash right now that would equal the value of the contemplated cash flow compared to a generic investment earning 10%). Generally, a positive PV-10 may be worth pursuing, while a negative PV-10 is not. Consequently, we currently intend to focus our growth efforts on identifying, evaluating and pursuing the acquisition of such oil and natural gas properties in areas where we currently have a presence and/or specific operating expertise that will position us to enhance our expected acquisition returns through leveraging our operational experience and expertise in order to provide productivity and cost improvements, and where appropriate, increase reserves through development drilling. We may acquire individual properties or private or publicly traded companies, in each case for cash, common stock, preferred stock or a combination thereof. We believe that the historical low commodity pricing environment, and very limited sources of debt and/or equity capital available to our industry, provides significant reserve and cash flow growth opportunities for us.

•Enhancing our existing portfolio by dedicating the majority of our drilling capital to our existing portfolio of oil and liquids-rich opportunities. A key element of our long-term strategy is to continue to develop the oil and natural gas liquids resource potential that we believe exist in numerous formations and to expand our presence in those areas. At this time, we have secured the rights to one development property in the Cherokee uplift, a well-known area with existing equipment and infrastructure and are in the process of modernizing their operations for current revenue generation. In response to the current opportunity to be an asset consolidator in the industry, we plan to limit near-term drilling capital for the foreseeable future to that necessary to fulfill leasehold commitments, preserve core acreage, and where the opportunity exists, to drill where we can add production and cash flow at attractive rates of return. We will, however, continue to evaluate high quality drilling opportunities that have the potential to add significant reserves and cash flow to our portfolio at low finding and development cost, thereby providing returns superior to those generated in the currently active unconventional resource plays. Discuss intended modernization steps and recompletions and reworks.

Our strategy is to acquire and develop additional properties we can restart, rework, and/or recomplete through cash and/or equity transactions. Our strategy is to acquire and develop additional producing properties in the vicinity of the Cherokee Uplift similar to our existing Logan Project that we can restart, rework, recomplete, and which have proven un-drilled potential to produce oil and natural gas. In this manner, our strategy involves acquiring existing infrastructure from historic operations. Deployment of current modern technology to enhance recompletions and drilling in previously undeveloped or underdeveloped areas is part of our strategy to enhance the value of acquired properties.

Production and Reserve Overview

The Company engaged Liquid Gold Technologies, Inc. (“LGT") to evaluate and deliver a Certified SEC Reserves and Valuation Report of the Logan Project. On April 8, 2023, but dated March 27, 2023 and effective January 1, 2023, LGT delivered the report (the “03-23 Report”). LGT utilized publicly available data and data provided by the Company.

According to the LGT Report, the project contains proven net reserves (including producing and non-producing) of 455,670 mcf of gas and 70,800 barrels of oil/condensate with an SEC PV-10 of $5,042,020 based on trailing twelve-month commodity prices of $90.57/bbl oil and $6.344/mbtu natural gas. In addition, the Logan Project contained additional probable net reserves (all non-producing or undeveloped) of 4,645,290 mcf of gas and 1,429,780 barrels of oil/condensate with an additional SEC PV-10 of $73,014,000. Total PV-10% Proved plus Probable using SEC approved pricing parameters was $78,056,020.

After closing of the Logan Project on March 9.2022, it was determined that Seller could not deliver the full list of leases listed in the Purchase and Sale Agreement. A few months thereafter, the Company engaged LGT to provide an updated report based on the actual leases in hand after Closing and better information supplied by the Company on well production in the year prior to Closing. On July 27, 2022, but effective July 1, 2022, LGT delivered the report (the “07-22 Report”).

According to the 07-22 Report, the Logan Project contained total PV-10% Proved plus Probable using SEC approved pricing parameters of $37,636,590. In contrast, the PV-10% Proved plus Probable valuation of the 03-23 Report ($78,056,020) is over twice that of the earlier 07-22 Report. This increase is attributable to (i) an aggressive leasing program by the Company to secure lands that had been part of the original sales package but which Seller was ultimately unable to deliver per the terms of the Purchase and Sale Agreement, (ii) a better price regime in the six months following the 07-22 Report, and (iii) identification of additional Behind Pipe productive zones, although the increase attributable to Behind Pipe zones is partly offset by a more pessimistic assessment of expected production from currently active wells.

The Company sells oil and natural gas on the spot market. It does not have a contractual price nor any delivery commitments. The Company does not have any hedges currently in place. It will explore these and other options for selling its product once volumes have increased.

The Company uses Liquid Gold Technologies Corporation (“LGT”) for annual reserve estimates according to SEC guidelines. LGT is certified to perform such estimates. The Company uses their reports as a guide for size and timing of planned expenditures. It should be noted on the most recent report that the size of the reserves is largely determined by yet-to-be-drilled horizontal wells in the Woodford Shale. The upside potential provided by the Woodford opportunity drove the decision to purchase this project, rather than the known low, late-stage production from the existing wells.

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. Drilling fresh wells without guidance of seismic may risk drilling into an unknown fault zone and potentially losing the well in the event circulation is lost and cannot be restored. 3D seismic is especially important for guiding laterals of a horizontal drilling program: without seismic guidance, there is an increased risk of either running into a fault or simply straying out of the optimal pay zone, resulting in a sub-par or possibly sub-economic well. Additionally, advanced geostatistical techniques enable 3D seismic and modern downhole logs to be used to more accurately map reservoirs and reservoir compartments. The Company is reviewing the cost of 3D seismic, both in terms of dollars and time, to determine whether it is prudent to acquire a survey prior to drilling up to eight horizontal Woodford laterals. With the relatively small acreage block in the Logan Project, we may not be able to permit a large enough survey to acquire good data.

Geological interpretation is based upon data recovered from existing oil and natural 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.

Market for Oil and Gas Production

The market for oil and natural gas production is regulated by both the state and federal governments. Although the overall market is mature, producers are able to market their oil and natural gas through negotiations with purchasers in the area . The purchasers in the area will purchase all crude oil offered for sale at posted field prices, subject to adjustments for quality differences, volume incentives and other variances. The price adjustments for quality differences are based on the benchmark which is Saudi Arabian light crude oil on which Organization of the Petroleum Exporting Countries (“OPEC”) price changes have been based. Quality variances from benchmark crude may result 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 purchaser or oil gatherer will sometimes handle check disbursements to both the working interest and royalty owners. If the purchasers will not handle the check disbursements (as is the case at the Logan Project), we will have to do so or contract with a third party to handle the payments and processing, we are 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 from a well and are not obligated in any manner whatsoever to pay for the costs of operating the lease. Therefore, we will be paying the expenses for the oil and natural gas revenues paid to the royalty and overriding royalty interests. This is standard procedure in the industry. 

Gas sales are made 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 usually 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. As our production levels grow, we intend to enter into price risk management financial instruments (derivatives) to reduce our exposure to short-term fluctuations in the price of natural gas and oil and to protect our return on investments. The derivative contracts apply only to a portion of our natural gas and oil production, provide only partial price protection against declines in natural gas and oil prices and may limit the benefit of future increases in natural gas and oil prices. 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.

The Company, through its wholly-owned subsidiary, AETO, is a party to a Crude Oil Purchase Agreement with Energy Transfer Crude Marketing LLC, or ETC, dated June 7, 2022, pursuant to which the Company sells to ETC all crude oil produced from the Logan Project. The price for the crude oil based on the weighted average price of West Texas Intermediate crude for the trade month, and valued in the trade as Sunoco OK SW crude. The term of the agreement is month-to-month and may be terminated by either party upon 30 days advance written notice.

The Company is a party to a Gathering and Processing Agreement with ETC Pipeline, Ltd., dated August 1, 2022, pursuant to which ETC Pipeline LTD provides certain gathering, processing and related services with respect to gas produced by the Company. The agreement provides that the fees for such services will be set forth in a transaction confirmation to be entered into with respect to the provision of specific services. The term of the Agreement is month-to-month and may be terminated by either party upon 60 days advance written notice.

Seasonality

Winter weather conditions and lease stipulations can limit or temporarily halt the drilling and producing activities of our operating partners and other oil and natural gas operations. These constraints and the resulting shortages or high costs could delay or temporarily halt the operations of our operating partners and materially increase our operating and capital costs. Such seasonal anomalies can also pose challenges for meeting well drilling objectives and may increase competition for equipment, supplies and personnel during the spring and summer months, which could lead to shortages and increase costs or delay or temporarily halt our operating partners’ operations.

Insurance

We maintain insurance coverage at levels and on terms and conditions that we believe to be customary in the oil and natural gas industry. We maintain coverage for commercial general, automobile, and umbrella insurance up to $3,000,000 and for well control, $5,000,000.

Competition

The oil and natural 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 natural gas. In addition, larger companies operating in the same area may be willing or able to offer oil and natural gas at a lower price.

We compete in Oklahoma with over 500 independent companies and approximately 40 significant independent operators including Marathon Oil, Devon Energy, Pioneer Natural Resources, and Mewbourne Oil Company in addition to over 450 smaller operations with no single producer dominating the area. Major operators such as ExxonMobil, Shell Oil, ConocoPhillips, and others that are considered major players in the oil and natural gas industry retain significant interests in Oklahoma.

We believe that we can successfully compete against other independent companies by utilizing the expertise of our staff and 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 natural gas is subject to regulation by state, federal and local authorities. 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 natural 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.

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 Sale

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:

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. In addition, Federal regulation to improve the safety of existing pipeline infrastructure by replacement could increase the cost of interstate transportation. FERC’s 2022 review of its policies relating to natural gas pipeline infrastructure could ultimately increase the cost of approving new interstate capacity or delay new interstate capacity being constructed. These changes affect the economics of natural gas production, transportation and sales. 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.

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. FERC does not regulate the construction of oil and natural gas liquids pipeline facilities, which is left to the states.

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:

Environmental Regulations

General. Our operations are affected by various state, local and federal environmental laws and regulations, including the:

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:

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:

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:

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:

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:

We could also be subject to other damage claims by governmental authorities or third parties related to such contamination.

Climate Change

Significant studies and research have been devoted to climate change, and climate change has developed into a major political issue in the United States and globally.  Certain research suggests that greenhouse gas emissions contribute to climate change and pose a threat to the environment.  Recent scientific research and political debate has focused in part on carbon dioxide and methane incidental to oil and natural gas exploration and production.

In the United States, no comprehensive federal climate change legislation has been implemented to date but the current administration has indicated willingness to pursue new climate change legislation, executive actions or other regulatory initiatives to limit greenhouse gas (“GHG”) emissions. These include rejoining the Paris Agreement treaty on climate change, several executive orders to address climate change, the U.S. Methane Emissions Reduction Action Plan, and a commitment to cut greenhouse gas emissions 50-52 percent of 2005 levels by 2030. Further, legislative and regulatory initiatives are underway to that purpose. The U.S. Congress has considered legislation that would control GHG emissions through a “cap and trade” program and several states have already implemented programs to reduce GHG emissions.  The U.S. Supreme Court determined that GHG emissions fall within the CAA definition of an “air pollutant.” Recent litigation has held that if a source was subject to Prevention of Significant Deterioration (“PSD”) or Title V based on emissions of conventional pollutants like sulfur dioxide, particulates, nitrogen dioxide, carbon monoxide, ozone or lead, then the EPA could also require the source to control GHG emissions and the source would have to install Best Available Control Technology to do so.  As a result, a source may still have to control GHG emissions if it is an otherwise regulated source.

In 2014, Colorado was the first state in the nation to adopt rules to control methane emissions from oil and natural gas facilities. In 2016, the EPA revised and expanded NSPS to include final rules to curb emissions of methane, a greenhouse gas, from new, reconstructed and modified oil and natural gas sources. Previously, already existing NSPS regulated VOCs, and controlling VOCs also had the effect of controlling methane, because natural gas leaks emit both compounds. However, by explicitly regulating methane as a separate air pollutant, the 2016 regulations were a statutory predicate to propose regulating emissions from existing oil and natural gas facilities. In September 2020, EPA made technical and policy changes to the methane rules that limited the scope of the rules. In 2021, President Biden issued Executive Order 13990, Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis. In furtherance of this EO, EPA on November 2, 2021 proposed rules to regulate methane emissions from the oil and natural gas industry, including, for the first time, reductions from certain upstream and midstream existing oil and natural gas sources. These regulations also expanded controls to reduce methane emissions, such as enhancement of leak detection and repair provisions. The Pipeline and Hazardous Materials Safety Administration (“PHMSA”) and the Department of Interior continue to focus on regulatory initiatives to control methane emissions from upstream and midstream equipment. To the extent that these regulations or initiatives remain in place and to the extent that our third-party operating partners are required to further control methane emissions, such controls could impact our business.

In addition, our third-party operating partners are required to report their GHG emissions under CAA rules.  Because regulation of GHG emissions continues to evolve, further regulatory, legislative and judicial developments are likely to occur.  Such developments may affect how these GHG initiatives will impact us.  Moreover, while the U.S. Supreme Court held in its 2011 decision American Electric Power Co. v. Connecticut that, with respect to claims concerning GHG emissions, the federal common law of nuisance was displaced by the CAA, the Court left open the question of whether tort claims against sources of GHG emissions alleging property damage may proceed under state common law. There thus remains some litigation risk for such claims.  Due to the uncertainties surrounding the regulation of and other risks associated with GHG emissions, we cannot predict the financial impact of related developments on us.

Legislation or regulations that may be adopted to address climate change could also affect the markets for our products by making our products more or less desirable than competing sources of energy.  To the extent that our products are competing with higher GHG emitting energy sources, our products would become more desirable in the market with more stringent limitations on GHG emissions.  To the extent that our products are competing with lower GHG emitting energy sources such as solar and wind, our products would become less desirable in the market with more stringent limitations on GHG emissions.  We cannot predict with any certainty at this time how these possibilities may affect our operations.

The majority of scientific studies on climate change suggest that extreme weather conditions and other risks may occur in the future in the areas where we operate, although the scientific studies are not unanimous.  Although operators may take steps to mitigate any such risks, no assurance can be given that they will not have a material adverse effect on our business.

Employees

As of December 31, 2022, we have three contractors, Jay Leaver, our President, Lacie Kellogg, our CFO, Jeffrey Wright, a contract field operations officer, and zero employees. 

Company's Office

Our principal executive office is located at 14143 Denver West Parkway, Suite 100, Golden, CO 80401, where we rent a virtual office from an unrelated third party, on a month-to-month basis, for a nominal amount. The services provided include telephone answering, mail receipt, and paid access to conference rooms. We do not believe that we will need to maintain a physical office at any time in the foreseeable future in order to carry out our plan of operations described herein. 

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. 

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

We may not be successful in producing oil or natural gas from some of our wells.

Ten of our 34 wells are currently producing oil or natural gas. We recently attempted to restart six additional wells but had to shut in five due to uneconomic volumes of water and the sixth did not yield any product. It is unlikely that many of the remaining 18 wells could be economically re-started in the existing completion zones which, as used herein, refers to the Mississippian Lime Formation. Though some of these wells may be candidates for recompletion in alternate zones or depths, we may ultimately need to plug and abandon these wells which could have a material adverse effect on our business, financial condition and operating results.

Acquiring oil and natural gas properties requires us to assess reservoir and infrastructure characteristics, including recoverable reserves, development and operating costs and potential environmental and other liabilities. Such assessments are inexact and inherently uncertain and include properties with which we do not have a long operational history. In connection with the assessments, we intend to perform a review of the subject properties, but such a review will not reveal all existing or potential problems. In the course of our due diligence, we may not inspect every well or pipeline. We cannot necessarily observe structural and environmental problems, such as pipe corrosion, when an inspection is made. We may not be able to obtain contractual indemnities from the seller for liabilities created prior to our purchase of a property. We may be required to assume the risk of the physical condition of properties in addition to the risk that they may not perform in accordance with our expectations. If properties we acquire do not produce as projected or have liabilities, we were unable to identify, we could experience a decline in our reserves and production, which could adversely affect our business, financial condition and results of operations.

We are currently producing a limited amount of oil and natural gas.

We produced a limited amount of oil and natural gas in 2022. Through December 31, 2022 and thereafter, our production was not sufficient to cover our operating expenses, although the production was adequate to cover a majority of our well bore field operations.

We have not completed a detailed geological/geophysical interpretation.

We are currently examining the costs and benefits of conducting a high-quality 3D seismic survey over the field as well as at least one full suite of modern logs because the detailed historical well for the Logan Project (files typically kept by the operator) were lost. Without such data, we are relying on the available logs and completion information available for the state. As a result of using this limited data set, we are more likely to attempt recompleting zones that end up being uneconomic which could have a material adverse effect on our business, financial condition and operating results.

We may utilize detailed geological interpretation combined with advanced seismic exploration techniques to identify the most promising sites within our leases. Seeking fresh wells without guidance of seismic may risk incursion into an unknown fault zone and potentially losing the well in the event circulation is lost and cannot be restored. 3D seismic is especially important for guiding laterals of a horizontal drilling program: without seismic guidance, there is an increased risk of either running into a fault or simply straying out of the optimal pay zone, resulting in a sub-par or possibly sub-economic well. Additionally, advanced geostatistical techniques enable 3D seismic and modern downhole logs to be used to more accurately map reservoirs and reservoir compartments. With the relatively small acreage block in the Logan Project, we may not be able to permit a large enough survey to acquire reliable data. 

We do not currently have any price hedges or other derivatives in place.

We do not currently have any price hedges or other derivatives in place with respect to commodity prices and do not intend to engage in such activities in the near future. As a result, our financial condition and operating results could be adversely affected by fluctuations in commodity prices.

We conduct our own field operations.

We currently conduct all of our field operations through our wholly-owned subsidiary, Alpha Energy Texas Operating, LLC (“AETO”). Although we have a limited history of performing such operations, we believe we can perform these activities less expensively than using a third-party operator. In the event AETO cannot continue as operator (for instance, as a result of an accident or it loses its bond or insurance), then we would be forced to hire an outside operator and there can be no assurance that we would be able to do so or be able to do so on financially acceptable terms.

We are dependent on a single purchaser of our oil.

We sell all of our crude oil to Energy Transfer Crude Marketing LLC (“ETC Marketing”) under a month-to-month agreement which may be terminated by either party upon 30 days advance written notice. In the event this agreement were to be terminated, there can be no assurance that we would be able to continue to sell crude oil produced at the Logan Project or be able to do so on financially acceptable terms. The failure to engage an alternative service provider if we lose the services of ETC Marketing would result in our inability to sell oil. There can be no assurance that ETC Marketing will continue to provide such services or that ETC Marketing or an alternative service provider will be available to provide services on financially acceptable terms. 

We are dependent on a single purchaser of our natural gas.

We sell all of our natural gas to ETC Pipeline, Ltd. (“ETC Pipeline”) under a month-to-month agreement which may be terminated by either party upon 60 days advance written notice. In the event this Agreement were to be terminated, there can be no assurance that we would be able to continue to sell natural gas produced at the Logan Project or be able to do so on financially acceptable terms. The failure to engage an alternative service provider if we lose the services of ETC Pipeline would result in our inability to sell natural gas. There can be no assurance that ETC Pipeline will continue to provide such services or that ETC Pipeline or an alternative service provider will be available to provide services on financially acceptable terms.

We have a limited operating history and limited experience pursuing our strategy and may not be able to operate our business successfully.

We have a limited operating history and limited experience pursuing our strategy. Historical results are not indicative of, and may be substantially different than, the results we achieve in the future. We cannot assure you that we will be able to operate our business successfully, or acquire, restart, rework or recomplete additional oil and natural gas producing properties, or become profitable. The results of our operations depend on several factors, our success in attracting and retaining motivated and qualified personnel, the availability of adequate short and long-term financing, conditions in the financial markets, prices for oil and natural gas resources, and general economic conditions. In addition, our future operating results and financial data may vary materially from historical operating results and financial data because of a number of factors.

We may not be able to continue operating as a going concern.

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 years ended December 31, 2022 and 2021 includes an explanatory paragraph stating the Company has recurring net losses from operations, and a net capital deficiency. 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 $6.9 million as of December 31, 2022. 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 expect losses to continue for the foreseeable future. We also expect that expenses will increase significantly as we seek to operate additional wells at the Logan Project and rework, restart, and recomplete existing wells at the Logan Project and elsewhere following future acquisitions, if any. We may never succeed in implementing our business strategy and, even if we do, we may never generate revenues that are significant or large enough to achieve profitability. If we do achieve profitability, we may not be able to sustain or increase profitability on a quarterly or annual basis. Our failure to become and remain profitable would decrease the value of the Company and could impair our ability to raise capital and acquire and operate additional properties.

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 expect that our planned expansion of business activities 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 operating our properties, take advantage of acquisition opportunities, or restart, rework, or recomplete development projects, or to respond to competitive pressures in the industry which may jeopardize our ability to continue operations.

We have granted a security interest in all of our well bores and other assets relating to the Logan Project to affiliates of our majority stockholder to secure our obligations under secured convertible notes.

In December 2022, the Company and 20 Shekels, Inc. an affiliate of our President Jay Leaver, and AEI Management, Inc., an affiliate of our majority stockholder, AEI Acquisition Company, LLC, entered into Exchange Agreements (the “Exchange Agreements”) with respect to certain outstanding indebtedness of the Company.   Under the Exchange Agreements, the Company entered into a new 7.25% Senior Secured Note Purchase Agreement (the “NPA”), new 7.25% Senior Secured Note due December 31, 2024 (the “7.25% Notes”) and a Security Agreement (the “7.25% Security Agreement”, and together with the NPA and 7.25% Notes, the “7.25% Transaction Documents”).  Under the terms of the Exchange Agreements, 20 Shekels, Inc. was issued a $906,754 principal amount 7.25% Notes and AEI Management, Inc. was issued $413,206 principal amount 7.25% Notes. Pursuant to the Security Agreement, the 7.25% Notes are secured by assets acquired in connection with the Company’s acquisition of the Logan Project, including the 34 well bores relating to the Logan Project, other than the leases.  In the event that we fail in the future to make any required payment under the agreements governing our indebtedness, we would be in default with respect to that indebtedness and the lenders could declare such indebtedness to be immediately due and payable.  Since substantially all of our debt obligations are secured by our assets, upon a default, our lenders may be able to foreclose on our assets, which would result io the cessation of our operations at the Logan project and materially impact our business.

We are subject to the risks relating to start-up oil and natural gas companies, including the risk that our oil and natural gas products may not be saleable to our targeted customers.

Our business is new to the marketplace and as such we have limited information on which to estimate our sales levels, the amount of potential revenue, and our operating and other expenses. While we believe our energy products will meet purchaser specifications and conform to industry standards, we cannot assure that we will be successful in our efforts to market our energy resources as contemplated.

The risks, uncertainties and challenges encountered by start-up companies operating in the oil and natural gas industry include:

• Generating sufficient revenue to cover operating costs and sustain operations;

• Acquiring and maintaining market share;

• Attracting and retaining qualified personnel, especially engineers with the requisite technical skills;

• Successfully developing new locations;

• 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 acquire, explore and develop properties and grow our business, and reach profitability.

The oil and natural 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 natural gas. In addition, larger companies operating in the same area may be willing or able to offer oil and natural gas at a lower price.

We compete in Oklahoma with over 500 independent companies and approximately 40 significant independent operators including Marathon Oil, Devon Energy, Pioneer Natural Resources, and Mewbourne Oil Company in addition to over 450 smaller operations with no single producer dominating the area. Major operators such as ExxonMobil, Shell Oil, ConocoPhillips, and others that are considered major players in the oil and natural gas industry retain significant interests in Oklahoma. 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 come under increased competition from alternative energy sources and conservation could reduce demand for natural gas and oil.

While natural gas provides a capable partner to supplement power generation in times of low wind speed or cloudy weather and gasoline provides an extremely compact, energy-dense, and relatively safe fuel for vehicles, improvements in wind and solar power and especially improvements in battery technology could lead to a decrease in demand for our primary products. There has been a general trend to move toward renewable forms of electric generation and electrification of the transportation industry. Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to natural gas and oil could reduce demand for natural gas and oil. The impact of the changing demand for natural gas and oil services and products may have a material adverse effect on our business, financial condition, results of operations and cash available for distribution.

We may not be able to keep pace with technological advances.

The energy industry in general, and the oil and natural gas 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 natural gas exploration and development. Additionally, technological advances in fuel economy and energy generation devices could reduce demand for natural gas and oil. 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 natural gas leases and wells 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, restarting, reworking, and recompleting 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 acquire new equipment or assets.

Results of our operations depend significantly upon the price and 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 executives may adversely affect our business.

Our business is dependent upon our President Jay Leaver and his affiliated company, Leaverite Exploration and our Chief Financial Officer Lacie Kellogg. Our success is dependent upon the continued availability of Mr. Leaver and Ms. Kellogg, neither of whom have an employment agreement with us. If it became necessary to replace them, it is unlikely new management could be found with the same level of knowledge and experience or at the same or similar cost. The loss of the services of these officers would adversely affect our business.

None of our executives have employment agreements or provisions that would restrict or prohibit them from competing with us and they currently devote only a portion of their time to the business of the Company. As a result, they could terminate their employment and immediately compete against us. The loss of the services of any member of our management team or other key persons could have a material adverse effect on our business, results of operations and financial condition.

None of our executives devotes their full-time efforts to the business of the Company. It is possible that situations may arise in the future where the personal interests of our officers and directors may conflict with our interests. Such conflicts could include determining what portion of their working time will be spent on our business and what portion on other business interests.

Our executive officers and directors will allocate their time to other businesses thereby causing conflicts of interest in their determination as to how much time to devote to our affairs. This conflict of interest could have a negative impact on our business.

Our officers and directors are not required to commit their full time to our affairs, which may result in a conflict of interest in allocating their time between our operations and their other businesses. For example, Jay Leaver, our President, is only required to devote 50% of his time to the Company and Lacie Kellogg, our Chief Financial Officer, serves as chief financial officer and director of several companies. We do not intend to have any full-time employees for the foreseeable future. Each of our officers is engaged in other business endeavors for which they may be entitled to substantial compensation and our officers are not obligated to contribute any specific number of hours per week to our affairs. Our independent directors may also serve as officers or board members for other entities. If our officers’ and directors’ other business affairs require them to devote substantial amounts of time to such affairs in excess of their current commitment levels, it could limit their ability to devote time to our affairs which may have a negative impact on our business.

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 only three contractors and no employees, we are dependent upon the active participation of several key management personnel, including Jay Leaver our President and Lacie Kellogg our Chief Financial Officer Each of these executives are critical to the strategic direction and overall management of our company as well as execution of our strategy. The loss of any of them could adversely affect our business, financial condition, and operating results. We do not carry key person life insurance.

We will need to hire and retain highly skilled technical personnel in order to pursue our strategy and grow our business. The competition for highly skilled technical, managerial, and other personnel is intense. Our recruiting and retention success is substantially dependent upon our ability to offer competitive salaries and benefits. We must compete with companies that possess greater financial and other resources than we do and that may be more attractive. To be competitive, we may have to increase the compensation, bonuses, stock options and other fringe benefits we offer in order to attract and retain such personnel. The costs of retaining or attracting 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, environmental or conservation lawsuits and lawsuits by government, environmental groups, consumers, 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 or licenses, 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 failure to continue to actively utilize our leases. 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.

We develop and sell resources where insurance or indemnification may not be available, including:

Certain of our activities are inherently dangerous and could result in loss of life or property damage. Certain products may raise questions with respect to issues of environmental harm or injury, trespass, conversion and similar concepts, which may raise complex legal issues. Indemnification to cover potential claims or liabilities resulting from a failure may be available in certain circumstances, but not in others. The insurance we maintain may not be adequate to protect against all our risks and uncertainties. Claims resulting from an accident, failure, environmental damage 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, failure, environmental damage or liability, 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 operate.

Our strategy may not be successful.

We intend to expand our operations and 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 operators, mineral rights owners, and surface owners, and satisfy legal and regulatory requirements, as we encounter uncertainty about implementation of our strategies and capabilities, unfamiliarity with our operating methods, and competition. We may not be successful in our proposed business activities.

We may be unable to generate sufficient revenue from our leases to achieve and sustain profitability.

At present, we rely solely on our Logan Project to generate revenue and we expect to substantially generate all our revenue in the foreseeable future from these assets, which is currently inadequate to cover our costs. We will need to continue to expand our efforts to develop new relationships and expand existing relationships with lessors and energy production capabilities, to achieve and maintain compliance with all applicable regulatory requirements, and to develop additional locations that will generate cashflow. If we fail in these efforts we may never receive a return on the substantial investments in leases, production, distribution and environmental and, regulatory compliance we have made, and will make in the future, which may cause us to fail to generate revenue and achieve profitability.

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 energy 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, cold weather events, or other disaster (such as a major flood, tsunami, volcanic eruption, or terrorist attack) affecting our facilities, or those of our suppliers or pipelines, could significantly disrupt our operations, and delay or prevent product shipment or installation during the time required to repair, rebuild, or replace our suppliers’ damaged manufacturing facilities; these delays could be lengthy and costly. If any of our customers’ facilities are negatively impacted by a disaster, shipments of our products could be delayed. Additionally, customers may delay purchases of our products until operations return to normal. 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.

The near-term effects of the recent COVID-19 coronavirus pandemic are known, as they adversely affected our business. Some long- term effects, such as supply chain issues and inflation, are becoming known and may adversely affect our business, results of operations, financial condition, liquidity and cash flow.

Over the past two years the impact of COVID-19 has had adverse effects on our business by slowing down our ability to work with third parties. We have witnessed supply chain related delays and increasing costs due to inflation. It is difficult to predict what other adverse effects, if any, COVID-19 and related matters can have on our business, or against the various aspects of same.

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, contractors or suppliers. In addition, the ability of our employees, contractors 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.

On January 30, 2020, the World Health Organization (“WHO”) announced a global health emergency caused by a new strain of the coronavirus (“COVID-19”) and advised of the risks to the international community as the virus spread globally. In March 2020, the WHO classified the COVID-19 outbreak as a pandemic based on the rapid increase in exposure globally. The spread of COVID-19 coronavirus caused public health officials to recommend precautions to mitigate the spread of the virus, especially as to travel and congregating in large numbers. Over time, the incidence of COVID-19 and its variants has diminished although periodic spikes in incidence occur. Consequently, restrictions imposed by various governmental health organizations may change over time. Several states have lifted restrictions only to reimpose such restrictions as the number of cases rise and new variants arise.

It is difficult to isolate the impact of the pandemic on our business, results of operations, financial condition and our future strategic plans.

The Company may experience long-term disruptions to its operations resulting from changes in government policy or guidance; quarantines of employees, customers and suppliers in areas affected by the pandemic and the presence of new variants of COVID-19; and closures of businesses or manufacturing facilities critical to its business or supply chains. The Company is actively monitoring, and will continue to actively monitor, the pandemic and the potential impact on its operations, financial condition, liquidity, suppliers, industry and workforce.

We may be negatively impacted by inflation.

Increases in inflation could have an adverse effect on us. Current and future inflationary effects may be driven by, among other things, supply chain disruptions and governmental stimulus or fiscal policies, and geopolitical instability, including the ongoing conflict between the Ukraine and Russia. Continuing increases in inflation could increase our costs of labor and other costs related to our business, which could have an adverse impact on our business, financial position, results of operations and cash flows. Inflation has also resulted in higher interest rates in the U.S., which could increase our cost of debt borrowing in the future.

We may be negatively impacted by the seasonality of our business.

Winter weather conditions and lease stipulations can limit or temporarily halt restart, rework and recompletion activities and producing activities for oil and natural gas operations. These constraints and the resulting shortages or high costs could delay or temporarily halt the operations and materially increase our operating and capital costs. Such seasonal anomalies can also pose challenges for meeting objectives and may increase competition for equipment, supplies and personnel during the spring and summer months, which could lead to shortages and increase costs or delay or temporarily halt our operations.

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 we could utilize for capital expenditures and our ability to borrow and raise additional capital.

The supply of and demand for oil and natural gas impact the prices we realize on the sale of these commodities and, in turn, materially affect our financial results. Our revenues, operating results, cash available for distribution and the carrying value of our oil and natural gas depend significantly upon the prevailing prices for oil and natural gas. Oil and natural gas prices have historically been, and will likely continue to be, volatile. The prices for oil and natural gas are subject to wide fluctuation in response to a number of factors beyond our control, including:

Sustained material declines in oil or natural gas prices may have the following effects on our business:

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.

In addition to oil and natural gas, most producing wells also produce saltwater, wastewater, brine, or produced water. We dispose of large volumes of saltwater produced in connection with our drilling and production, pursuant to permits issued to us by governmental authorities. While these permits are issued under existing laws and regulations, these 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 consensus 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’ performance 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. 

Magnitude 2.5 — OCC contacts the operator, discusses mitigation plan, operations may continue

Magnitude 3.0 — required minimum six-hour pause, technical call with OCC regarding mitigations, operations continue with an approved and revised completion plan

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

Restrictions on disposal well volumes or a lack of sufficient disposal wells, the filing of lawsuits, or curtailment or restrictions on oil and natural 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 strategy that are greater than cash flows from operations. Limited liquidity would likely negatively impact our ability to execute our business plan.

Our capital investment needs exceed our historical and 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 acquisitions and restart, rework and recomplete activities including activities required 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 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 filing. 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. In addition, in the past, we often have increased our capital budget during the year as a result of acquisitions or changes in drilling plans. Alternatively, we may have to reduce capital expenditures, and our ability to execute our business plans could be adversely affected, if:

Actual quantities of oil and natural gas reserves and future cash flows from those reserves will most likely vary from our estimates.

It is not possible to accurately measure underground accumulations of oil and natural gas. 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, operating and development costs, future prices of these commodities, the effect of government regulation, taxes and availability of funds. The accuracy of a reserve estimate is a function of:

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. If any of these assumptions prove to be incorrect, our estimates of reserves, the classifications of reserves based on risk of recovery and our estimates of the future net cash flows from our reserves could change significantly.

In accordance with SEC reporting rules, we calculate the estimated discounted future net cash flows from proved reserves using the SEC’s pricing methodology for calculating proved reserves, adjusted for market differentials and costs in effect at year end discounted at 10% per annum. 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. Over time, we may make material changes to reserve estimates to take into account changes in our assumptions and the results of actual development and production. In addition, actual production rates for future periods may vary significantly from the rates assumed in the calculation. Moreover, the 10% discount factor used when calculating discounted future net cash flows, in compliance with the FASB statement on oil and natural gas producing activities disclosures, may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with the Company, or the oil and natural gas industry in general. You should not assume that the present value of future net cash flows is the current market value of our proved reserves.

The reserve estimates made for fields that do not have a lengthy production history are less reliable than estimates for fields with lengthy records. A lack of production history may contribute to inaccuracy in our estimates of proved reserves, future production rates and the timing of development expenditures. Further, our lack of knowledge of all individual well information known to the well operators such as incomplete well stimulation efforts, restricted production rates for various reasons and up-to-date well production data, etc. may cause differences in our reserve estimates.

To grow our production and cash flows, we must continue to develop existing reserves and locate or acquire new reserves.

Currently, our reserves are limited. However, our strategy is to grow our production and cash flows. As we produce oil and natural gas, our reserves decline. Unless we successfully replace reserves through acquisitions or other means 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.

Our future success depends on developing our existing inventory of mineral acreage and acquiring additional mineral interests. Failure to develop our existing inventory of mineral acreage and to acquire additional mineral interests will cause reserves and production to decline materially from their current levels.

The rate of production from natural gas and oil properties generally declines as reserves are depleted. Our proved reserves will decline materially as reserves are produced except to the extent that we acquire additional mineral interests on properties containing proved reserves and our lessees or well operators conduct additional successful exploration and development drilling, successfully apply new technologies or identify additional behind-pipe zones (different productive zones within existing producing well bores) or secondary recovery reserves.

Developing natural gas and oil invariably involves unprofitable efforts, not only from dry wells, but also from wells that are productive but do not produce sufficient reserves to return a profit after deducting drilling, completion, operating and other costs. In addition, wells that are profitable may not achieve a targeted rate of return. We rely on third-party operators’ interpretation of seismic data and other advanced technologies in identifying prospects and in conducting exploration and development activities. Nevertheless, prior to drilling a well, the seismic data and other technologies used do not allow operators to know conclusively whether natural gas, oil or NGL is present in commercial quantities.

Cost factors can adversely affect the economics of any project, and the eventual cost of drilling, completing and operating a well is controlled by well operators and existing market conditions. Further, drilling operations may be curtailed, delayed or canceled as a result of numerous factors, including:

• unexpected drilling conditions;

• title problems;

• pressure or irregularities in formations;

• equipment failures or accidents;

• fires, explosions, blowouts and surface cratering;

• availability to market production via pipelines or other transportation;

• adverse weather conditions;

• environmental hazards or liabilities;

• lack of water disposal facilities;

• governmental regulations;

• cost and availability of drilling rigs, equipment and services; and

• expected sales price to be received for natural gas, oil or NGL produced from the wells.

Competition for acquisitions of mineral interests may increase the cost of, or cause us to refrain from, completing acquisitions. Our ability to complete acquisitions is dependent upon, among other things, our ability to obtain debt and equity financing and, in some cases, regulatory approvals. Further, these acquisitions may be in geographic regions in which we do not currently hold properties, which could result in unforeseen operating difficulties. In addition, if we enter into new geographic markets, we may be subject to additional and unfamiliar legal and regulatory requirements. Compliance with regulatory requirements may impose substantial additional obligations on us and our management, cause us to expend additional time and resources in compliance activities and increase our exposure to penalties or fines for non-compliance with such additional legal requirements. Further, the success of any completed acquisition will depend on our ability to effectively integrate the acquired business or assets into our existing operations. The process of integrating acquired businesses or assets may involve unforeseen difficulties and may require a disproportionate amount of our managerial and financial resources. In addition, possible future acquisitions may be larger and for purchase prices significantly higher than those paid for earlier acquisitions.

No assurance can be given that we will be able to identify suitable mineral interest acquisition opportunities, negotiate acceptable terms, obtain financing for acquisitions on acceptable terms or successfully acquire identified targets. Our failure to achieve consolidation savings, to integrate the acquired businesses and assets into our existing operations successfully or to minimize any unforeseen operational difficulties could have a material adverse effect on our financial condition, results of operations and cash available for distribution. The inability to effectively manage the integration of acquisitions could reduce our focus on subsequent acquisitions and current operations, which, in turn, could negatively impact our growth, results of operations and cash available for distribution.

Any acquisition of additional mineral and royalty interests that we complete will be subject to substantial risks.

Any acquisition involves potential risks, including, among other things:

Lower oil and natural 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 natural gas producing activities. Under this method, all costs incurred in the acquisition, exploration and development of oil and natural gas properties are capitalized into cost centers. The net capitalized costs of our oil and natural gas properties may not exceed the present value of estimated future net revenues from proved reserves, discounted at 10% per annum, plus the lower of cost or fair value of unproved properties. If net capitalized costs of our oil and natural 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. 

All long-lived assets, principally our natural gas and oil properties, are monitored for potential impairment when circumstances indicate that the carrying value of the asset on our books may be greater than our future net cash flows. The need to test a property for impairment may result from declines in natural gas and oil sales prices or unfavorable adjustments to natural gas and oil reserves. The decision to not participate in future development on our leasehold acreage can trigger a test for impairment. Also, once assets are classified as held for sale, they are reviewed for impairment. Because of the uncertainty inherent in these factors, we cannot predict when or if future impairment charges will be recorded.

The risk that we will be required to further impair the carrying value of our oil and natural 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. If an impairment charge is recognized, cash flow from operating activities is not impacted, but net income and, consequently, stockholders’ equity are reduced. In periods when impairment

Restarting, Reworking and Recompleting is a costly and high-risk activity.

In addition to the numerous operating risks described in more detail below, the restarting, reworking and recompleting of wells involves the risk that no commercially productive oil or natural gas reservoirs will be encountered. The seismic data and other technologies we use do not allow us to know conclusively if 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 restarting, reworking or recompleting and producing wells. Furthermore, our operations may be curtailed, delayed or canceled as a result of a variety of factors, including:

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 restart, rework and recompletion 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 natural gas business involves many operating risks that can cause substantial losses.

Our oil and natural gas acquisition and production strategy is subject to all of the operating risks associated with drilling for and producing oil and natural gas, including the risk of:

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:

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 damage, 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 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 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. 

A significant amount of our total estimated 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 may significantly reduce the quantity and present value of our natural gas and oil reserves which would 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 natural gas wells.

Hydraulic fracturing is an essential and common practice in the oil and natural 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 natural 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 natural 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 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 if employed to produce commercial quantities of natural gas and oil from many reservoirs requires the use and disposal of significant quantities of water. In certain regions, there may be insufficient local capacity to provide a source of water for our 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. 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 and refining facilities. We deliver oil and natural gas through gathering systems and pipelines that we do not own and which are operated by a sole source. The lack of alternatives or 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. 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. Also, the shipment of our or our operators’ natural gas and oil on third-party pipelines may be curtailed or delayed if it does not meet the quality specifications of the pipeline owners. The curtailments arising from these and similar circumstances may last from a few days to several months. In many cases, we or our operators are provided only with limited, if any, notice as to when these circumstances will arise and their duration.

Any significant curtailment in gathering system or transportation, processing or refining-facility capacity could reduce our or our operators’ ability to market oil production and have a material adverse effect on our financial condition, results of operations and cash distributions to stockholders. Our or our operators’ access to transportation options and the prices we or our operators receive can also be affected by federal and state regulation—including regulation of oil production, transportation and pipeline safety—as well as by general economic conditions and changes in supply and demand. 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. . Federal regulation to improve the safety of existing pipeline infrastructure by replacement could increase the cost of interstate transportation. FERC’s 2022 review of its policies relating to natural gas pipeline infrastructure could ultimately increase the cost of approving new interstate capacity or delay new interstate capacity being constructed. 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 natural 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, in addition to the other matters discussed under the caption "Regulation" in Items 1 and 2 of this report:

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, including pipelines.

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 natural gas companies. Such legislative changes have included, but not been limited to:

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 natural 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 natural 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 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 natural 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 natural gas companies, major oil and natural gas companies, independent oil and natural 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 natural 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.

Periodically, there are 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 natural gas industry in recent periods have led to declining costs of some oilfield equipment, services, and supplies. However, if the current oil and natural 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 also "— The oil and natural 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 includes 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 natural 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 face various risk associated with the long-term trend toward increased activism against oil and natural gas exploration and development activities.  

Opposition toward oil and natural gas production has been growing globally. Companies in the oil and natural 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:

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 natural 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:

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 natural gas industry has become increasingly dependent upon digital technologies to conduct day-to-day operations including certain exploration, development and production activities. We have entered into agreements with third parties for hardware, software, telecommunications and other information technology services in connection with our business. In addition, we have 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, floods 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, floods, cold weather events, 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 natural 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, floods, cold weather events, 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 natural 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.

We therefore may become subject to various laws and regulations pertaining to Native American oil and natural gas leases, fees, taxes and other burdens, obligations and issues unique to oil and natural gas operations within Native American reservations. One or more of these Native American requirements, or delays in obtaining necessary approvals or permits necessary to operate on tribal lands pursuant to these regulations, may increase our costs of doing business on Native American tribal lands and have an impact on the economic viability of any well or project on those lands.

The conflict in Ukraine and related price volatility and geopolitical instability could negatively impact our business. 

In late February 2022, Russia launched significant military action against Ukraine. The conflict has caused, and could intensify, volatility in natural gas, oil and NGL prices, and the extent and duration of the military action, sanctions and resulting market disruptions could be significant and could potentially have a substantial negative impact on the global economy and/or our business for an unknown period of time. There is evidence that the increase in crude oil prices during the first half of calendar year 2022 was partially due to the impact of the conflict between Russia and Ukraine on the global commodity and financial markets, and in response to economic and trade sanctions that certain countries have imposed on Russia. Any such volatility and disruptions may also magnify the impact of other risks described in this “Risk Factors” section. 

Risks Related to Our Common Stock

General securities market uncertainties resulting from the COVID-19 pandemic.

Since the outset of the pandemic the United States and worldwide national securities markets have undergone unprecedented stress due to the uncertainties of the pandemic and the resulting reactions and outcomes of government, business and the general population. These uncertainties have resulted in declines in all market sectors, increases in volumes due to flight to safety and governmental actions to support the markets. As a result, until the pandemic has stabilized, the markets may not be available to the Company for purposes of raising required capital. Should we not be able to obtain financing when required, in the amounts necessary to execute on our plans in full, or on terms which are economically feasible we may be unable to sustain the necessary capital to pursue our strategic plan and may have to reduce the planned future growth and/or scope of our operations.

General securities market uncertainties resulting in geo-political considerations.

Since the outset of the military conflict in Ukraine, the United States and worldwide national securities markets have undergone unprecedented stress due to the uncertainties of that conflict and the resulting reactions and outcomes of governments, businesses, and the general population. These uncertainties have resulted in declines in all market sectors, increases in volumes due to flight to safety and governmental actions to support the markets. As a result, until the military conflict has stabilized, the markets may not be available to the Company for purposes of raising required capital. Should we not be able to obtain financing when required, in the amounts necessary to execute on our plans in full, or on terms which are economically feasible, we may be unable to sustain the necessary capital to pursue our strategic plan and may have to reduce the planned future growth and/or scope of our operations.

General securities market uncertainties resulting in economic considerations.

Recent unease regarding the geo-political considerations and increasing inflation has caused the United States and worldwide national securities markets to have undergone unprecedented stress due to the uncertainties of regarding the economy and the resulting reactions and outcomes of governments, businesses, and the general population. These uncertainties have resulted in declines in all market sectors, increases in volumes due to flight to safety and governmental actions to support the markets. As a result, until economic outlook has stabilized, the markets may not be available to the Company for purposes of raising required capital. Should we not be able to obtain financing when required, in the amounts necessary to execute on our plans in full, or on terms which are economically feasible, we may be unable to sustain the necessary capital to pursue our strategic plan and may have to reduce the planned future growth and/or scope of our operations.

Our management and controlling stockholder, AEI Acquisition Company, LLC, has voting control of the Company.

Our controlling stockholder, AEI Acquisition Company, LLC, currently owns approximately 74% of the total issued and outstanding common stock of the Company and our officers and directors own approximately 2.96% of our common stock (exclusive of shares of our common stock underlying the 7.25% Notes held by affiliates of Harry McMillan, who maintains sole voting and investment power over AEI Acquisition Company, LLC, which are subject to beneficial ownership blockers). AEI and management are able to influence the outcome of all corporate actions requiring approval of our stockholders, 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, which may discourage stockholders from bringing a lawsuit against directors for breach of their fiduciary duties, or from bringing derivative litigation against our directors and officers.

Our Bylaws provide that we will indemnify any director, officer, employee or agent of the corporation, or any person serving in any such capacity of any other entity or enterprise at the request of the corporation, against any and all legal expenses (including attorneys' fees), claims and/or liabilities arising out of any action, suit or proceeding, except an action by or in the right of the corporation. The corporation may, but shall not be required to, indemnify any person where such person acted in good faith and in a manner reasonably believed to be in or not opposed to the best interests of the corporation and, with respect to any criminal action or proceeding, where there was not reasonable cause to believe the conduct was unlawful. The termination of any action, suit or proceeding by judgment, order or settlement, conviction, or upon a plea of nolo contendere or its equivalent, shall not, of itself, create a presumption that the person did not act in good faith and in a manner reasonably believed to be in or not opposed to the best interests of the corporation, and that, with respect to any criminal action or proceeding, there was reasonable cause to believe that the conduct was unlawful. The corporation shall reimburse or otherwise indemnify any director, officer, employee, or agent against legal expenses (including attorneys' fees) actually and reasonably incurred in connection with defense of any action, suit, or proceeding herein above referred to, to the extent such person is successful on the merits or otherwise. Indemnification shall be made by the corporation only when authorized in the specific case and upon a determination that indemnification is proper by the stockholders, a majority vote of a quorum of the Board of Directors, consisting of directors who were not parties to the action, suit, or proceeding, or independent legal counsel in a written opinion, if a quorum of disinterested directors so orders or if a quorum of disinterested directors so orders or if a quorum of disinterested directors cannot be obtained. 

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 that need to be addressed in our internal control over financial reporting, disclosure of management’s assessment of our internal controls over financial reporting or disclosure of our public accounting firm’s attestation to or report on management’s assessment of our internal controls over financial reporting may have an adverse impact on the price of our Common Stock.

Management recently undertook an assessment of the effectiveness, as of December 31, 2022, 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 that evaluation, management concluded that our internal controls over financial reporting were not effective as of December 31, 2022.

Based on that evaluation, management concluded that, for the year ended December 31, 2022, such internal controls and procedures were not effective due to the following material weakness identified:

In addition, discovery and disclosure of a material weakness in the future or our inability to cure the material weakness we previously discovered and disclosed, by definition, could have a material adverse impact on our financial statements. Such an occurrence could negatively affect our business and affect how our stock trades. This could, in turn, negatively affect our ability to access public equity or debt markets for capital.

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, depend 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.

An active, liquid trading market for our common stock does not exist and if an active market were to develop, the price of our common stock may be volatile.

There is no meaningful public market for our common stock although our common stock is quoted on the OTC Pink Open Markets. The lack of an active market may impair 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 price of shares of common stock. An inactive market may impair our ability to raise capital by selling shares and our ability to use our capital stock to acquire other companies or technologies.

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 stockholder 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 are 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 are 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 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:

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.

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.

AEI Acquisition Company, LLC currently owns approximately 74% of the outstanding shares of our common stock. If it, or any other of our stockholders, sells substantial amounts of our common stock in the public market upon the expiration of any statutory holding period or otherwise, or issued upon the exercise of outstanding warrants or other rights to receive common stock, 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. Under the terms of a Purchase and Sale Agreement with Pure Oil & Gas, Inc. and ZQH Holding, LLC entered June 25, 2020 for the purchase of oil and natural gas assets in Rogers County, Oklahoma, the Company recorded $1,210,000 of convertible debt which is convertible into common stock at $1.00 per share. The Company has disputed its obligation to pay any further amounts under the Purchase and Sale Agreement due to the seller’s failure to perform. In the event that the seller prevailed and was able to convert its debt into common stock, the Company could be required to issue additional shares of its common stock which constitutes additional overhang and could have the effects described above.

Our common stock may become subject to the “penny stock” rules of the SEC, which would make transactions in our stock cumbersome and may reduce the value of an investment in our stock.

The SEC has adopted rules that regulate broker-dealer practices in connection with transactions in penny stocks. Penny stocks are generally equity securities with a price of less than $5.00, other than securities registered on certain national securities exchanges or authorized for quotation on certain automated quotation systems, provided that current price and volume information with respect to transactions in such securities is provided by the exchange or system. If we do not obtain a listing on the NYSE American Stock Exchange or another national securities exchange and if the price of our common stock is less than $5.00, our common stock could be deemed a penny stock. The penny stock rules require a broker-dealer, before a transaction in a penny stock not otherwise exempt from those rules, to deliver a standardized risk disclosure document containing specified information. In addition, the penny stock rules require that before effecting any transaction in a penny stock not otherwise exempt from those rules, a broker-dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive (i) the purchaser’s written acknowledgment of the receipt of a risk disclosure statement; (ii) a written agreement to transactions involving penny stocks; and (iii) a signed and dated copy of a written suitability statement. These disclosure requirements may have the effect of reducing the trading activity in the secondary market for our common stock, and therefore stockholders may have difficulty selling their shares.

ITEM 1B. UNRESOLVED STAFF COMMENTS.

None.

ITEM 2. DESCRIPTION OF PROPERTY.

Corporate Office

Our principal executive office is located at 14143 Denver West Parkway, Suite 100, Golden, CO 80401 , where we rent a virtual office from an unrelated third party, on a month-to-month basis, for a nominal amount. The services provided include telephone answering, mail receipt, and paid access to conference rooms.

ITEM 3. LEGAL PROCEEDINGS.

None 

ITEM 4. MINE SAFETY DISCLOSURES.

Not applicable to our operations.

PART II

ITEM 5. MARKET FOR COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND SMALL BUSINESS ISSUER PURCHASE OF EQUITY SECURITIES.

Market Information.

Our common stock is currently quoted on the OTC Pink Open Markets under the symbol APHE.

Because we are quoted on the OTC Pink Open Markets, our securities may be less liquid, receive less coverage by security analysts and news media, and, therefore, may reflect lower prices than might otherwise be obtained if the shares were listed on a national securities exchange.

The following table sets forth the high and low bid quotations for our common stock as reported on the OTC Pink Open Markets for the periods indicated.

Holders

As of April 17, 2023, there are 130 record holders of our common stock.

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 April 17, 2023, there were 21,653,326 shares of common stock outstanding held by 130 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.

ITEM 6. SELECTED FINANCIAL DATA.

None.

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

Overview

The Company was incorporated in the State of Colorado on September 26, 2013.

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.” 

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, 2022 Compared to the Year Ended December 31, 2021

During the years ended December 31, 2022 and 2021, the Company generated revenues of $270,627 and $3,839. The increase in revenue was due to acquired percentage working interests and net revenue interests in the Logan Project.

Lease operating expenses were $573,770 for the year ended December 31, 2022 compared to $15,652 for 2021. The increase in oil and gas sales and lease operating expenses was due to an increase in Alpha Energy Texas operations.

Operating expenses were $1,256,702 for the year ended December 31, 2022 compared to $894,498 for 2021. The change was primarily attributable to an increase of $310,849 in professional expenses related to the engagement of new legal and audit firms. In addition, there was an increase in gain on accounts payable of $120,250 related to the Company recording a gain on accounts payable of $0 and $120,250 during the years ended December 31, 2022 and 2021, respectively. These changes were offset by decreases of $36,000 in board of director fees and a decrease of $32,895 in general and administrative expenses.

Other expense was $22,704 for the year ended December 31, 2022 compared to other expense of $164,427 for 2021. The change was attributable to a $194,416 gain on change in fair value of derivative liabilities due to the payoff of a convertible note in 2022, which was offset by a $63,299 increase in interest expense.

During the year ended December 31, 2022, the Company recognized a net loss of $1,582,549 compared to $1,070,738 for the year ended December 31, 2021.

Liquidity and Capital Resources

Overview –

Liquidity describes the ability of a company to generate sufficient cash flows to meet the cash requirements of its business operations, including working capital needs, debt services, acquisitions, contractual obligations and other commitments. As of the date of this filing, we have yet to generate meaningful revenue from our business operations and have funded acquisitions, capital expenditure and working capital requirement through equity and debt financing.

As of December 31, 2022, we had total current assets of $208,544 and total current liabilities of $1,737,933. We have historically funded our operations from lines of credit, sales of equity securities, loans and advances, including from related parties.

As of December 31, 2022, our revenues have been inadequate to cover our operating costs. Accordingly, we expect we will be dependent on obtaining capital from external sources to fund our operations over the next two to three years. Although we have been successful in raising capital in the past, financing may not be available on terms favorable to us, if at all, so we may not be successful in obtaining additional financing. Therefore, it is not considered probable, as defined in applicable accounting standards, that our plan to raise additional capital will alleviate the substantial doubt regarding our ability to continue as a going concern. 

Cash Flows –

The following table summarizes our cash flows from operating, investing and financing activities for the periods presented.

Cash flows from operating activities

Our cash flows used in operating activities to date have been primarily comprised of costs related to pursuing acquisitions and general and administrative activities as a result of operating as a public company, which we expect to increase.

Net cash used in operating activities was $1,463,814 and $356,892 for the years ended December 31, 2022 and 2021, respectively. The increase in net cash flows used in operating activities as compared to the same period in 2021 is primarily driven by our signing of the Logan 1 acquisition in March 2022 and preparation for oil and natural gas related production activities thereafter. 

Cash flows from investing activities

Our cash flows from investing activities have been comprised primarily of purchases of equipment and installation of improvements to our leased facilities.

Net cash used in investing activities was $1,387,449 and $95,791 for the years ended December 31, 2022 and 2021, respectively. The increase was primarily due to the acquisition of oil and natural gas property during the year ended December 31, 2022.

Cash flows from financing activities

We have financed our operations primarily through sales of equity securities, loans and advances, including from related parties.

Net cash provided by financing activities was $2,946,408 and $452,900 for the years ended December 31, 2022 and 2021, respectively. The increase is comprised of $120,236 in proceeds from advances, from related parties, $500,000 from senior secured convertible notes payable from related party and $2,504,500 in proceeds from the sale of common stock, which were offset by repayments on the Convertible Credit Line of $168,328 and $10,000 repayments of advances, related party. The Company generated cash of $452,900 from financing activities during the year ended December 31, 2021 which consisted of $427,900 advances, related party, related party, $20,000 in proceeds from convertible credit line payable, related party and $5,000 in proceeds from the sale of common stock.

On June 1, 2021, the Company entered into a convertible credit line with a related party, AEI Acquisition Company, LLC, the beneficial owner of 74% of the Company’s common stock, which provides for up to $1,500,000 of advances. The outstanding principal amount accrues interest at a rate of 7% per annum and is convertible into shares of common stock at a rate equal to the lesser of (i) $4.00 per share or (ii) the closing price on the common stock on the primary trading market for our common stock on the day immediately preceding the date of conversion. During the year ended December 31, 2022, the Company repaid the convertible credit line in full. As of December 31, 2022 and 2021, the outstanding principal balance on the convertible credit line was $0 and $168,328, respectively.

On December 31, 2022, the Company and 20 Shekels, Inc. an affiliate of our President Jay Leaver, and AEI Management, Inc., an affiliate of our majority stockholder, AEI Acquisition Company, LLC., entered into Exchange Agreements (the “Exchange Agreements”) with respect to certain outstanding indebtedness of the Company. Under the Exchange Agreements, the Company’s previously issued 7.25% Senior Secured Notes due February 22, 2024 to affiliates of Mr. Leaver (which were assigned to 20 Shekels, Inc. a corporation wholly-owned by Marshwiggle, LLC, a limited liability company jointly owned by Mr. Leaver and his spouse ) and to AEI Management, Inc. were amended and restated and the Contractual Investment Agreements (“CIA”) entered with the Company and related agreements were terminated and replaced with the new 7.25% Senior Secured Note Purchase Agreement agreements and the new 7.25% Transaction Documents. Under the terms of the Exchange Agreements, 20 Shekels, Inc. was issued a $906,754 principal amount 7.25% Note and AEI Management, Inc. was issued a $413,206 principal amount 7.25% Note. As a result of the amendments, the holders and the Company amended and restated the terms of the contractual agreements governing 7.25% Notes in order to, among other things, extend the maturity date to December 31 2024 and limit the scope of the collateral pledged to assets acquired on March 9, 2022 (34 well bores and related assets) under the Purchase and Sale Agreement with Progressive Well Service, LLC on the Cherokee Uplift in Central Oklahoma for the Logan 1 Assets.  In addition, AEI Management, Inc. was appointed collateral agent for 7.25% Notes, the CIAs were terminated, and the parties agreed to various representations and warranties, covenants, and conditions, as provided in the new 7.25% Transaction Documents and released all prior obligations under the CIA and related agreements.

Quantitative and Qualitative Disclosures about Market Risk

We are exposed to a variety of market and other risks including credit risks, the market price for oil and natural gas and transaction risks as well as risks relating to the availability of funding sources, hazard events and specific asset risks.

Going Concern

The continuation of the Company as a going concern is dependent upon our ability to obtain continued financial support from its stockholders, necessary equity financing to continue operations and the attainment of profitable operations. As of December 31, 2022, the Company has incurred an accumulated deficit of $6,954,467 since inception and had not yet generated any revenue from operations. Additionally, management anticipates that its cash on hand as of December 31, 2022 is sufficient to fund its planned operations into but not beyond one year from the date of the issuance of these financial statements. The Company’s continuing losses from operations and net capital deficiency raise substantial doubt regarding our ability to continue as a going concern.

We will have additional capital requirements for 2023 and beyond. We may need to seek additional financing, which may or may not be available to us.

Off Balance Sheet Arrangements

None

Contractual Obligations 

The Company, through its wholly-owned subsidiary Alpha Energy Texas Operating LLC, or ETC, is a party to a Crude Oil Purchase Agreement with Energy Transfer Crude Marketing LLC, dated June 7, 2022, pursuant to which the Company sells to ETC all crude oil produced from the Logan Project. The price for the crude oil based on the weighted average price of West Texas Intermediate crude for the trade month and valued in the trade as Sunoco OK SW crude. The term of the Agreement is month-to-month and may be terminated by either party upon 30 days advance written notice.

The Company is a party to a Gathering and Processing Agreement with ETC Pipeline, Ltd., dated August 1, 2022, pursuant to which ETC Pipeline LTD provides certain gathering, processing and related services with respect to gas produced by the Company. The Agreement provides that the fees for such services will be set forth in a transaction confirmation to be entered into with respect to the provision of specific services. The term of the Agreement is month-to-month and may be terminated by either party upon 60 days advance written notice.

Significant Accounting Policies

For a discussion of our significant accounting policies please see Note 1 to the audited financial statements included as part of this report. Management determined there were no critical accounting policies.

Critical Accounting Estimates

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amount of assets, liabilities and contingencies at the date of the financial statements as well as the reported amounts of expenses during the reporting period. As a result, management is required to routinely make judgments and estimates about the effects of matters that are inherently uncertain. Actual results may differ from these estimates under different conditions or assumptions.

Management believes its application of accounting policies, and the estimates inherently required therein, are reasonable. These accounting policies and estimates are periodically reevaluated, and adjustments are made when facts and circumstances dictate a change.

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 and unproved 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. 

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.

The capitalized costs of oil and gas properties, excluding unevaluated and unproved properties, are amortized as depreciation, depletion and amortization expense using the units-of-production method based on estimated proved recoverable oil and gas reserves.

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.

Revenue 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, 2022 or 2021. The Company recorded revenues of $270,627 and $3,839 and costs of revenues totaling $538,770 and $15,652 during the years ended December 31, 2022 and 2021 respectively.

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, 2022 and 2021, there were 263,992 and 168,328 shares issuable from senior secured convertible notes and 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.

Property and Equipment

Property and equipment is recorded at cost and depreciated over their estimated useful lives using the straight-line depreciation method as follows:

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 unproved 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.

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.

The capitalized costs of oil and gas properties, excluding unevaluated and unproved properties, are amortized as depreciation, depletion and amortization expense using the units-of-production method based on estimated proved recoverable oil and gas reserves.

Concentrations of Risk

The Company has 100 % of the Working Interest in the oil and gas leases, which are located in the state of Colorado and Oklahoma. 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.

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 as of December 31, 2022 and 2021.

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.

Related Parties

The Company follows ASC 850, Related Party Disclosures, for the identification of related parties and disclosure of related party transactions.

Stock-based Compensation

Employee and non-employee share-based compensation is measured at the grant date, based on the fair value of the award, and is recognized as an expense over the requisite service period.

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.  

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.

NOTE 3 – OIL AND GAS PROPERTIES

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.

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. On March 9, 2022, the Company closed on the acquisition of 34 well bores and related assets under the PSA with cash payments of $726,298. The Company is 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.

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. During the year ended December 31, 2022, the Company paid $30,000 related to the extension agreement.

Oil and gas properties at December 31, 2022 and 2021 consisted of the following:

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 $794,000 and $626,000 as of December 31, 2022 and 2021, respectively which is calculated by multiplying a 25.63% estimated tax rate by the cumulative net operating loss (NOL) of approximately $3,101,000 and $2,440,000, 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:

A reconciliation of income taxes computed at the statutory rate is as follows:

The Company has an operating loss carry forward of approximately $3,101,000 as of December 31, 2022.

NOTE 5 – COMMON STOCK

The Company is authorized to issue 75,000,000 shares of its capital stock, consisting of 10,000,000 shares of preferred stock, par value $0.001 per share, and 65,000,000 shares of common stock, par value $0.001 per share.

The Company compensates each director with 4,000 shares of common stock each month. During the years ended December 31, 2022 and 2021, the Company issued 156,000 and 192,000 shares of common stock valued at $156,000 and $192,000, respectively, as board of director compensation.

During the year ended December 31, 2022, the Company recorded stock compensation in the amount of $78,720 and issued 78,720 shares of common stock to Kelloff Oil & Gas, LLC. In addition, the Company recorded stock compensation in the amount of $29,000 issued 29,000 shares of common stock for services provided during the year ended December 31, 2022.

On September 2, 2022, the Company entered into a six-month agreement with a consultant that includes the issuance of 60,000 common shares. During the year ended December 31, 2022, the Company issued 60,000 common shares and recorded $40,000 of expense. As of December 31, 2022, there was $20,000 of unrecognized expense related to this agreement. The Company will recognize the remaining expense over the service period.

On October 15, 2022, the Company entered into a one year agreement with a consultant. Per the agreement, the Company will compensate the consultant $10,000 and issue 2,000 common shares per month. During the year ended December 31, 2022, the Company issued 5,000 common shares and recorded $5,000 of expense.

During the year ended December 31, 2022, the Company issued 2,504,500 shares of common stock and received cash proceeds of $2,504,500.

For the year ended December 31, 2021

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 year ended December 31, 2021, the Company sold 5,000 shares of common stock for total proceeds of $5,000.

The Company pays its CFO a yearly bonus of 25,000 shares of common stock. During the year ended December 31, 2021, the Company issued 25,000 shares of common stock to the CFO with a fair value of $25,000.

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.

NOTE 6 – RELATED PARTY TRANSACTIONS

Advances from Related Party

The Company received advances from AEI Management, Inc., a Company owned by a significant shareholder, totaling $88,956 and $234,100 during the years ended December 31, 2022 and 2021, respectively. AEI Management paid expenses on the Company’s behalf of $19,150 during the year ended December 31, 2021. The advances are unsecured, non-interest bearing and are payable on demand. During the year ended December 31, 2022, the Company repaid $10,000 of the advances and converted $413,206 of advances to a senior secured convertible note due February 24, 2024.

The Company received advances from Jay Leaver, President of the Company, totaling $31,280 and $193,800 during the years ended December 31, 2022 and 2021, respectively. Mr. Leaver paid oil and gas payments on the Company’s behalf totaling $65,500 during the year ended December 31, 2021. The advances are unsecured, non-interest bearing and is payable on demand. During the year ended December 31, 2022, the Company converted $325,580 of advances to a senior secured convertible note due February 24, 2024.

Other

During the year ended December 31, 2021, the Chief Financial Officer allowed the use of his residence as an office for the Company at no charge.

During the year ended December 31, 2021, a board member of the Company acted as corporate council to Company at no charge, other than board of director fees.

As of December 31, 2022 and 2021, there was $0 and $628,550 of short-term advances due to related parties, respectively.

Accounts Payable and Accrued Expenses - Related Parties

As of December 31, 2022, there was $203,484 of accounts payable related parties which consisted of $203,484 due to Leaverite Exploration, Inc. d/b/a Leaverite Consulting (“Leaverite Exploration”), a corporation wholly-owned by our President, Jay Leaver pursuant to a consulting agreement.

As of December 31, 2021, there was $228,668 of accounts payable related parties which consisted of $208,484 due to Leaverite Exploration, $4,394 due to former CFO John Lepin, $10,000 due Kelloff Oil &Gas, LLC, a limited liability company and $5,790 due to Staley Engineering LLC for consulting services.

Notes Payable - Related Party

On December 3, 2020, the Company executed a promissory note for $65,000 with Jay Leaver, our President. The unsecured note matured three years from date of issuance and bore interest at a rate of 5% per annum. As of December 31, 2021, the note payable had unpaid accrued interest in the amount of $13,003. On February 23, 2022, the promissory note was amended to a principal amount of $406,750, which includes the original $65,000 plus additional advances of $325,580 and accrued interest of $16,170. The amended promissory note matures on February 23, 2025 and bears interest at 5% per annum. In February 2022, Mr. Leaver advanced an additional $500,000 to the Company. On February 25, 2022, Mr. Leaver’s $406,750 promissory note and $500,000 advance were assigned to 20 Shekels, Inc, a corporation wholly-owned by Marshwiggle, LLC, a limited liability company jointly owned by Mr. Leaver and his spouse and on February 25, 2022 the Company issued $906,750 of its secured senior secured convertible notes due February 24, 2024, bearing interest at a rate of 7.25% per annum (the “7.25% Note”) in exchange for the prior obligations. The 7.25% Note is convertible into shares of the Company’s Common Stock at $5.00 per share.

Senior Secured Convertible Notes Payable – Related Party

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 fixed 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 purports to be secured by certain oil and gas leases, lands, minerals and other properties of the Company, subject to prior liens and security interests. See Note 4 – Related Party Transactions. $413,206 from a related party were exchanged for a Convertible Note. Due to the variable conversion price in the convertible credit line, this fixed senior secured convertible note is treated as derivatives due to possibility of insufficient shares available at conversion to settle the notes. The day one derivative liability was $65,262, which was recorded as a discount on the senior secured convertible notes payable. During the year ended December 31, 2022, the Company amortized $27,624 of the discount as interest expense. As of December 31, 2022, the unamortized discount was $37,638. The outstanding principal balance on the senior secured convertible notes payable as of December 31, 2022 amounted to $413,206. See discussion of derivative liability in Note 9 – Derivative Liability.

On February 25, 2022, Mr. Leaver assigned a $406,750 promissory note and advances of $500,000 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. Due to the variable convertible credit line, this fixed senior secured convertible note are treated as derivatives due to possibility of insufficient shares available at conversion to settle the notes. The day one derivative liability was $143,214, which was recorded as a discount on the senior secured convertible notes payable. During the year ended December 31, 2022, the Company amortized $60,621 of the discount as interest expense. As of December 31, 2022, the unamortized discount was $82,593. The outstanding principal balance on the senior secured convertible notes payable as of December 31, 2022 amounted to $906,754. See discussion of derivative liability in Note 9 – Derivative Liability.

On December 31, 2022, the Company and 20 Shekels, Inc. an affiliate of our President Jay Leaver, and AEI Management, Inc., an affiliate of our majority stockholder, AEI Acquisition Company, LLC., entered into Exchange Agreements (the “Exchange Agreements”) with respect to certain outstanding indebtedness of the Company. Under the Exchange Agreements, the Company’s previously issued 7.25% Senior Secured Notes due February 22, 2024 to affiliates of Mr. Leaver (which were assigned to 20 Shekels, Inc. a corporation wholly-owned by Marshwiggle, LLC, a limited liability company jointly owned by Mr. Leaver and his spouse ) and to AEI Management, Inc. were amended and restated and the Contractual Investment Agreements (“CIA”) entered with the Company and related agreements were terminated and replaced with the new 7.25% Senior Secured Note Purchase Agreement agreements and the new 7.25% Transaction Documents. Under the terms of the Exchange Agreements, 20 Shekels, Inc. was issued a $906,754 principal amount 7.25% Note and AEI Management, Inc. was issued a $413,206 principal amount 7.25% Note. As a result of the amendments, the holders and the Company amended and restated the terms of the contractual agreements governing 7.25% Notes in order to, among other things, extend the maturity date to December 31 2024 and limit the scope of the collateral pledged to assets acquired on March 9, 2022 (34 well bores and related assets) under the Purchase and Sale Agreement with Progressive Well Service, LLC on the Cherokee Uplift in Central Oklahoma for the Logan 1 Assets. In addition, AEI Management, Inc. was appointed collateral agent for 7.25% Notes, the CIAs were terminated, and the parties agreed to various representations and warranties, covenants, and conditions, as provided in the new 7.25% Transaction Documents and released all prior obligations under the CIA and related agreements.

As of December 31, 2022, the senior secured convertible notes payable balance, net of discount was $1,199,729.

As of December 31, 2022, the future maturities of debt, excluding debt discounts are as follows:

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, 2022 and 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 June 1, 2021, the Company entered into a new convertible credit line agreement to borrow up to $1,500,000 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, 2022, the Company amortized $11,100 of the discount as interest expense. As of December 31, 2022, and December 31, 2021, the unamortized discount was $0 and $11,100, respectively. During the year ended December 31, 2022, the Company repaid $168,328 of principal on the convertible credit line and $53,275 of accrued interest. The outstanding principal balance on the convertible credit line as of December 31, 2022 and December 31, 2021 amounted to $0 and $168,328. 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, 2022 and 2021:

As of December 31, 2022, and 2021, the Company had a $0 and $145,041 derivative liability balance on the consolidated balance sheets, respectively and recorded a gain from derivative liability fair value adjustment of $171,712 and loss from derivative liability fair value adjustment of $33,310 during the years ended December 31, 2022 and 2021, 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. During the year ended December 31, 2022, the Company repaid the convertible credit line in full, which caused the senior secured convertible notes to no longer be classified as a derivative. As a result, the Company recorded a reclassification from derivative liabilities to equity of $181,805.

Utilizing Level 3 Inputs, the Company recorded a gain on fair market value adjustments related to convertible credit line payable and senior secured notes payable for the year ended December 31, 2022 of $171,712. The fair market value adjustments as of December 31, 2022 were calculated utilizing the Black-Scholes option pricing model using the following assumptions: exercise price of $1.00 - $5.00, computed volatility of 180% - 261% and discount rate of 3.92% - 4.76%.

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:

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 0.03125% overriding royalty interest in each future producing well. On April 8, 2022, CFO resigned as director, officer and employee of the Company.

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.

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, 2022, 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, 2022.

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:

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, 2022 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.

ITEM 9B. OTHER INFORMATION

None.

ITEM 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS

None.

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The information required by this Item is incorporated herein by reference from our Proxy Statement for our upcoming 2023 Annual Meeting of Stockholders.

ITEM 11. EXECUTIVE COMPENSATION

The information required by this Item is incorporated herein by reference from our Proxy Statement for our upcoming 2023 Annual Meeting of Stockholders.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

The information required by this Item is incorporated herein by reference from our Proxy Statement for our upcoming 2023 Annual Meeting of Stockholders.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPNDENCE

The information required by this Item is incorporated herein by reference from our Proxy Statement for our upcoming 2023 Annual Meeting of Stockholders.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

The information required by this Item is incorporated herein by reference from our Proxy Statement for our upcoming 2023 Annual Meeting of Stockholders.

PART IV

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES

(a)

(b) Exhibits

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused the report to be signed on its behalf by the undersigned, thereunto duly authorized.

Alpha Energy, Inc.

/s/ Jay Leaver

Jay Leaver, President (Principal Executive Officer)

Date: April 17, 2023

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.