EDGAR 10-K Filing

Company CIK: 1603793
Filing Year: 2022
Filename: 1603793_10-K_2022_0001493152-22-016856.json

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ITEM 1. BUSINESS
Item 1. Business.
Our Company
Norris Industries, Inc. (“NRIS” or the “Company”) was incorporated on February 19, 2014, as a Nevada corporation and is headquartered in Weatherford, Texas. The Company was formed to conduct operations in the oil and gas industry, and currently focuses on the development, production and maintenance of its existing crude oil and natural gas properties in Texas. On May 4, 2015, the Company initially acquired working interests from the Bend Arch Lion 1A and the Bend Arch Lion 1B Joint Ventures in Coleman County of Texas, encompassing a total production of 7 producing oil and gas wells on a total of 380 acres out of a total of 777-acre leaseholds indicating proven recoverable reserves. We believed that the Bend Arch Lion 1A and 1B Joint Ventures as parts of the total 777-acre leasehold have not been fully explored. The Company has managed the 45-acre Marshall Walden joint venture with 8 Woodbine Sand oil wells in Kilgore City, Texas. Additionally, the Company had a 640-acre lease in King County that expired in 2022. The Company chose not to renew the lease. The Company, in fiscal year 2018, also purchased producing oil and gas mineral leases on December 28, 2017, in the Texas counties of Jack County and Palo-Pinto County in North Central Western part of Texas. The leases were for 20 gross oil and gas wells on 2,790 gross acres with majority working and operating interests with daily production of 50 barrels of oil equivalent (“BOE”). During fiscal year 2020, the Company completed a purchase of the remaining 90% working interest ownership (“WI”) of the Marshall-Walden property that it did not own previously, and now owns 100% of the WI, with a 75% net revenue interest (“NRI”). Currently, NRIS holds approximately 4,200 total gross acres in leaseholds in various areas of the North Central, and in North East Texas regions. The Company plans to focus its limited resources on its existing leaseholds in the future.
The Company underwent a change of control in July 2017, when Patrick Norris, and his affiliate JBB Partners (“JBB”) acquired majority ownership of the Company and provided loans and equity funding for the oil/gas mineral rights purchases and for covering the operational expenses of Company.
The Company will, from time to time, seek strategic investors and other funding to help it develop additional exploration and acquisition projects located within the Bend Arch-Fort Worth Basin and other prime acquisition targets in the Central West, South and East Texas.
Our Business Strategy
We are a small exploration & production (“E&P”) oil and natural gas company that focuses on the, development, production, and maintenance of its existing of crude oil and natural gas properties in Texas. The Company’s goal is to tap into the high potential leases of the Central West Texas region of the United States, aiming to unlock the potential in the prolific Bend Arch-Fort Worth region. This area is approximately 120 miles long and 40 miles wide, running from Archer County, Texas in the north to Brown County, Texas in the south. The Company also will look at other acquisition opportunities in the Permian Basin, West Texas, East Texas and South Texas regions.
Management believes that focusing on the development of existing small producing fields is one of the key differentiators of the Company. Oil and natural gas reserve development is a technologically oriented industry. Management believes that the use of current generally available technology has greatly increased the success rate of finding commercial oil or natural gas deposits. In this context, success means the ability to make an oil/gas well that produces a commercialized quantity of hydrocarbons. In general, the Company expects to conduct 3D Seismic surveys to determine more accurate drilling locations and drilling depths beside its initial georadiometry technology application via its last 10 drilling projects.
For near- to medium-term cash flow enhancement, the Company will plan to focus on existing fields and to selectively consider larger-reserve oil and gas properties with low production to acquire at reasonable cost and then implement effective Enhanced Oil Recovery (“EOR”) methods to improve its current revenues and assets. For long-term cash flow enhancement, the Company plans to identify other oil-field related, and niche enterprises to consider for bolt on, or diversified acquisition targets to grow Company revenues. This may be with use of capital partners to buyout via the Company’s strategic joint venture partnerships, and to raise outside capital to fund any potential future acquisition.
The Company’s long-term objective is to increase shareholder value by growing reserves, production and cash flow. As result we may seek to identify and consider acquisition opportunities of oilfield services companies and other non-oilfield companies that align with our operational plan to implement a diversified growth strategy
Notwithstanding the above stated objectives, the ramifications of the pandemic containment measures and consequent disruptions to the United States and world economies due to the COVID - 19 viral outbreaks had an adverse impact on the overall business of the Company and the industry in which it operates. The demand for oil and gas has impacted all producers as commodity prices of oil and gas has increased substantially, but so has inflation resulting in higher costs for materials, equipment, personnel and service providers. In addition, in early 2022 the industry faced added complications as result of the Russian Federation invasion of Ukraine. As result energy prices have risen however, we are unable to predict exact supply and demand balances that will cause energy prices to be highly volatile and thus affect our revenues into the near future. Therefore, we anticipate that we may not be able to cover operating costs and will have to take cost cutting measures and seek continued operational financing.
As a result of the COVID-19 pandemic and war in Ukraine and the various governmental and political responses and those of our subcontractors, customers and suppliers, we expect continued delays or disruptions and temporary suspensions of operations due to shortages of labor and increased cost from suppliers. In addition, our financial condition and results of operations have been and are likely to continue to be adversely affected by the COVID-19 public health developments. Thus, subject to adjustments due to the COVID - 19 pandemic and the general economic consequences and the more specific impact on the oil and gas industry, the current general strategic objectives of the Company are set forth below.
The Company is currently listed on the OTCQB marketplace of OTC Link as an E&P oil and gas company.
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Develop and Grow Our Hydrocarbon Acreage Positions Using Outside Development Expertise.
We plan to focus on improving our assets that are located in hydrocarbon-rich resource plays to improve our asset quality and to improve on production. We plan to leverage outside expertise to apply available EOR technologies to economically develop our existing property portfolio and those that we may acquire in the future. We plan to operate the majority of our acreage, giving us greater control over the planning of capital expenditures, execution and cost reduction. Operating our own acreage also will allow us to adjust our capital spending based on drilling results and the economic environment. Our leasehold acquisition strategy is to pursue long-term contracts that allow us to maintain flexible development plans and avoid short-term obligations to drill wells, as have been common in other resource plays. As a small producer, we regularly evaluate industry drilling results and implement technologically effective operating practices which may increase our initial production rates, ultimate recovery factors and rate of return on invested capital.
Manage Our Property Portfolio Proactively. We evaluate our properties to identify and divest non-core assets and higher cost or lower volume producing properties with limited developmental potential, to enable us to focus on a portfolio of core properties with what we believe to be the greatest economic potential to increase our proved reserves and production.
Acquire Small Producing Companies with Compelling Underlying Values. We review acquisition opportunities with underlying assets to evaluate their development potential and accelerate production to unlock their potential value. The current oil and gas economic environment may provide us with acquisition opportunities for new properties.
Maintain Access to Capital to Execute Our Growth Plan. Our management team is focused on maintaining available credit lines since this gives us the ability to use borrowing capacity and access to outside capital markets and to provide us with a liquidity level to execute if opportunity emerges to purchase assets and revenues.
Our operation strategy is to identify niche hydrocarbon land leases in Texas with in-depth studies and develop proven reserves via drilling new wells and re-entering existing low production wells to maximize production and enhance valuation of our production assets.
Based upon management’s knowledge and its use of outside petroleum exploration experience, geology expertise, and ability to identify potential acreage and moderate production fields, management believes that the Company’s future valuation as a public company is speculative but could become attractive if and when we increase our production successfully.
The Company acquisition model, to the extent it is implemented, will be based on a concept that has been proven to be an effective and successful path of development for many other well- known E&P players:
a) the financed acquisition of mature smaller oil fields that have potential for instituting EOR incremental production processes; and
b) Develop strategic partnerships with existing operators to share production increases garnered through the implementation of this EOR plan.
After identifying a new prospect, additional research and evaluation will be carried out using geologists, 3D seismic, satellite hydrocarbon imaging, production data and other available resources to glean information and data in order to make an acquisition decision. After an acquisition, the objective will be to increase production using current technologies with a designated budget pre-approved by the Company’s senior management team. The Company will seek to implement cost saving measures in operating budgets for each exploration project, but each budget will vary depending on the total depth of drilling and whether it is a new drilling or a re-entry. For each project, the Company plans on hiring selected operators to work under the close supervision of a core team of Company geologists, engineers, and scientists. The exploration and production process is a two-phase process: 1) drilling and testing and 2) well completion. The Company plans to hire drilling specialists and technical consultants designated to oversee the drilling and reentering of existing holes for each well during the drilling and testing phase. For the well completion process, the Company plans to hire technical data collectors and cementing operators to ensure the best performance upon perforating the wells at different pay zones based on thorough technical advisory work done by our internal and external production personnel and geologists before production. The Company also plans to apply selective leading edge EOR technologies from technology vendors to improve existing production.
Our Competitive Strengths
Management believes that the Company offers a number of competitive strengths that would allow it to successfully execute our business strategies:
Simple Capital Structure. We have a simple capital structure and de-risked inventory of locations with what we believe is upside potential to take advantage of the continuing situation for oil prices to acquire potential production at reasonable cost.
Management Team. With selected experience in key aspects of the development of resource plays, our management team and its consultants have decades of combined experience in the industry and a commitment to create shareholder value via an acquisition strategy. We also consult and work with geologists, engineers, and other professionals to execute on our business objectives.
Moderate Risk Exploration Practice. Unlike many major oil companies that often drill very deep wells with a high degree of risk, we focus on shallow well exploration (sub 5,000 feet) that is less expensive and has lower risk factors. The basis for management’s belief that the wells that can be drilled in the prospective leases will have the capacity to produce a reasonable amount of hydrocarbon and due to our recent studies of the general areas where we are prospecting the projects.
Under The Radar Asset Base. Management believes there are available for acquisition, from time to time, hydrocarbon land leases with sub-300 barrels of oil per day (“bopd”) wells with have large hydrocarbon reserves that have been overlooked by other oil and gas operators. Management believes that these “under the radar” prospective leases have multi-year drilling inventory and reasonable production history with high upside potential, and they are not readily accessible to the public for auctions, thus adding to our competitive advantage on these “under the radar” opportunities. Management also believes that these leases are not economically justifiable for the major oil and gas companies in the region because such companies need wells that produce at least 300 barrels (“Bbls”) of oil per day per well to meet their business model and operating costs.
Geographic Diversity. We believe that our geographic focus encompassing the West, Central West, East and South Texas regions provides us with some flexibility to direct our capital resources to projects with the better potential returns and access to multiple key end markets, which mitigates our exposure to temporary price dislocations in any one market.
Technologies
Oil and natural gas reserve development is a now a technology-oriented industry. Management believes that technology has greatly increased the success rate of finding commercially viable oil or natural gas deposits. In this context, success rate means the ability to locate an oil/gas well that can produce a commercialized quantity of hydrocarbon.
At NRIS, we engage consultants to focus on geoscience along with help in our understanding of complex mineralogy in shale reservoirs and better determining zones susceptible to enhanced production methods. We use technology to indicate where to frack with the potential of greater success as it provides us with rapidly available data while delivering game changing levels of collaboration: multi-well, multi-user and multi interpreter. Our field engineers, geologists and petrophysicists work together for better drilling decisions.
Reservoir Estimate
As of March 1, 2022, our estimated gross proved oil and natural gas reserves, as prepared by our independent reserve engineering firm, Kurt Mire, PE, using SEC prices used throughout this report for crude oil, condensate, and natural gas were $71.67 per barrel of oil and $3.95 per MMBTU for Henry Hub gas. As result of lease purchases from funding made available from our majority owner, we include 100% of our net oil reserves and 100% of our net natural gas reserves that were classified as proved producing that include values from the proved developed producing, proved behind pipe, and proved non-producing reserves categories as of March 1, 2022.
Sales Strategy
Our sales strategy in relation to spot pricing will be to produce less when the sales price is lower and produce more when the sales price is higher. To maintain the lowest production cost, we will aim to have our inventory be as low as possible, in some instances virtually zero. Our E&P core team has business relationships with BML, Transport Oil, and Lion Oil Trading & Transportation, for oil sales and WTG Jameson for gas sales. The Company entered into production agreements with BML, Lion Oil and WTG Jameson so that, as our tier 1 buyer, they can handle pick-up and sales of our crude oil stock to refineries and gas via local gas pipelines.
As such, crude oil will be picked up from our leases as needed during the calendar month. At the end of the month the crude total sales will be tallied by lease and the 30-day average of the daily closing of oil will be tabulated. On or about the 25th of the following month the proceeds checks will be issued to the financial parties of record.
In the current market environment resulting from the public health lock-down and overall disruption to the oil and gas market, our production may have to be curtailed or we may shut-in some of our wells at a point in time or may hold, or continue to store some, or all of our oil as inventory to be sold at a later date as have refused to accept zero price for our production.
Operational Plans
During fiscal year 2020, the Company was in a period of assessment and work-over of its existing wells as result of its acquisition of the Jack and Palo Pinto oil and gas leases. We continue to look for, on a selective basis, oil and gas reserve concessions with existing production. However, any acquisitions will have to take into account the current and anticipated market for oil and gas products and the general economic outlook, which in part drives the consumption of oil and gas. For any potential acquisition, we will then seek to raise enough capital via equity or debt financing options to meet our operational needs and acquisition requirements, be this from our control owner, or other third-party financing sources, including the capital markets.
Based on the Company’s general management and petroleum exploration experience, as well as its geology expertise, the Company believes it has the ability to identify potential acreage with existing producing fields and acquire them.
As mentioned before the effect of the government responses to COVID-19 as well as the war in Ukraine has impacted the domestic and international demand for crude oil and natural gas, which has contributed to price volatility, impacted dramatically the price we receive for oil and natural gas and has materially and adversely affected the demand for, and costs incurred on our production, which means that our production may have to be shut-in, or costs will increase on some of our wells at any point in time..
Completed Acquisitions with Production Enhancement Programs
To date, the Company has prospected and completed several exploration and acquisition projects, all of which may change subject to market conditions and risk assessments due to the COVID 19 public health response and general economic conditions:
The Bend Arch Lion 1A JV, Coleman County, TX:
This drilling joint venture is a 160-acre leasehold having four producing wells which have been drilled by our Texas-based operating partner International Western Oil. This field has been surveyed with high quality proven reserves encompassing several pay zones highlighted by the Gray Sand, the Palo Pinto, and in some instances the Ellenburger pay zone. On May 4, 2015, the Company acquired a 39.5% working interest from IWO in the Bend Arch Lion 1A Joint Venture (the Pittard Bend Arch White property encompassing 160 acres - State ID# 21488) (the “1A Venture”.) By acquiring these working interests, the Company directly receives the share of working interest revenue (after accounting for applicable taxes, expenses, and landowner royalties) IWO was receiving prior to the acquisitions.
As of February 28, 2022, the 1A Venture property had four (4) gross oil and gas wells (1.58 net wells). The initial production of this property started in April 2014.
Management plans to review and determine how best to implement a production improvement program on several of its wells including the Bend Arch Lion 1A and others. As a result of recent studies that show accessible proven reserves in several pay zones highlighted by the Gray Sand and the Ellenburger pay zones, management believes its production improvement program can offer an increase from the current production of these fields by re-completing certain pay zones with either standard acidizing jobs, a new EOR method, or reentering and fixing equipment in areas that have become declining wellbores.
The Bend Arch Lion 1B JV, Coleman County, TX:
This drilling joint venture is a 220-acre leasehold having 6 new producing wells which have been drilled by our Texas-based operating partner International Western Oil. In May 2015, the Company acquired working interests of this leasehold which has been surveyed with high quality proven reserves encompassing several pay zones highlighted by the Gray Sand and in some instances the Ellenburger pay zone. At the moment, the leasehold has 3 producing wells coming from the Gray Sand formation and 3 producing wells coming from the Ellenberger formation. On May 4, 2015, the Company acquired 46% working interest in the Bend Arch Lion 1B Joint Venture (the Pittard Bend Arch Red property encompassing 220 acres - State ID# 13121) (the “1B Venture”).
As of February 28, 2022, the 1B Venture property had six (6) gross oil and gas wells (3 net wells). The initial production of this property started in March 2015.
Management plans to determine how best to implement a production improvement program on the Bend Arch Lion 1B as the result of our prior in-depth studies that show accessible proven reserves in several pay zones highlighted by the Gray Sand pay zone and the Ellenburger pay zone. Management believes this can offer a potential increase from the current production of this field by re-completing certain Gray Sand pay zone with either standard acidizing jobs or a new EOR method and entering the virgin Gray Sand pay zone or increasing pumping efficiency in the Ellenburger pay zone in certain declining wellbores.
The Marshall Walden JV, Kilgore City, TX:
As of July 29, 2016, the Company served as the managing venturer in a 45-acre joint venture with Odyssey Enterprises LLC which has financed the Marshall Walden joint venture for the lease purchase and optimization of wells located in Kilgore, Texas, in the heart of the Woodbine formation. There are 8 wellbores in the acquisition, with 4 currently in production and 4 inactive. During the year ended February 28, 2021, the Company completed a purchase of the 90% WI that it did not own previously, and now owns 100% WI, with a 75% NRI. Management believed that the Marshall Walden acquisition had value at the time of purchase in mid-2019.
As of February 28, 2022, the Marshall Walden property had six (6) gross oil and gas wells (0.6 net wells) which are intermittently active, plus two (2) injection wells. There are no definitive plans currently; the Company expects to determine such in the next fiscal year. The initial production of this property started in September 2016.
As of February 28, 2022, the Ratliff property had minimal production but had value in several proved developed not producing (“PDNP”) wells based on the Company’s year-end reserve analysis. As result Management believes that this acquisition should be written off at this time and has taken a non-cash charge against full value on this to zero.
The Stuart Leases of Jack County and Palo-Pinto County
The Jack County and Palo-Pinto County Stuart oil leases were purchased on December 28, 2017 and have twenty (20) gross oil and gas wells (15 net wells), which the management is operating production on its properties.
Reserve Information
The data below is based on the SEC Non-Escalated Analysis of Estimated Proved Reserve of the Jack County and Palo Pinto County associated leases as well as the Bend Arch Lion 1A and Bend Arch Lion 1B, and Marshall-Walden leaseholds in which the Company has certain minority interests. As of March 1, 2022, this evaluation report was prepared by an independent third-party Kurt Mire, a PE reservoir engineer based in Houston, Texas. To the extent able, the Company will concentrate on those wells in which the Company either owns a majority, or 100% of the working interest in such oil and gas property lease.
Estimated Proved Reserves
Net to Norris Industries, Inc.
SEC Non-Escalated Analysis
As of March 1, 2022
Proved
Developed Proved Proved Non- Proved Total BOE
Producing Behind Pipe producing Shut-in & Value
Net Reserve
Oil - Bbl. 18,160 6,700 1,400 - 26,260
Gas - Mcf 65,100 46,400 4,400 - 115,900
Income Data
Future gross revenue $ 1,643,500 $ 634,100 $ 103,500 $ - $ 2,381,100
Expenses & Taxes $ 1,150,200 $ 232,200 $ 43,500 $ - $ 1,425,900
Investments costs $ 73,700 $ 36,900 $ 22,400 $ 56,300 $ 189,300
Undiscounted cash flows $ 419,600 $ 365,000 $ 37,400 $ (56,300 ) $ 765,900
Discounted cash flows at 10% $ 313,200 $ 299,400 $ 31,700 $ (42,900 ) $ 601,400
The unit prices used throughout this report for crude oil, condensate, and natural gas were $71.67 per barrel of oil and $3.95 per MCF for Henry Hub gas which are above current market prices. The reserve report unit prices are based upon the appropriate prices in effect the first trading day of each month from March 2021 through February 2022 and averaged for the year which ranged from low of $57.76 for to a high of $95.72 per barrel of oil for WTI crude.
Employees
We presently have a limited number of individuals performing services for the Company: Patrick Norris our Chief Executive Officer, President, Chief Accounting Officer and Chief Financial Officer; Ross Henry Ramsey, the President of the oil division and Board-Member.
Mr. Ramsey devotes approximately 40 hours per week to the affairs of the Company. Mr. Ramsey serves as the President of the oil and gas division of the Company.
Ms. Lisa Boudoin devotes approximately 20 hours per week for administrative functions.

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors.
RISK FACTORS
An investment in our common stock involves a high degree of risk. You should carefully consider the risks described below, together with all of the other information included in this annual report, before making an investment decision. If any of the following risks occurs, our business, financial condition or results of operations could suffer. In that case, the trading price of our shares of common stock could decline, and you may lose all or part of your investment. You should read the section entitled “Cautionary Note Regarding Forward-Looking Statements” for a discussion of what types of statements are forward-looking statements, as well as the significance of such statements in the context of this annual report.
Risks Related to Our Business
LIMITED OPERATING HISTORY.
The Company was formed on February 19, 2014. The Company has had limited operations upon which an evaluation of the Company can be based. Exploration stage companies, such as the Company are subject to all of the risks inherent in the establishment of any new business in the E&P sector of the oil and gas industry. Our financial viability is dependent upon raising funds and successfully executing our business plan. The likelihood of our success must be considered in the light of the challenges, both expected and unexpected, frequently encountered in connection with starting and expanding a new business. Accordingly, we are planning to align our primarily fixed expense levels with our expectation of future revenues. We may be unable to adjust spending in a timely manner to compensate for unexpected shortfalls in any forthcoming revenue. Any such shortfalls will have an immediate adverse impact on our operating results and financial condition which could cause investors to lose all or a substantial part of their investment.
THE OIL AND GAS INDUSTRY IS NO LONGER IN A SUBSTANTIAL DOWNTURN DUE TO RECOVERY FROM COVID-19 PANDEMIC.
During the 2022 fiscal year, we performed an analysis of our oil and gas properties in light of recovery from the COVID-19 pandemic, and the increase in oil and gas prices and anticipated economic conditions in our industry. As a result, we don’t believe there to be any further impairment expenses required due to prior reduction in carrying value of our oil and gas properties in the March 1, 2022, Reserve Report.
Our business and operations were adversely affected by and are expected to continue to be adversely affected by the recent COVID-19 pandemic and the public health response and may be adversely affected in the future by other similar outbreaks. Our operations, and those of our subcontractors, customers and suppliers, have experienced and are anticipated to continue to experience delays or disruptions and temporary suspensions of operations. In addition, our financial condition and results of operations have been and are likely to continue to be adversely affected by the coronavirus outbreak and has somewhat recovered due to significant recovery of oil and gas prices.
The future potential magnitude of the COVID-19 outbreak is currently still unknown. The continuation or amplification of this virus could continue to affect the United States and global economy, (due to recent resurgent outbreaks in China) that might affect prices and our business and operations, and the demand more broadly for oil and gas or could be further disruptions due to invasion Ukraine by Russian forces in February and March of 2022.
The coronavirus pandemic has resulted in a widespread health crisis that may adversely affect the economies and financial markets of many countries, resulting in an economic downturn that will affect our operating results. Other contagious diseases in the human population could have similar adverse effects. In addition, it has negatively impacted the domestic and international demand for crude oil and natural gas, which has contributed to price volatility, impacted the price we receive for oil and natural gas, and has materially and adversely affected the demand for and marketability of our production; to us this means that our production may have to be shut-in for some of our wells at any point in time and may hold, or continue to store some, or all of our oil as inventory to be sold at a later date as we have refused to accept zero price for our production.
These unprecedented situations are anticipated to continue to affect the same for the foreseeable future. As the impact from COVID-19, and Ukraine invasion are difficult to predict, the extent to which it will negatively or positively affect our operating results, or the duration of any potential business disruption is uncertain. The magnitude and duration of any impact will depend on future developments and new information that may emerge regarding the severity and duration of COVID-19 or war and the actions taken by various governmental authorities to contain war or treat pandemic and related impacts, all of which are beyond our control.
These potential impacts, while uncertain, have already impacted our 2023 fiscal year first quarter results of operations, and anticipated to have an unknown impact on multiple future quarters’ results as well.
OUR FINANCIAL STATEMENTS HAVE BEEN PREPARED ON A GOING CONCERN BASIS.
The Company has incurred continuing losses since 2016, including a loss of approximately $500,000 for the fiscal year ended February 28, 2022. During the fiscal year ended February 28, 2022, the Company accessed $400,000 in funding, and reduced its general and administrative costs, increased revenues, and incurred cash losses of approximately $421,000 from its operating activities. If we do not increase our income so as to be able to cover our operating expenses, we will need to obtain financing during the fiscal year to fund our operations. We do not have any specific sources of capital to be able to raise additional working capital. Our principal shareholder, who is not legally obligated to fund our operations, may provide funding, but there is no assurance that the shareholder will make a further capital investment or lend us operating funds. As of February 28, 2022, the Company had availability of $600,000 on its existing credit line with JBB Partners, Inc. (“JBB”), an entity that is owned and controlled by Mr. Patrick Norris, the Company’s Chief Executive Officer, and principal shareholder. If we are not able to obtain working capital funding, we will have to curtail our operations or cease operations. If either event occurs, investors will suffer a diminution in the value of their investment.
AS WE CONTINUE TO DEVELOP OUR OPERATIONS, WE WILL NEED SUBSTANTIAL CAPITAL TO FUND OUR OPERATIONS, AND IF WE ARE NOT ABLE TO OBTAIN SUFFICIENT CAPITAL, WE MAY BE FORCED TO LIMIT THE SCOPE OF OUR OPERATIONS.
The Company currently has working interests in wells and acreage. To develop and expand our operations, we will need to make substantial capital expenditures for the acquisition of petroleum exploration companies, hydrocarbon land leases, and existing oil and gas production with large reserves, and for drilling new wells and re-entering existing low production wells. We intend to finance our capital expenditures primarily through our cash flows from operations, bank borrowings, and public and private equity and debt offerings. Lower crude oil and natural gas prices, however, will reduce our cash flows. In addition, new equity or convertible debt securities issued by us to obtain financing could have rights, preferences and privileges senior to the shares being offered for resale by the selling security holders.
Further, if the condition of the credit and capital markets materially declines, we might not be able to obtain financing on terms we consider acceptable, if at all. Our capital needs will depend on numerous factors, including (i) our profitability; (ii) the development of similar services undertaken by our competition; and (iii) the amount of our capital expenditures. We cannot assure you that we will be able to obtain capital in the future to meet our needs. If we cannot obtain financing, we may be required to limit our expansion and decrease or eliminate capital expenditures. Such reductions could materially adversely affect our business and our ability to compete.
In addition, weakness and/or volatility in domestic and global financial markets or economic conditions may increase the interest rates that lenders require us to pay and adversely affect our ability to finance our capital expenditures through equity or debt offerings or other borrowings. A reduction in our cash flows (for example, as a result of lower crude oil and natural gas prices) and the corresponding adverse effect on our financial condition and results of operations may also increase the interest rates that lenders require us to pay. In addition, a substantial increase in interest rates would decrease our net cash flows available for reinvestment. Any of these factors could have a material and adverse effect on our business, financial condition and results of operations.
The oil and gas business is characterized by high fixed costs resulting from the significant capital outlays associated with the acquisition, development, and exploration of crude oil and natural gas properties. We are dependent on the production and sale of quantities of crude oil at product margins sufficient to cover operating costs, including any increases in costs resulting from future inflationary pressures or market conditions and increases in costs of fuel and power necessary in operating our facilities. Furthermore, future major capital investment, various environmental compliance related projects, regulatory requirements, or competitive pressures could result in additional capital expenditures, which may not produce a return on investment. Such capital expenditures may require significant financial resources that may be contingent on our access to capital markets and commercial bank loans. Additionally, other matters, such as regulatory requirements or legal actions, may restrict our access to funds for capital expenditures.
Our ability to generate operating cash flow is subject to many of the risks and uncertainties that exist in our industry, some of which we may not be able to anticipate at this time. Future cash flows from operations are subject to a number of risks and variables, such as the level of production from existing wells, prices of natural gas and oil, our success in developing and producing new reserves and the other risk factors discussed herein. Our ability to obtain capital from other sources, such as the capital markets, other financing and asset sales, is dependent upon many of those same factors as well as the orderly functioning of credit and capital markets. If such proceeds are inadequate to fund our planned spending, we would be required to reduce our capital spending, seek to sell different or additional assets or pursue other funding alternatives, and we could have a reduced ability to replace our reserves and increase liquids production.
YOU WILL EXPERIENCE DILUTION OF YOUR OWNERSHIP INTEREST BECAUSE OF THE FUTURE ISSUANCE OF ADDITIONAL SHARES OF OUR COMMON STOCK AND OUR PREFERRED STOCK.
If we raise additional capital through the issuance of equity or convertible debt securities, the percentage ownership of the Company held by existing shareholders will be reduced and those shareholders may experience significant dilution. In addition, we may also have to issue securities that may have rights, preferences and privileges senior to our common stock. In the event we seek to raise additional capital through the issuance of debt or its equivalents, this will result in increased interest expense.
WE WILL BE DEPENDENT UPON KEY PERSONNEL FOR THE FORESEEABLE FUTURE.
Given our early stage of development, we are highly dependent on our executive officers, employees, and contractors. Although we believe that we will be able to identify, engage and motivate qualified personnel, an inability to do so could adversely affect our ability to market, sell, and develop our products and services. Any difficulty to attracting and retaining key people could have an adverse effect on our business.
SIGNIFICANT ADVERSE IMPACT TO OUR CAPITAL RESERVE OF ANY UNINSURED LIABILITY CLAIM.
We do not have any insurance to cover potential risks and liabilities, including, but not limited to, injuries or economic losses arising out of or relating to our omission or errors in providing our services. Even if we decide to obtain insurance coverage in the future, it is possible that: (1) we may not be able to get enough insurance to meet our needs; (2) we may have to pay very high premiums for the additional coverage; (3) we may not be able to acquire any insurance for certain types of business risk; or (4) we may have gaps in coverage for certain risks. We may be exposed to potential uninsured claims for which we could have to expend significant amounts of capital. Consequently, if we were found liable for a significant uninsured claim in the future, we may be forced to expend a significant amount of our capital to resolve the uninsured claim.
UNCERTAINTY OF PROFITABILITY.
Our business model requires significant investment in acquisitions and explorations, and, if and to the extent our business grows, we will need to hire new employees. Specifically, our profitability will depend upon our success at accomplishing the following tasks:
● implementing and executing our business model;
● establishing name recognition and a reputation for value with domestic and worldwide investors and partners;
● implementing results-oriented explorations, domestic and worldwide distribution and sales strategies; and
● developing sound business relationships with key strategic partners; and hiring and retaining skilled employees.
Additionally, our revenues and operating results may vary significantly from quarter-to-quarter due to a number of factors, including:
● economic conditions generally, as well as those specific to the oil and gas industry such as demand for petroleum generally and more specifically from small producers such as the Company and the pricing for the crude oil and gas we produce;
● our ability to manage relationships with industry and distribution partners to sell our production;
● our ability to access capital as needed, on terms which are fair and reasonable to the Company;
● our ability to successfully to produce high quality oil, and get that product to buyers in the intended manner; and
● the ability of third-party vendors to manage their procurement and delivery operations.
MANAGEMENT OF GROWTH.
Successful expansion of our business will depend on our ability to effectively attract and manage staff, strategic business relationships, and shareholders. Specifically, we will need to hire skilled management and technical personnel as well as manage partnerships to navigate shifts in the general economic environment as well as in our target geographic exploration locations. Expansion has the potential to place significant strains on financial, management, and operational resources, yet failure to expand will inhibit our profitability goals.
WE ARE IN A HIGHLY COMPETITIVE MARKET.
We expect to face substantial competition in the oil and gas industry. There are many exploration companies in the oil and gas industry which will compete directly with us. There are many large, well-capitalized, private and public companies in this industry, which have the resources, lease access, loyal buyers and expertise to drill and produce oil if they wish to do so. Many of our existing and potential competitors have substantially greater financial, technical and marketing resources than we do. These competitors may be able to adopt more aggressive pricing policies. This type of pricing pressure could force us to offer discounts, decreasing our profit margin.
CONFLICTS OF INTEREST.
The Company’s principal executive officer and director also controls a majority of the outstanding shares of the Company’s stock and will continue to do so for the foreseeable future. As a result, no other persons can or will be able to affect any Company action except with the consent of these officers and directors, and in certain matters (such as compensation, incentive stock ownership, and continues employment), there may be an inherent conflict of interest unless such persons agree to abstain from voting on such matters, which they are not legally required to do. Our officer and director may also serve as officers and directors of other entities that are not affiliated with us. Such non-affiliates may be involved in similar business enterprises to ours.
WE MAY INCUR SIGNIFICANT COSTS TO BE A PUBLIC COMPANY TO ENSURE COMPLIANCE WITH U.S. CORPORATE GOVERNANCE AND ACCOUNTING REQUIREMENTS AND WE MAY NOT BE ABLE TO ABSORB SUCH COSTS.
We may incur significant costs associated with our public company reporting requirements, costs associated with newly applicable corporate governance requirements, including requirements under the Sarbanes-Oxley Act of 2002 and other rules implemented by the Securities and Exchange Commission. We expect these costs to be at least $75,000 per year. We expect all of these applicable rules and regulations to significantly increase our legal and financial compliance costs and to make some activities more time consuming and costly. We also expect that these applicable rules and regulations may make it more difficult and more expensive, and nearly impossible for us to obtain director and officer liability insurance and if able to obtain coverages in the future, we may be required to accept reduced policy limits and coverage or incur substantially higher costs to obtain the same or similar coverage. As a result, it may be more difficult for us to attract and retain qualified individuals to serve on our board of directors or as executive officers. We are currently evaluating and monitoring developments with respect to these newly applicable rules, and we cannot predict or estimate the amount of additional costs we may incur or the timing of such costs. In addition, we may not be able to absorb these costs of being a public company which will negatively affect our business operations.
WHILE NOT APPLICABLE TO COMPANY CURRENTLY BECAUSE WE DO NOT MEET ANY OF THE ACCELERATED FILER REQUIREMENTS. IN THE FUTURE, THE PRICE OF OUR SHARES OF COMMON STOCK MAY DECLINE AND AN INABILITY TO OBTAIN FUTURE FINANCING IF THE COMPANY IS NOT ABLE TO COMPLY WITH THE ACCELERATED FILING AND INTERNAL CONTROL REPORTING REQUIREMENTS IMPOSED BY THE SEC.
As directed by Section 404 of the Sarbanes-Oxley Act, as amended by SEC Release No. 33-8934 on June 26, 2008, the SEC adopted rules requiring each public company to include a report of management on the company’s internal controls over financial reporting in its annual reports. In addition, the independent registered public accounting firm auditing a company’s financial statements must also attest to and report on management’s assessment of the effectiveness of the company’s internal controls over financial reporting as well as the operating effectiveness of the company’s internal controls. We will be required to include a report of management on its internal control over financial reporting. The internal control report must include a statement
● Of management’s responsibility for establishing and maintaining adequate internal control over its financial reporting;
● Of management’s assessment of the effectiveness of its internal control over financial reporting as of year-end; and
● Of the framework used by management to evaluate the effectiveness of our internal control over financial reporting.
Furthermore, if we become a larger company than currently, our independent registered public accounting firm will be required to file its attestation report separately on our internal control over financial reporting on whether it believes that we have maintained, in all material respects, effective internal control over financial reporting.
While we expect to expend significant resources in developing the necessary documentation and testing procedures required by Section 404 of the Sarbanes-Oxley Act, there is a risk that we may not be able to comply timely with all of the requirements imposed by this rule. In the event that we are unable to receive a positive attestation from our independent registered public accounting firm with respect to our internal controls, investors and others may lose confidence in the reliability of our financial statements and our stock price and ability to obtain equity or debt financing as needed could suffer.
In addition, in the event that our independent registered public accounting firm is unable to rely on our internal controls in connection with its audit of our financial statements, and in the further event that it is unable to devise alternative procedures in order to satisfy itself as to the material accuracy of our financial statements and related disclosures, it is possible that we would be unable to file our Annual Report on Form 10-K with the SEC, which could also adversely affect the market price of our Common Stock and our ability to secure additional financing as needed.
OUR ARTICLES OF INCORPORATION PROVIDE FOR INDEMNIFICATION OF OFFICERS AND DIRECTORS AT OUR EXPENSE AND LIMIT THEIR LIABILITY WHICH MAY RESULT IN A MAJOR COST TO US AND HURT THE INTERESTS OF OUR SHAREHOLDERS BECAUSE CORPORATE RESOURCES MAY BE EXPENDED FOR THE BENEFIT OF OFFICERS AND/OR DIRECTORS.
The Company’s Certificate of Incorporation and By-Laws include provisions that eliminate the personal liability of the directors of the Company for monetary damages to the fullest extent possible under the laws of the State of Nevada or other applicable law. These provisions eliminate the liability of directors to the Company and its stockholders for monetary damages arising out of any violation of a director of his fiduciary duty of due care. Under Nevada law, however, such provisions do not eliminate the personal liability of a director for (i) breach of the director’s duty of loyalty, (ii) acts or omissions not in good faith or involving intentional misconduct or knowing violation of law, (iii) payment of dividends or repurchases of stock other than from lawfully available funds, or (iv) any transaction from which the director derived an improper benefit. These provisions do not affect a director’s liabilities under the federal securities laws or the recovery of damages by third parties.
REPORTING REQUIREMENTS UNDER THE EXCHANGE ACT AND COMPLIANCE WITH THE SARBANES-OXLEY ACT OF 2002, INCLUDING ESTABLISHING AND MAINTAINING ACCEPTABLE INTERNAL CONTROLS OVER FINANCIAL REPORTING, ARE COSTLY AND MAY INCREASE SUBSTANTIALLY.
The rules and regulations of the SEC require a public company to prepare and file periodic reports under the Exchange Act, which will require that the Company engage legal, accounting, auditing and other professional services. The engagement of such services is costly. Additionally, the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”) requires, among other things, that we design, implement and maintain adequate internal controls and procedures over financial reporting. The costs of complying with the Sarbanes-Oxley Act and the limited technically qualified personnel we have may make it difficult for us to design, implement and maintain adequate internal controls over financial reporting. In the event that we fail to maintain an effective system of internal controls or discover material weaknesses in our internal controls, we may not be able to produce reliable financial reports or report fraud, which may harm our overall financial condition and result in loss of investor confidence and a decline in our share price.
As a public company, we will be subject to the reporting requirements of the Exchange Act, the Sarbanes-Oxley Act, the Dodd-Frank Act of 2010 and other applicable securities rules and regulations. Despite recent reforms made possible by the JOBS Act, compliance with these rules and regulations will nonetheless increase our legal and financial compliance costs, make some activities more difficult, time-consuming or costly and increase demand on our systems and resources. The Exchange Act requires, among other things, that we file annual, quarterly, and current reports with respect to our business and operating results.
The increased costs associated with operating as a public company may decrease our net income or increase our net loss, and may cause us to reduce costs in other areas of our business or increase the prices of our products or services to offset the effect of such increased costs. Additionally, if these requirements divert our management’s attention from other business concerns, they could have a material adverse effect on our business, financial condition and results of operations.
THE COMPANY MAY BE SUBJECT TO LITIGATION IN THE FUTURE WHICH COULD IMPACT THE FINANCIAL HEALTH OF THE COMPANY.
Currently there are no legal proceedings pending or threatened against the Company. However, from time to time, we may become involved in various lawsuits and legal proceedings that arise in the ordinary course of business. Litigation is subject to inherent uncertainties, and an adverse result in these or other matters may arise from time to time that may harm our business.
Risks Related To The Exploration Business
IMPACT OF COVID-19 AND RUSSIAN INVASION OF UKRAINE ON OUR BUSINESS.
Our business and operations have been adversely affected by the pandemic in 2020. In 2021, as result of initial reopening of business activities in recovery from COVID-19, and the invasion of Ukraine by the Russian Federation in March 2022, there has been a substantial increase in oil and gas prices from higher demand on energy. However, we cannot predict the future and the exact impact it will have on energy services and commodity prices due to other similar outbreaks or a peaceful resolution to the war that could cause a rapid decline in overall energy prices. Our financial condition and results of operations have been and are likely to continue to be affected by COVID-19 outbreak in other countries as well as the invasion of Ukraine by Russian forces in 2022.
The timeline and potential magnitude of COVID-19 or outcome to the war is currently unknown. The continuation or amplification of this virus, or war could continue to affect the US or the global economy, including our business and operations, and the supply and demand, more broadly for oil and gas prices and the industry.
AS WE CONTINUE TO DEVELOP OUR OPERATIONS, OUR PRODUCTION REVENUES MAY BE ADVERSELY AFFECTED BY CHANGES IN OIL AND GAS PRICES, AND IF WE ARE UNABLE TO BRING NEW OIL WELLS TO PRODUCTION WITH REASONABLE PRODUCTION CAPACITY.
The Company is an early-stage company in the oil and gas industry, which has ownership and working interests in wells and acreage. For the Company to reach strong stable production capacity it must raise enough capital to help the Company acquire and exploit new working interests in any future production wells. Any significant changes in oil prices or any inability on our part to anticipate or react to such changes could result in reduced revenues and profits and erosion of our competitive and financial position. Our success also depends on our ability to acquire good hydrocarbon production and bringing new oil wells to production with reasonable production capacity. In addition, changes from very shallow well to semi shallow well exploration or geographical exploration locations could result in higher costs of production and higher risks.
AS WE CONTINUE TO DEVELOP OUR OPERATIONS, PRODUCTION REVENUE MAY DECREASE OVER TIME DUE TO A VARIETY OF FACTORS.
As we continue to develop our operations, production revenue may decrease over time due to a variety of factors, including the aging of re-entry wells, changes in hydrocarbon flows, depletion, natural disasters, weather, negative publicity resulting from regulatory action or litigation against companies in our industry, or a downturn in economic conditions or taxes specifically targeting the consumption of oil and gas. Any of these changes may reduce our projected production revenues. Our success is also dependent on our technology innovations and applications, including maintaining production capacity, and the effectiveness of our advertising campaigns, marketing programs and market positioning. Although we will devote significant resources to meeting our revenue goals, there can be no assurance as to our ability either to explore new projects and launch successful new production, or to effectively execute explorations and new acquisitions. In addition, both the launch and ongoing success of new production and acquisitions are inherently uncertain, especially as to their appeal to our investors.
ANY DAMAGE TO OUR REPUTATION COULD HAVE AN ADVERSE EFFECT ON OUR BUSINESS, FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Maintaining a good reputation will be important to the Company. Adverse publicity about our operations, including the incidence of “dry holes” in exploration or low production wells, whether valid or not, may cause production and delivery disruptions. If any of our production wells becomes depleted for any reason, is mishandled or causes injury, we may be subject to legal liability. A widespread non-commercialized production or a significant depletion could cause our production to be disrupted for a period of time, which could further reduce our revenue and damage our corporate image. Failure to maintain high ethical, social and environmental standards for all of our operations and activities or adverse publicity regarding our responses to health concerns, our environmental impact, including drilling and production materials, energy use and waste management, or other sustainability issues, could jeopardize our reputation. In addition, water is a limited resource in many parts of the world. Our reputation could be damaged if we do not act responsibly with respect to water use of our exploration purposes. Failure to comply with local laws and regulations, to maintain an effective system of internal controls or to provide accurate and timely financial statement information could also hurt our reputation. Damage to our reputation or loss of buyer confidence in our oil production for any of these reasons could result in decreased demand for our products and could have a material adverse effect on our business, financial condition and results of operations, as well as require additional resources to rebuild our reputation.
AS WE CONTINUE TO DEVELOP OUR OPERATIONS, CHANGES IN THE LEGAL AND REGULATORY ENVIRONMENT COULD LIMIT OUR BUSINESS ACTIVITIES, INCREASE OUR OPERATING COSTS, AND REDUCE DEMAND FOR OUR PRODUCTION OR RESULT IN LITIGATION.
As we continue our operations, we will be subject to various laws and regulations administered by federal, state and local governmental agencies in the United States. These laws and regulations may change, sometimes dramatically, as a result of political, economic or social events. Such regulatory environment changes may include changes in: laws related to advertising and deceptive marketing practices; accounting standards; taxation requirements, including taxes specifically targeting the consumption of our products; anti-trust laws; and environmental laws, including laws relating to the regulation of oil and gas production. Changes in laws, regulations or governmental policy and related interpretations may alter the environment in which we do business and, therefore, may impact our results or increase our costs or liabilities. Governmental entities or agencies in jurisdictions where we plan to operate may also impose new quality or production requirements, or other restrictions. Regulatory authorities under whose laws we operate may also have enforcement powers that can subject us to actions such as product recall, seizure of products or other sanctions, which could have an adverse effect on our sales or damage our reputation.
The Company is still in the process of determining whether to use hydraulic fracturing in its operations. Hydraulic fracturing is a commonly used process that involves injecting water, sand, and small volumes of chemicals into the wellbore to fracture the hydrocarbon-bearing rock thousands of feet below the surface to facilitate higher flow of hydrocarbons into the wellbore. Various federal legislative and regulatory initiatives have been undertaken which could result in additional requirements or restrictions being imposed on hydraulic fracturing operations. For example, the Department of Interior has issued proposed regulations that would apply to hydraulic fracturing operations on wells that are subject to federal oil and gas leases and that would impose requirements regarding the disclosure of chemicals used in the hydraulic fracturing process as well as requirements to obtain certain federal approvals before proceeding with hydraulic fracturing at a well site. These regulations, if adopted, would establish additional levels of regulation at the federal level that could lead to operational delays and increased operating costs.
The US Congress has considered legislation that would require additional regulation affecting the hydraulic fracturing process. Consideration of new federal regulation and increased state oversight continues to arise. The US Environmental Protection Agency (“EPA”) announced in the first quarter of 2010 its intention to conduct a comprehensive research study on the potential effects that hydraulic fracturing may have on water quality and public health. The EPA issued a final report in June 2014.
At the same time, legislation and/or regulations have been adopted in several states that require additional disclosure regarding chemicals used in the hydraulic fracturing process but that include protections for proprietary information. Legislation and/or regulations are being considered at the state and local level that could impose further chemical disclosure or other regulatory requirements (such as restrictions on the use of certain types of chemicals or prohibitions on hydraulic fracturing operations in certain areas) that could affect our operations. The adoption of any future federal, state, or local laws or implementing regulations imposing reporting obligations on, or limiting or banning, the hydraulic fracturing process could make it more difficult to complete natural gas and oil wells and could have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial condition.
DISRUPTION OF OUR PROPOSED SUPPLY CHAIN COULD HAVE AN ADVERSE IMPACT ON OUR BUSINESS, FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Our ability and the ability of our suppliers, business partners, including drillers, operators, and independent buyers, to make, move and sell our products is critical to our success. Damage or disruption to our or their manufacturing or distribution capabilities due to adverse weather conditions, natural disaster, fire, terrorism, the outbreak or escalation of armed hostilities, pandemics, strikes and other labor disputes or other reasons beyond our or their control, could impair our ability to produce oil. So far in fiscal year 2022, as a result of the COVID-19 pandemic and official reaction to the pandemic, as well as war in Ukraine there has been severe, far-reaching disruptions to the oil and gas industry, generally, which also is affecting the Company. We expect to experience additional losses and we may have to change production. We recognize that a failure to take adequate steps to mitigate the likelihood or potential impact of such events, or to effectively manage such events if they occur, could adversely affect our business, financial condition and results of operations, as well as require additional resources to restore our supply chain.
AS WE CONTINUE TO DEVELOP OUR OPERATIONS, WE ARE BE SUBJECT TO HAZARDS AND RISKS INHERENT IN THE DRILLING, PRODUCTION, AND TRANSPORTATION OF CRUDE OIL AND NATURAL GAS
We will be subject to hazards and risks inherent in the drilling, production, and transportation of crude oil and natural gas, including: i) well blowouts, explosions and cratering, ii) pipeline ruptures and spills, iii) fires, iv) formations with abnormal pressures, v) equipment malfunctions, vi) natural disasters and vii) surface spillage and surface or ground water contamination from petroleum constituents or hydraulic fracturing chemical additives. Failure or loss of equipment, as the result of equipment malfunctions, cyber-attacks, or natural disasters such as hurricanes, could result in property damages, personal injury, environmental pollution and other damages for which we could be liable. Litigation arising from a catastrophic occurrence, such as those mentioned above, may result in substantial claims for damages. Ineffective containment of a drilling well blowout or pipeline rupture, or surface spillage and surface or ground water contamination from petroleum constituents or hydraulic fracturing chemical additives could result in extensive environmental pollution and substantial remediation expenses. If a significant amount of our production is interrupted, our containment efforts prove to be 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.
TERRORIST ATTACKS OR CYBER-INCIDENTS COULD RESULT IN INFORMATION THEFT, DATA CORRUPTION, OPERATIONAL DISRUPUTON AND/OR FINANCIAL LOSS.
Like most companies, we have become increasingly dependent upon digital technologies, including information systems, infrastructure and cloud applications and services, to operate our businesses, to process and record financial and operating data, communicate with our business partners, analyze mine and mining information, estimate quantities of coal reserves, as well as other activities related to our businesses. Strategic targets, such as energy-related assets, may be at greater risk of future terrorist or cyber-attacks than other targets in the United States. Deliberate attacks on, or security breaches in, our systems or infrastructure, or the systems or infrastructure of third parties, or cloud-based applications could lead to corruption or loss of our proprietary data and potentially sensitive data, delays in production or delivery, difficulty in completing and settling transactions, challenges in maintaining our books and records, environmental damage, communication interruptions, other operational disruptions and third-party liability. Our limited amount of insurance may not protect us against many types of such occurrences. Consequently, it is possible that any of these occurrences, or a combination of them, could have a material adverse effect on our business, financial condition, results of operations and cash flows. Further, as cyber incidents continue to evolve, we may be required to expend additional resources to continue to modify or enhance our protective measures or to investigate and remediate any vulnerability to cyber incidents.
Risks Related to Our Common Stock
THERE IS NO ASSURANCE THAT OUR COMMON STOCK WILL EVER TRADE ON A RECOGNIZED EXCHANGE. THEREFORE, YOU MAY BE UNABLE TO LIQUIDATE YOUR INVESTMENT IN OUR STOCK.
There is a limited public trading market for our common stock and there can be no assurance that one will ever develop. Market liquidity will depend on the availability of shares in the market place, on the perception of our operating business, and on any steps that our management might take to bring us to the awareness of investors. There can be no assurance given that there will be any awareness generated. Consequently, investors may not be able to liquidate their investment or liquidate it at a price that reflects the value of the business. As a result, holders of our securities may not find purchasers for our securities should they decide to sell. Consequently, our securities should be purchased only by investors having no need for liquidity in their investment and who can hold our securities for an indefinite period of time.
WE MAY NEVER PAY ANY DIVIDENDS TO SHAREHOLDERS.
We currently intend to retain any future earnings for use in the operation and expansion of our business. Accordingly, we do not expect to pay any dividends in the foreseeable future but will review this policy as circumstances dictate.
OUR COMMON STOCK IS CONSIDERED A PENNY STOCK, WHICH MAY BE SUBJECT TO RESTRICTIONS ON MARKETABILITY, SO YOU MAY NOT BE ABLE TO SELL YOUR SHARES.
We currently are subject to the SEC’s “penny stock” rules while our shares of Common Stock sell below $5.00 per share. Penny stocks generally are equity securities with a price of less than $5.00. The penny stock rules require broker-dealers to deliver a standardized risk disclosure document prepared by the SEC which provides information about penny stocks and the nature and level of risks in the penny stock market. The broker-dealer must also provide the customer with current bid and offer quotations for the penny stock, the compensation of the broker-dealer and its salesperson, and monthly account statements showing the market value of each penny stock held in the customer’s account. The bid and offer quotations, and the broker-dealer and salesperson compensation information must be given to the customer orally or in writing prior to completing the transaction and must be given to the customer in writing before or with the customer’s confirmation.
In addition, the penny stock rules require that prior to a transaction; the broker dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser’s written agreement to the transaction. The penny stock rules are burdensome and may reduce purchases of any offerings and reduce the trading activity for shares of our Common Stock. As long as our shares of Common Stock are subject to the penny stock rules, the holders of such shares of Common Stock may find it more difficult to sell their securities.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments.
This information is not required for smaller reporting companies.

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ITEM 2. PROPERTIES
Item 2. Properties.
The Company headquarters is at 102 Palo Pinto St. Suite B Weatherford, Texas 76086. The Company terminated its prior lease agreement and has a new month-to-month rental agreement that started in August 28, 2018 at rate of $950 per month.

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings.
Not applicable.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures.
Not Applicable.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Market Information
Since April 2016, the Company’s shares of common stock have traded on the OTC Market under the ticker symbol “INWP.” The symbol was changed to “NRIS” after the Company’s name change in February 2018.
The common stock only trades occasionally, in low volume amounts. A recent trade was on May 10, 2022, for which day the closing price was approximately $0.11.
Holders of Common Stock
As of May 12, 2022, we had 118 shareholders of record of our common stock. We believe we have at least an additional 100 shareholders, who hold their shares of common stock under “street name.”
Dividend Policy
The Company has never paid cash dividends on its common stock and does not anticipate paying dividends in the foreseeable future. The payment of future cash dividends is subject to the discretion of the Board of Directors and will depend upon the Company’s earnings (if any), general financial condition, cash flows, capital requirements and other considerations deemed relevant by the Board of Directors.
Recent Sales of Unregistered Securities
None
Securities Authorized for Issuance Under Equity Compensation Plans.
We currently do not have an equity compensation plan.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. Selected Financial Data
We are not required to provide the information required by this Item because we are a smaller reporting company.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
Overview
Norris Industries, Inc. (the “Company”, “we”, or “us”) is an oil and natural gas company that focuses on the acquisition, development, and exploration of crude oil and natural gas properties in Texas. As of March 1, 2022 the SEC Non-Escalated Analysis of Estimated Proved Reserve of our various leases in Jack County and Palo-Pinto County, the Ratliff leases, the Marshall-Walden, and the Bend Arch Lion 1A and Bend Arch Lion 1B leaseholds, is a total of 29 Mbbl in oil net reserves, plus 150 MMcf in natural gas net reserves being out of total of BOE equivalent of 54 Mbbl in gross reserves, which is down from prior year by 322 Mbbl due to reduction of expected production as result of well workover issues.
The reserves associated with the report from Kurt Mire , PE have been classified in accordance with the definitions of the Securities and Exchange Commission as found in Part 210 - Form and Content of and Requirements for Financial Statements, Securities Act of 1933, Securities Exchange Act of 1934, Public Utility Holding Company Act of 1935, Investment Company Act of 1940, Investment Advisers Act of 1940, and Energy Policy and Conservation Act of 1975, under Rules of General Application § 210.4-10 Financial accounting and reporting for oil and gas producing activities pursuant to the Federal securities laws and the Energy Policy and Conservation Act of 1975.
The Company’s longer term main objective is to actively focus on improving its existing fields and to look for additional reserve oil and gas concessions and production opportunities, aiming to participate with capital partners for a transaction related to buyouts and joint ventures. The Company will continue to conserve capital to be able to focus on smaller oil and natural gas properties in West, Central West, East and South Texas, aiming to increase its revenues via an acquisition. It also will try to improve the existing production revenues of the Bend Arch Lion 1A, Bend Arch Lion 1B, Marshall Walden joint venture property, which includes the purchase of the leases in Jack County and Palo Pinto County, re-entries and EOR methods as mentioned in the Operational Plan section above.
The Company ultimately plans to tap into the high potential leases of the West Texas region of the United States, aiming to obtain reserves for future development, so as to increase its overall oil and gas assets in the Permian Basin. The Permian Basin is a sedimentary basin largely contained in the western part of the U.S. state of Texas and the southeastern part of the U.S. state of New Mexico. It reaches from just south of Lubbock, TX, to just south of Midland and Odessa, TX, extending westward into the southeastern part of New Mexico. It is so named because it has one of the world’s thickest deposits of rocks from the Permiangeologic period. The greater Permian Basin comprises several component basins: of these, Midland Basin is the largest, Delaware Basin is the second largest, and Marfa Basin is the smallest. The Permian Basin extends beneath an area approximately 250 miles (400 km) wide and 300 miles (480 km) long.
Results of Operations
Revenues
The Company generated revenues of $452,291 from oil and gas production sales during the year ended February 28, 2022, compared to $280,160 during the year ended February 28, 2021. The increase in oil and gas sales revenues was primarily due to the dramatic increase in oil and gas prices obtained from buyers due to the increases of energy prices due to recovery of global demand and instability of possible supply disruptions due to Russia invasion of Ukraine.
Because of the disruption to the oil and gas industry caused by recovery of demand from the COVID-19 pandemic and world supply disruptions from Russia the Company expects that there will be continued volatility of energy prices and Company cannot make a prediction of its expected revenues for fiscal year 2023.
Lease Operating Expenses
Lease operating expenses for the years ended February 28, 2022 and February 28, 2021, were $599,455 and $552,713, respectively. We incurred slightly higher lease operating expenses in 2022 primarily because of higher costs of operations primarily as a result of the increased prices of oil and gas due to recovering industry caused by the events described above.
Operating Expenses
Operating expenses for the years ended February 28, 2022 and February 28, 2021, were $203,682 and $313,515, respectively. The decrease was primarily due to management implementing cost controls to lower the general and administrative expenses incurred by the Company.
Depletion and Accretion Expenses
For the years ended February 28, 2022 and February 28, 2021, the Company recorded depletion and accretion expense of $41,109 and $235,001, respectively, related to depletion of oil and gas properties and amortization of asset retirement obligations. The decrease was majorly resulted from higher oil and gas reserves evaluated as of March 1, 2022, which majorly due to higher oil and gas prices in the market. The Company recognized lower depletion expenses for the current fiscal year due to the greater oil and gas reserve as of the fiscal year end to be depleted in future years.
Impairment Expense
For the years ended February 28, 2022 and February 28, 2021, the Company recorded impairment of $nil and $196,197, respectively, related to a ceiling test write-down of its oil and gas properties.
Other Income (Expense)
For the years ended February 28, 2022 and February 28, 2021, the Company recorded interest expense of $106,992 and $92,526, respectively. Higher interest expense was incurred in 2022 due to additional debt issuances to related parties in the current year.
Net Loss
Our operations resulted in a net loss in the amount of $498,947 for the year ended February 28, 2022, compared to a net loss of $1,109,792 for the year ended February 28, 2021. The decrease was primarily related to lower SG&A costs recognized during the current fiscal year and lower impairment recognized from our oil and gas properties.
Liquidity and Capital Resources
On February 28, 2022, the Company had cash of $139,569.
Net cash used in operating activities during the year ended February 28, 2022, was $421,062, compared to cash used in operating activities of $504,650 for the same period in 2021. The decrease was primarily related to slightly lower expenses incurred from our oil and gas properties.
Net cash used in investing activities during years ended February 28, 2022 and 2021, was $-0-.
During the year ended February 28, 2022, cash provided by financing activities was $400,000 related to proceeds from the Company’s related party loans. Net cash provided by financing activities during the year ended February 28, 2021, was $507,200, related to proceeds of $500,000 from the Company’s line of credit with JBB and proceeds of $7,200 from the exercise of stock options.
The Company will require additional financing to support its operations and to pursue its acquisition program. As of February 28, 2022, the Company had availability of $600,000 on its existing credit line with JBB. If the Company requires additional financing beyond what is available under its existing credit line, it does not have any committed sources of financing at this time. If it is unable to obtain financing, it will have to reduce or curtail its operations and acquisition program. There is no assurance that it will be able to obtain financing in the future, and even if financing is available, it may not be on terms acceptable to the Company.
To date, the funding during the past three fiscal years to support operations and facilitate some acquisitions has been provided by the largest shareholder of the Company. This individual does not have any legal obligation to continue to provide funding to the Company. Yet the majority owner has indicated a willingness, and provided some assurances, to selectively review and determine added funding for certain low risk initiatives on those oil and gas wells in which the Company has either a 100% or a majority working interest in order to increase its existing production. Our majority shareholder expects, but is not legally obligated, to provide funding for the Company’s capital expenditure program for fiscal year 2023. Such funding may be provided in the form of loans, issuance of equity or other means.
The financial statements of the Company have been prepared on a going concern basis. The Company will either have to increase its operating revenues to a point to be able to cover its operating expenses or obtain funding from other investors or lenders. There is no assurance that the Company will be able to increase its revenues or obtain funding. The Company believes that it will experience revenue disruption and declines as a result of the COVID-19 pandemic and the government response thereto as well as the war and general political instability in Europe due to Russian Federation invasion of Ukraine. If it is not able to do so, it will have to adjust operations or cease operations. There is no assurance that the Company will be able to continue its operations. In such instances, investors will suffer a loss in the value of their investment in the Company.
Off-Balance Sheet Arrangements
As of February 28, 2022, we did not have any off-balance sheet arrangements as defined in Item 303(a)(4)(ii) of Regulation S-K promulgated under the Securities Act of 1934.
Critical Accounting Policies
We believe it is helpful to investors to understand the critical accounting policies underlying our financial statements and the following discussion of our company’s financial condition and results of operations.
Significant Accounting Policies.
Our significant accounting policies relate to use of estimates, cash, accounts receivable and allowance for doubtful accounts, property and equipment, revenue recognition, income taxes, impairment or disposal of long-lived assets, asset retirement obligations, and computation of earnings per share.
Use of Estimates.
The nature of our business requires that we make estimates and assumptions in accordance with U.S. GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, as well as the reported amounts of revenue and expenses during the reporting period. These estimates are based on information as of the date of the consolidated financial statements. Significant estimates required to be made by management include, but are not limited to, the valuation of accounts receivable, depletion and accretion, and oil and gas reserves. Actual results could differ from those estimates. The ongoing COVID-19 pandemic has impacted these estimates and assumptions and will continue to do so.
The ongoing COVID-19 pandemic and related governmental responses, volatility in commodity prices, and severe weather resulting from climate change have impacted and likely will continue to impact our business. Under earlier state and federal mandates that regulated business closures, our business was deemed as an essential business and, as such, remained open. As U.S. federal, state, and local officials address surging coronavirus cases and roll out COVID-19 vaccines, we expect to continue operating.
In February 2022, Russia invaded neighboring Ukraine. The conflict has caused turmoil in global markets, resulting in higher oil prices, and injected even more uncertainty into a worldwide economy recovering from the effects of COVID-19. Given the evolving conflict, there are many unknown factors and events that could materially impact our operations.
We have instituted various initiatives throughout the company as part of our business continuity programs, and we are working to mitigate risk when disruptions occur. The Russian conflict with Ukraine and the COVID-19 pandemic continue to evolve. Therefore, uncertainty around the availability and commodity prices of crude oil, the commodity prices and demand for our refined products, and the general business environment is expected to continue through 2022 and beyond.
We assessed certain accounting matters that generally require consideration of forecasted financial information in context with the information reasonably available to us and the unknown future impacts of the Russian-Ukrainian conflict and COVID-19 as of February 28, 2022 and through the filing date of this report. The accounting matters assessed included, but were not limited to, our allowance for doubtful accounts and related reserves, and the carrying value of long-lived assets.
Oil and Gas Properties, Full Cost Method
The Company follows the full cost method of accounting for its oil gas properties, whereby all costs incurred in connection with the acquisition, exploration for and development of petroleum and natural gas reserves are capitalized. Such costs include lease acquisition, geological and geophysical activities, rentals on non-producing leases, drilling, completing and equipping of oil wells and administrative costs directly attributable to those activities and asset retirement costs. Disposition of oil properties are accounted for as a reduction of capitalized costs, with no gain or loss recognized unless such adjustment would significantly alter the relationship between capital costs and proved reserves of oil and gas, in which case the gain or loss is recognized in the statement of operations.
Depletion and depreciation of proved oil properties will be calculated on the units-of-production method based upon estimates of proved reserves. Such calculations include the estimated future costs to develop proved reserves. Costs of unproved properties are not included in the costs subject to depletion. These costs are assessed periodically for impairment.
At the end of each quarter, the unamortized cost of oil and gas properties, net of related deferred income taxes, is limited to the sum of the estimated future after-tax net revenues from proved properties, after giving effect to cash flow hedge positions, discounted at 10%, and the lower of cost or fair value of unproved properties, adjusted for related income tax effects. Costs in excess of the present value of estimated future net revenues are charged to impairment expense. This limitation is known as the “ceiling test,” and is based on SEC rules for the full cost oil and gas accounting method.
The Company capitalizes pre-acquisition costs directly identifiable with specific properties when the acquisition of such properties is probable. Capitalized pre-acquisition costs are presented in the balance sheet.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative and Qualitative Disclosures About Market Risk.
We are a smaller reporting company and are not required to provide the information under this item.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data.
Report of Independent Registered Public Accounting Firm (PCAOB ID 171)
Report of Independent Registered Public Accounting Firm (PCAOB ID Number 688)
Financial Statements:
Consolidated Balance Sheets - As of February 28, 2022 and February 28, 2021
Consolidated Statements of Operations - For the Years Ended February 28, 2022 and February 28, 2021
Consolidated Statement of Changes in Stockholders’ Equity - For the Years Ended February 28, 2022 and February 28, 2021
Consolidated Statements of Cash Flows - For the Years Ended February 28, 2022 and February 28, 2021
Notes to Consolidated Financial Statements
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and the Board of Directors of Norris Industries, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheet of Norris Industries, Inc. (the “Company”) as of February 28, 2022, the related consolidated statements of operations, stockholders’ deficit and cash flows, for the year then ended, and the related notes (collectively, the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of February 28, 2022, and the results of its operations and its cash flows for the year then ended in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audit included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audit provides a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the board of directors and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Depreciation, depletion and amortization (“DD&A”) of proved oil and gas properties
At February 28, 2022, the net carrying value of the Company’s oil and gas properties was $176,553 and depreciation, depletion and amortization (“DD&A”) expense was $41,109 for the year then ended. As described in Note 1 to the financial statements, the Company follows the full cost method of accounting for its oil and gas properties. Under the full cost method, all costs incurred in connection with the acquisition, exploration for and development of petroleum and natural gas reserves are capitalized. Such costs include lease acquisition, geological and geophysical activities, rentals on non-producing leases, drilling, completing, and equipping of oil wells and administrative costs directly attributable to those activities and asset retirement costs. DD&A of the cost of proved oil and gas properties is calculated using the unit-of-production method based on proved oil and gas reserves, as estimated by the Company’s independent reserve engineering firm. Significant judgment is required in evaluating geoscience and engineering data when estimating proved oil and gas reserves. Estimating reserves also requires the use of inputs, including oil and gas prices and operating and capital costs assumptions, among others. Because of the complexity involved in estimating oil and gas reserves, management used an independent reserve engineering firm to estimate proved oil and gas reserves as of February 28, 2022.
Auditing the Company’s DD&A calculation is especially complex and judgmental because of our use of the work of the Company’s independent reserve engineering firm and the evaluation of management’s determination of the inputs described above used by the independent reserve engineering firm in estimating proved oil and gas reserves.
We obtained an understanding of the Company’s controls over its process to calculate DD&A, including management’s controls over the completeness and accuracy of the financial data provided to the engineers for use in estimating oil and gas reserves.
Our audit procedures included, among others, evaluating the professional qualifications and objectivity of the independent reserve engineers primarily responsible for the preparation of the reserve estimates for select properties. In addition, in assessing whether we can use the work of the engineers, we evaluated the completeness and accuracy of the financial data and inputs described above used by the engineers in estimating oil and gas reserves by agreeing them to source documentation, and we identified and evaluated corroborative and contrary evidence. We also tested the mathematical accuracy of the DD&A calculation, including comparing the oil and gas reserve amounts used in the calculation to the Company’s reserve reports.
/s/ HORNE LLP
We have served as the Company’s auditor since 2021.
Ridgeland, Mississippi
June 15, 2022
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Shareholders and Board of Directors of
Norris Industries, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheet of Norris Industries, Inc. (the “Company”) as of February 28, 2021, the related consolidated statements of operations, stockholders’ deficit and cash flows for the year ended February 28, 2021, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of February 28, 2021, and the results of its operations and its cash flows for the year ended February 28, 2021, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audit. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audit included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audit provides a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period audit of the financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Depreciation, depletion and amortization and impairment of oil and gas properties
At February 28, 2021, the net carrying value of the Company’s oil and gas properties was $220,850, depreciation, depletion and amortization (“DD&A”) expense was $235,001, and impairment expense was $196,197 for the year then ended. As described in Note 1, the Company follows the full cost method of accounting for its oil and gas properties. DD&A of the cost of proved oil and gas properties is calculated using the unit-of-production method based on proved oil and gas reserves, as estimated by the Company’s external reservoir engineers. Under the full cost method, a ceiling test is performed each quarter. The ceiling test determines a limit, on a country-by-country basis, on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated DD&A, impairment, and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves. If capitalized costs exceed this limit, the capitalized cost is reduced to fair value. Proved oil and gas reserves are those quantities of natural gas, crude oil, condensate, and natural gas liquids, which by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations. Additionally, the expected future cash flows used for impairment reviews and related fair value calculations are based on judgmental assessments of future production volumes from estimated oil and gas reserves. Significant judgment is required by the Company’s external reservoir engineers in evaluating geological and engineering data when estimating oil and gas reserves. Estimating reserves also requires the selection of inputs, including oil and gas price assumptions, future operating and capital costs assumptions, and tax rates by jurisdiction, among others. Because of the complexity involved in estimating oil and gas reserves, management engaged independent petroleum engineers to prepare the proved oil and gas reserve estimates for select properties as of February 28, 2021. Auditing the Company’s DD&A and impairment calculations is complex because of the use of the work of the independent petroleum engineers and the evaluation of management’s determination of the inputs described above used by the engineers in estimating oil and gas reserves.
We obtained an understanding of the Company’s controls over its process to calculate DD&A and impairment, including management’s controls over the completeness and accuracy of the financial data provided to the engineers for use in estimating oil and gas reserves.
Our audit procedures included, among others, evaluating the professional qualifications and objectivity of the independent petroleum engineers primarily responsible for the preparation of the reserve estimates for select properties. In addition, in assessing whether we can use the work of the engineers, we evaluated the completeness and accuracy of the financial data and inputs described above used by the engineers in estimating oil and gas reserves by agreeing them to source documentation, and we identified and evaluated corroborative and contrary evidence. For proved undeveloped reserves, we evaluated management’s development plan for compliance with the SEC rule that undrilled locations are scheduled to be drilled within five years, unless specific circumstances justify a longer time, by assessing consistency of the development projections with the Company’s development plan and the availability of capital relative to the development plan. We also tested the mathematical accuracy of the DD&A and impairment calculations, including comparing the oil and gas reserve amounts used in the calculations to the Company’s reserve reports.
/s/ Marcum LLP
Marcum llp
We served as the Company’s auditor from 2018 to 2021.
Houston, Texas
June 1, 2021
NORRIS INDUSTRIES, INC.
CONSOLIDATED BALANCE SHEETS
FEBRUARY 28, 2022 AND 2021
ASSETS
Current Assets
Cash $ 139,569 $ 160,631
Account receivable - oil & gas 70,946 32,890
Total Current Assets 210,515 193,521
Oil and Gas Property - Full Cost Method
Properties subject to amortization 2,982,455 2,989,156
Less: accumulated depletion and impairment (2,805,902 ) (2,768,306 )
Total Oil and Gas Property, net 176,553 220,850
Total Assets $ 387,068 $ 414,371
LIABILITIES AND STOCKHOLDERS’ DEFICIT
Current Liabilities
Accounts payable and accrued expenses $ 139,404 $ 171,564
Accounts payable and accrued expenses - related party - 233,510
Total Current Liabilities 139,404 405,074
Convertible notes payable - related party 3,600,000 3,200,000
Accounts payable and accrued expenses - related party - long-term 340,502 -
Asset retirement obligations 92,822 96,010
Total Liabilities 4,172,728 3,701,084
Stockholders’ Deficit
Preferred stock, $0.001 par value per share 20,000,000 shares authorized: - -
Series A Convertible Preferred stock, $0.001 par value per share 1,000,000 shares authorized; 1,000,000 shares issued and outstanding; liquidation preference of $2,250,000 1,000 1,000
Common stock, $0.001 par value per share, 150,000,000 shares authorized; 90,883,013 and 90,883,013 shares issued and outstanding 90,883 90,883
Additional paid-in capital 6,286,399 6,286,399
Accumulated deficit (10,163,942 ) (9,664,995 )
Total Stockholder’s Deficit (3,785,660 ) (3,286,713 )
Total Liabilities and Stockholders’ Deficit $ 387,068 $ 414,371
The accompanying notes are an integral part of these consolidated financial statements.
NORRIS INDUSTRIES, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
FOR THE YEARS ENDED FEBRUARY 28, 2022 AND 2021
Revenues
Oil and gas sales $ 452,291 $ 280,160
Total Revenues 452,291 280,160
Operating Expenses
Lease operating expenses 599,455 552,713
General and administrative expenses 203,692 313,515
Impairment expense - 196,197
Depletion, depreciation and accretion 41,109 235,001
Total Operating Expenses 844,256 1,297,426
Loss from Operations (391,955 ) (1,017,266 )
Interest Expenses (106,992 ) (92,526 )
Net Loss $ (498,947 ) $ (1,109,792 )
Net loss per common share - basic and diluted $ (0.01 ) $ (0.01 )
Weighted average number of common shares outstanding - basic and diluted 90,883,013 90,883,013
The accompanying notes are an integral part of these consolidated financial statements.
NORRIS INDUSTRIES, INC.
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ DEFICIT
FOR THE YEARS ENDED FEBRUARY 28, 2022 AND 2021
Shares Amount Shares Amount Capital Receivable Deficit Equity
Series A Convertible Preferred Stock Common Stock Additional
Paid-in
Subscription Accumulated Total
Stockholders’
Shares Amount Shares Amount Capital Receivable Deficit Equity
Balance, February 29, 2020 1,000,000 1,000 90,883,013 $ 90,883 $ 6,286,399 $ (7,200 ) $ (8,555,203 ) $ (2,184,121 )
Collection from subscription receivable - - - - - 7,200 - 7,200
Net loss - - - - - - (1,109,792 ) (1,109,792 )
Balance, February 28, 2021 1,000,000 1,000 90,883,013 90,883 6,286,399 - (9,664,995 ) (3,286,713 )
Net loss - - - - - - (498,947 ) (1,109,792 )
Balance, February 28, 2022 1,000,000 $ 1,000 90,883,013 $ 90,883 $ 6,286,399 $ - $ (10,163,942 ) $ (3,785,660 )
The accompanying notes are an integral part of these consolidated financial statements.
NORRIS INDUSTRIES, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED FEBRUARY 28, 2022 AND 2021
Cash Flow from Operating Activities
Net loss $ (498,947 ) $ (1,109,792 )
Adjustments to reconcile net loss to net cash used in operating activities:
Depletion, depreciation and accretion 41,109 235,001
Impairment expense - 196,197
Changes in operating assets and liabilities:
Accounts receivable - oil & gas (38,056 ) 5,659
Accounts payable and accrued expenses (32,160 ) 77,259
Accounts payable and accrued expenses - related party 106,992 91,026
Net Cash Used in Operating Activities (421,062 ) (504,650 )
Cash Flow from Financing Activities
Proceeds from related party loans 400,000 500,000
Collection of subscription receivable - 7,200
Net Cash Provided by Financing Activities 400,000 507,200
Net (Decrease) Increase in Cash (21,062 ) 2,550
Cash - beginning of year 160,631 158,081
Cash - end of year $ 139,569 $ 160,631
Supplemental Cash Flow Information
Interest paid $ - $ -
Income tax paid $ - $ -
The accompanying notes are an integral part of these consolidated financial statements.
NORRIS INDUSTRIES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Organization, Nature of Operations and summary of Significant Accounting Policies
Norris Industries, Inc. (“NRIS” or the “Company”), was incorporated on February 19, 2014 as a Nevada corporation. The Company was formed to conduct operations in the oil and gas industry. The Company’s principal operating properties are in the Ellenberger formation in Coleman County, and in Jack County and Palo-Pinto County Texas. The Company’s production operations are all located in the State of Texas.
On April 25, 2018, the Company incorporated a Texas registered subsidiary, Norris Petroleum, Inc., as its own operating entity.
Basis of Presentation
The accompanying financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules of the Securities and Exchange Commission (“SEC”). The Company’s consolidated financial statements include the accounts of the Company, its wholly-owned subsidiaries and entities in which the Company has a controlling financial interest. All significant inter-company accounts and transactions have been eliminated in consolidation.
Liquidity and Capital Considerations
The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business for the twelve-month period following the issuance date of these consolidated financial statements.
The Company’s business and operations have been adversely affected by and are expected to continue to be adversely affected by the recent COVID-19 outbreak and may be adversely affected in the future by other similar outbreaks.
As a result of the recent COVID-19 outbreak, including voluntary and mandatory quarantines, travel restrictions and other restrictions, the Company’s operations, and those of its subcontractors, customers and suppliers, have and are anticipated to continue to experience delays or disruptions and temporary suspensions of operations. In addition, the Company’s financial condition and results of operations have been and are likely to continue to be adversely affected by the COVID-19 outbreak.
The timeline and potential magnitude of the COVID-19 outbreak and the Ukraine-Russia war is currently unknown. The continuation or amplification of this virus could continue to more broadly affect the United States and global economy, including our business and operations, and the demand, for oil and gas.
The Company has incurred continuing losses since 2016, including a loss of $498,947 for the fiscal year ended February 28, 2022. During the fiscal year ended February 28, 2022, the Company received $400,000 in funding from its credit line and incurred cash losses of $421,062 from its operating activities. As of February 28, 2022, the Company had $600,000 available to borrow under its existing credit line with JBB Partners, Inc. (“JBB”), an affiliate of the Company’s Chief Executive Officer. As of February 28, 2022, the Company had a cash balance of approximately $140,000 and working capital of approximately $71,000. The Company has extended its maturity date to September 30, 2023.
The Company’s principal capital and exploration expenditures during next fiscal year are expected to relate to selected well workovers on its Jack and Palo Pinto County acreages. The Company believes that it has sufficient cash on hand and available funds from its line of credit to fund its costs for such expenditures as well as other operating costs, for the 12 month period subsequent to issuance of these financial statements.
In the event that the Company requires additional capital to fund higher operational losses or oil and gas property lease purchases for fiscal year ending February 28, 2023, the Company expects to seek additional capital from one or more sources via restricted private placement sales of equity and debt securities from those other than JBB. However, there can be no assurance that the Company would be able to secure the necessary capital to fund its costs on acceptable terms, or at all. If, for any reason, the Company is unable to fund its operations, it would have to undertake other aggressive cost cutting measures and then be subject to possible loss of some of its rights and interests in prospects to curtail operations and forced to forego opportunities or in worst case, cease operations.
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 and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expense during the period. Actual results could differ from those estimates.
Risks and Uncertainties
The Company’s operations are subject to significant risks and uncertainties, including financial, operational, technological, and other risks associated with operating an emerging business, including the potential risk of business failure.
Cash and Cash Equivalents
The Company considers all highly liquid investments purchased with an original maturity of the year or less to be cash equivalents. The Company has not experienced any losses on its deposits of cash and cash equivalents.
Oil and Gas Properties, Full Cost Method
The Company follows the full cost method of accounting for its oil and gas properties, whereby all costs incurred in connection with the acquisition, exploration for and development of petroleum and natural gas reserves are capitalized. Such costs include lease acquisition, geological and geophysical activities, rentals on non-producing leases, drilling, completing and equipping of oil wells and administrative costs directly attributable to those activities and asset retirement costs. Disposition of oil properties are accounted for as a reduction of capitalized costs, with no gain or loss recognized unless such adjustment would significantly alter the relationship between capital costs and proved reserves of oil and gas, in which case the gain or loss is recognized in the statement of operations.
Depletion and depreciation of proved oil properties are calculated on the units-of-production method based upon estimates of proved reserves. Such calculations include the estimated future costs to develop proved reserves. Costs of unproved properties are not included in the costs subject to depletion. These costs are assessed periodically for impairment.
At the end of each quarter, the unamortized cost of oil and gas properties, net of related deferred income taxes, is limited to the sum of the estimated future after-tax net revenues from proved properties, after giving effect to cash flow hedge positions, discounted at 10%, and the lower of cost or fair value of unproved properties, adjusted for related income tax effects. Costs in excess of the present value of estimated future net revenues are charged to impairment expense. This limitation is known as the “ceiling test,” and is based on SEC rules for the full cost oil and gas accounting method.
Income Taxes
Income taxes are accounted for in accordance with the provisions of ASC Topic No. 740. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement 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. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Valuation allowances are established, when necessary, to reduce deferred tax assets to the amounts expected to be realized.
Uncertain Tax Positions
The Company evaluates uncertain tax positions to recognize a tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained on examination by the taxing authorities based on the technical merits of the position. Those tax positions failing to qualify for initial recognition are recognized in the first interim period in which they meet the more likely than not standard or are resolved through negotiation or litigation with the taxing authority, or upon expiration of the statute of limitations. De-recognition of a tax position that was previously recognized occurs when an entity subsequently determines that a tax position no longer meets the more likely than not threshold of being sustained.
Revenue Recognition
The Company’s revenue is comprised entirely of revenue from exploration and production activities. The Company’s oil is sold primarily to wholesalers and others that sell product to end use customers. Natural gas is sold primarily to interstate and intrastate natural-gas pipelines, various end-users, local distribution companies, and natural-gas marketers. NGLs are sold primarily to various end-users. Payment is generally received from the customer in the month following delivery.
Contracts with customers have varying terms, including spot sales or month-to-month contracts, or contracts with a finite term, where the production from a well or group of wells is sold to one or more customers. The Company recognizes sales revenues for oil, natural gas, and NGLs based on the amount of each product sold to a customer when control transfers to the customer. Generally, control transfers at the time of delivery to the customer at a pipeline interconnect, the tailgate of a processing facility, or as a tanker lifting is completed. Revenue is measured based on the contract price, which may be index-based or fixed, and may include adjustments for market differentials and downstream costs incurred by the customer, including gathering, transportation, and fuel costs.
Revenues are recognized for the sale of the Company’s net share of production volumes. Sales on behalf of other working interest owners and royalty interest owners are not recognized as revenues. The Company does not hedge nor forward sell any of its current production via derivative financial contracts.
Share-based Compensation
The Company estimates the fair value of each share-based compensation award at the grant date by using the Black-Scholes option pricing model. The fair value determined represents the cost for the award and is recognized over the vesting period during which an employee is required to provide service in exchange for the award. Share-based compensation expense is recognized based on awards ultimately expected to vest. Excess tax benefits, if any, are recognized as an addition to paid-in capital.
Net Loss per Common Share
Basic net loss per common share amounts are computed by dividing the net loss available to the Company’s shareholders by the weighted average number of common shares outstanding over the reporting period. In periods in which the Company reports a net loss, dilutive securities are excluded from the calculation of diluted earnings per share as the effect would be anti-dilutive. The following table summarizes the common stock equivalents excluded from the calculation of diluted net loss per as the inclusion of these shares would be anti-dilutive for the years ended February 28, 2022 and February 28, 2021:
Schedule of Antidilitive Securities Excluded from Computation of Earning Per Shares
Series A Convertible Preferred Stock 66,666,667 66,666,667
Convertible debt 21,000,000 16,000,000
Total Common Shares to be issued 87,666,667 82,666,667
Concentrations of Credit Risk
Financial instruments which potentially subject the Company to concentrations of credit risk include cash deposits placed with financial institutions. The Company maintains its cash in bank accounts which, at times, may exceed federally insured limits as guaranteed by the Federal Deposit Insurance Corporation (“FDIC”). At February 28, 2022, $-0- of the Company’s cash balances was uninsured. The Company has not experienced any losses on such accounts.
Recently Issued Accounting Pronouncements
In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326), Measurement of Credit Losses on Financial Instruments. The standard replaces the incurred loss impairment methodology in current U.S. GAAP with a methodology that reflects expected credit losses on instruments within its scope, including trade receivables. This update is intended to provide financial statement users with more decision-useful information about the expected credit losses. The effective date of ASU No. 2016-13 will be the first quarter of the Company’s fiscal 2022 with early adoption permitted. The Company is currently evaluating the impact of the adoption of ASU No. 2016-13 on its consolidated financial statements.
The Company does not expect the adoption of any other recently issued accounting pronouncements to have a significant impact on its financial position, results of operations, or cash flows.
Subsequent Events
In preparing these consolidated financial statements, the Company has evaluated events and transactions for potential recognition or disclosure through the date these consolidated financial statements were issued.
Note 2 - Revenue from Contracts with Customers
Disaggregation of Revenue from Contracts with Customers
The following table disaggregates revenue by significant product type for the years ended February 28, 2022 and 2021:
Schedule of Disaggregation of Revenue
Oil sales $ 293,872 $ 208,347
Natural gas sales 158,419 71,813
Total $ 452,291 $ 280,160
There were no significant contract liabilities or transaction price allocations to any remaining performance obligations as of February 28, 2022 and February 28, 2021.
Note 3 - Oil and Gas Properties
The following table summarizes the Company’s oil and gas activities by classification for the years ended February 28, 2022 and 2021:
Summary of Oil and Gas Activities
February 29, 2020 Additions Dispositions February 28, 2021
Oil and gas properties, subject to amortization $ 2,930,237 $ - $ - $ 2,930,237
Asset retirement costs 69,224 (10,305 ) - 58,919
Accumulated depletion (2,341,261 ) (427,045 ) - (2,768,306 )
Total oil and gas assets $ 658,200 $ (437,350 ) $ - $ 220,850
February 28, 2021 Additions Dispositions February 28, 2022
Oil and gas properties, subject to amortization $ 2,930,237 $ - $ - $ 2,930,237
Asset retirement costs 58,919 (6,701 ) - 52,218
Accumulated depletion (2,768,306 ) (37,596 ) - (2,805,902 )
Total oil and gas assets $ 220,850 $ (437,350 ) $ - $ 176,553
The depletion recorded for production on proved properties for the years ended February 28, 2022 and February 28, 2021, amounted to $41,109 and $230,848, respectively. During the years ended February 28, 2022 and February 28, 2021, the Company recognized impairment expense of $-0- and $196,197, respectively, related to a ceiling test write-down of its oil and properties subjection to amortization.
Note 4 - Asset Retirement Obligations
The following table summarizes the change in the Company’s asset retirement obligations during the year ended February 28, 2022:
Schedule of Asset Retirement Obligations
Asset retirement obligations as of February 28, 2021 $ 96,010
Additions -
Current year revision of previous estimates (6,701 )
Accretion during the year ended February 28, 2022 3,513
Asset retirement obligations as of February 28, 2022 $ 92,822
During the year ended February 28, 2022, the Company decreased the asset retirement obligations estimate by $6,701 and recognized accretion expense of $3,513. During the year ended February 28, 2021, the Company recognized accretion expense of $4,153.
Note 5 - Related Party Transactions
Promissory Note to JBB
On December 28, 2017, the Company borrowed $1,550,000 from JBB to complete the purchases of a series of oil and gas leases (the “Loan Note”). The loan has an interest rate of 3% per annum, a maturity date of December 28, 2018 and is secured by all assets of the Company. The loan is convertible to the Company’s common stock at the conversion rate of $0.20 per share.
On June 26, 2018, the Company and JBB entered into a modification of the existing Loan Note, to add provisions to permit the Company to obtain additional advances under the Loan Note up to a maximum of $1,000,000. The Company may request an advance in increments of $100,000 no more frequently than every 30 days, provided that (i) it provides a description of the use of proceeds for the advance reasonably acceptable to JBB, and (ii) the Company is not otherwise in default of the Loan Note. The original loan amount and the advances are secured by all the assets of the Company and are convertible into common stock of the Company at the rate of $0.20 per common share, subject to adjustment for any reverse and forward stock splits. The Loan Note may be repaid at any time, without penalty, however, any advance that is repaid before maturity may not be re-borrowed as a further advance.
On May 21, 2019, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note to September 30, 2020.
On June 13, 2019, JBB lent the Company $250,000 under a secured promissory note. The funds were used to acquire the remaining working interest in the Marshall Walden oil and gas property from Odyssey Enterprises LLC. The loan has an interest rate of 5% per annum, a maturity date of June 30, 2022, and is secured by all assets of the Company. The loan is convertible into the Company’s common stock at a conversion rate of $0.20 per common share.
On October 1, 2019, the Company entered into another amendment of its Loan Note with JBB to increase the line of credit by an additional $500,000, for a total of $1,500,000, and extend the maturity date for the original note and line of credit to December 31, 2020.
On May 29, 2020, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note to September 30, 2021.
On December 22, 2020, the Company entered into an extension agreement with JBB to extend the maturity of all its outstanding indebtedness under credit line and Loan Note to May 31, 2022.
On May 1, 2021, the Company entered into a new funding agreement with a maturity date of May 31, 2022 and an interest rate of five percent annual percentage rate (5% APR) with JBB for a further $1 million drawable in $100,000 increments at the discretion of JBB to cover the Company’s current and projected working capital requirements in near-term. The loan is convertible into common stock of the Company at the rate of $0.08 per share, subject to adjustment for any reverse and forward stock splits. As of February 28, 2022, the Company has availability of $600,000 on its $1,000,000 credit line entered into May 1, 2021.
On May 2, 2022, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note to September 30, 2023.
During the year ended February 28, 2022, JBB advanced $400,000 to fund the Company’s operations under the Loan Note. As of February 28, 2022, the Company had availability of $600,000 on its existing credit line with JBB.
During the year ended February 28, 2021, JBB advanced $500,000 to fund the Company’s operations under the Loan Note.
The Company recognized interest expense of $106,992 and $92,526 for the years ended February 28, 2022 and February 28, 2021, respectively. Accrued interest as of February 28, 2022 and February 28, 2021 was $342,001 and $233,510, respectively. As of February 28, 2022 and February 28, 2021, there was $3,600,000 and $3,200,000, respectively, outstanding under notes payable to JBB.
Note 6 - Commitments and Contingencies
Office Lease
As of September 1, 2018, the Company moved to the offices of International Western Oil Corp. (“IWO”), a related party, in Weatherford, TX that is being rented on a month-to-month sublease basis at rate of $950 per month from IWO. During the years ended February 28, 2022 and February 28, 2021, the Company incurred $11,400 and $11,400, respectively, of rent expense under this lease that is included in general and administrative expenses on the consolidated statement of operations.
Leasehold Drilling Commitments
The Company’s oil and gas leasehold acreage is subject to expiration of leases if the Company does not drill and hold such acreage by production or otherwise exercises options to extend such leases, if available, in exchange for payment of additional cash consideration. In the King County, Texas lease acreage, 640 acres were due to expire in June 2021; and the Company chose not to extend this lease.
Note 7 - Equity Transactions
There were no issuances of common stock (or common stock activity) during the years ended February 28, 2022 and 2021.
On January 6, 2020, one of the officers exercised the option and purchased 720,000 shares of the Company’s common stock at an exercise price of $0.01 per share, for total of $7,200. The Company fully collected the outstanding proceed from the officer during the fiscal year ended February 28, 2021.
Note 8 - Income Taxes
Due to the Company’s net losses and the valuation allowance provided on the related deferred tax assets, there were no provisions for income taxes for the years ended February 28, 2022 and February 28, 2021.
The difference between the income tax expense of zero shown in the statement of operations and pre-tax book net loss times the federal statutory rate of 21% for the years ended February 28, 2022 and February 28, 2021, respectively, are summarized as follows:
Schedule of Effective Income Tax Expense Reconciliation
Pretax book loss $ (104,779 ) $ (233,056 )
Permanent differences:
Return to provision adjustment 258,989
Impairment expense - 41,201
Change in valuation allowance (154,210 ) 191,855
Total tax expense $ - $ -
Deferred income tax assets for the years ended February 28, 2022 and February 28, 2021 are as follows:
Schedule of Deferred Income Tax Assets
Deferred Tax Assets
Net operating losses carry forwards $ 2,099,902 $ 2,167,036
Others 104,779 191,855
Total deferred tax assets 2,204,681 2,358,891
Less valuation allowance (2,204,681 ) (2,358,891 )
Total deferred tax assets $ - $ -
In assessing the realization of deferred tax assets, management considers whether it is more likely than not that some portion or all of deferred assets will not be realized. The ultimate realization of the deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.
Based on the available objective evidence, management believes it is more likely than not that the net deferred tax assets will not be fully realizable. Accordingly, management has applied a full valuation allowance against its net deferred tax assets at February 28, 2022 and February 28, 2021. The net change in the total valuation allowance from February 28, 2022 and February 28, 2021, was a decrease of $154,210.
The Company’s policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax expense. As of February 28, 2022, and February 28, 2021, the Company did not have any significant uncertain tax positions or unrecognized tax benefits.
As of February 28, 2022, the Company has federal net operating loss carryforwards of approximately $10,498,478 for federal tax purposes, respectively. If not utilized, federal net operating loss carryforwards approximating $1.4 million will expire beginning in 2038. The remaining net operating loss carryforwards have no statutory expiration.
Utilization of NOL and tax credit carryforwards may be subject to a substantial annual limitation due to ownership change limitations that may have occurred or that could occur in the future, as required by the Internal Revenue Code (the “Code”), as amended, as well as similar state provisions. In general, an “ownership change” as defined by the Code results from a transaction or series of transactions over a three-year period resulting in an ownership change of more than 50 percent of the outstanding stock of a company by certain shareholders or public groups. The Company experienced an “ownership change” within the meaning of IRC Section 382 during the year ended February 28, 2022. As a result, certain limitations apply to the annual amount of net operating losses that can be used to offset post ownership change taxable income.
Note 9 - Subsequent Events
On May 2, 2022, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note and funding agreement to September 30, 2023.
Note 10 - Supplemental Oil and Gas Disclosures (Unaudited)
Capitalized Costs Relating to Oil and Gas Producing Activities
The estimates of proved oil and gas reserves utilized in the preparation of these statements were prepared by Kurt Mire for the years ended February 28, 2022 and 2021, using reserve definitions and pricing requirements prescribed by the SEC. The Company used a combination of production performance and offset analogies, along with estimated future operating and development costs as provided by the Company and based upon historical costs adjusted for known future changes in operations or developmental plans, to estimate its reserves.
There are numerous uncertainties inherent in estimating quantities of proved reserves, projecting future rates of production and projecting the timing of development expenditures, including many factors beyond our control. The reserve data represents only estimates. Reservoir engineering is a subjective process of estimating underground accumulations of natural gas and oil that cannot be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretations and judgment. All estimates of proved reserves are determined according to the rules prescribed by the SEC. These rules indicate that the standard of “reasonable certainty” be applied to the proved reserve estimates. This concept of reasonable certainty implies that as more technical data becomes available, a positive, or upward, revision is more likely than a negative, or downward, revision. Estimates are subject to revision based upon a number of factors, including reservoir performance, prices, economic conditions and government restrictions. In addition, results of drilling, testing and production subsequent to the date of an estimate may justify revision of that estimate. Reserve estimates are often different from the quantities of natural gas and oil that are ultimately recovered. The meaningfulness of reserve estimates is highly dependent on the accuracy of the assumptions on which they were based. In general, the volume of production from natural gas and oil properties we own declines as reserves are depleted. Except to the extent we conduct successful development activities or acquire additional properties containing proved reserves, or both, our proved reserves will decline as reserves are produced. There have been no major discoveries or other events, favorable or adverse, that may be considered to have caused a significant change in the estimated proved reserves since February 28, 2022. The Company emphasizes that reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. In addition, a portion of the Company’s proved reserves are proved developed non-producing and proved behind pipe, which increases the imprecision inherent in estimating reserves which may ultimately be produced.
All of the Company’s reserves are located in the United States.
Schedule of Capitalized Costs Relating to Oil and Gas Producing Activities
February 28, 2022 February 28, 2021
Proved oil and gas properties $ 2,982,455 $ 2,989,156
Unproved oil and gas properties - -
Accumulated depreciation, depletion, amortization and impairment (2,805,902 ) (2,768,306 )
Total acquisition, development and exploration costs $ 176,553 $ 220,850
Estimated Quantities of Proved Oil and Gas Reserves
The following table sets forth proved oil and gas reserves together with the changes therein, proved developed reserves and proved undeveloped reserves for the years ended February 28, 2022 and 2021. Units of oil are in thousands of barrels (“MBbls”) and units of gas are in millions of cubic feet (“MMcf”). Gas is converted to barrels of oil equivalents (“MBoe”) using a ratio of six Mcf of gas per Bbl of oil.
Schedule of Estimated Quantities of Proved Oil and Gas Reserves
Oil Gas BOE Oil Gas BOE
Proved reserves:
Beginning of year 29
Revisions (9 ) (50 ) (17 )
Extensions and discoveries - - - - - -
Purchases of minerals-in-place
Sales of minerals-in-place - - - - - -
Production (5 ) (30 ) (10 ) (5 ) (47 ) (13 )
End of year 15
Proved developed reserves:
Beginning of year 29
End of year 8
Proved not producing reserves:
Beginning of year - - -
End of year 7
Proved undeveloped reserves:
Beginning of year - - - -
End of year - - -
Standardized Measure of Discounted Future Net Cash Flows and Changes Therein Relating to Proved Reserves
The standardized measure of discounted future net cash flows, in management’s opinion, should be examined with caution. The basis for this table is the reserve studies prepared by the Company’s independent petroleum engineering consultants, which contain imprecise estimates of quantities and rates of future production of reserves. Revisions of previous year estimates can have a significant impact on these results. Also, exploration costs in one year may lead to significant discoveries in later years and may significantly change previous estimates of proved reserves and their valuation. Therefore, the standardized measure of discounted future net cash flow is not necessarily indicative of the fair value of the Company’s proved oil and natural gas properties.
Future cash inflows for 2022 were computed by applying the average price for the year to the year-end quantities of proved reserves. The 2022 average price for the year was calculated using the 12-month period prior to the ending date of the period covered by the report, determined as an un-weighted arithmetic average of the first-day-of-the-month price for each month within such period. Adjustment in this calculation for future price changes is limited to those required by contractual arrangements in existence at the end of each reporting year. Future development, abandonment and production costs were computed by estimating the expenditures to be incurred in developing and producing proved oil and natural gas reserves at the end of the year, based on year-end costs, assuming continuation of year-end economic conditions. Future income tax expense was computed by applying statutory rates, less the effects of tax credits for each period presented, and to the difference between pre-tax net cash flows relating to the Company’s proved reserves and the tax basis of proved properties, after consideration of available net operating loss and percentage depletion carryovers. Discounted future net cash flows have been calculated using a ten percent discount factor. Discounting requires a year-by-year estimate of when future expenditures will be incurred and when reserves will be produced.
The estimated present value of future cash flows relating to prove reserves is extremely sensitive to prices used at any measurement period. The prices used for each commodity for the years ended February 28, 2022 and 2021, as adjusted, were as follows:
Schedule of Estimated Present Value of Future Cash Flows Relating to Prove Reserves
Oil (Bbl)
Using
NYMEX
WTI Gas (Mcf)
Using
NYMEX
Henry Hub
2022 (average price) $ 71.67 $ 3.95
2021 (average price) $ 38.69 $ 2.08
The information provided in the tables set out below does not represent management’s estimate of the Company’s expected future cash flows or of the value of the Company’s proved oil and gas reserves. Estimates of proved reserve quantities are imprecise and change over time as new information becomes available. Moreover, probable and possible reserves, which may become proved in the future, are excluded from the calculations. The arbitrary valuation prescribed under ASC No. 932 requires assumptions as to the timing and amount of future development and production costs. The calculations should not be relied upon as an indication of the Company’s future cash flows or of the value of its oil and gas reserves.
The following table sets forth the standardized measure of discounted future net cash flows relating to proven reserves for the years ended February 28, 2022 and 2021, respectively (stated in thousands):
Schedule of Discounted Future Net Cash Flows Relating to Proven Reserves
Future cash inflows $ 2,381 $ 626
Future costs:
Production costs (1,244 ) (269 )
Future tax expense (182 ) (47 )
Future development costs (189 ) (29 )
Future net cash flows
10% annual discount for estimated timing of cash flows (164 ) (60 )
Standardized measure of discounted net cash flows $ 602 $ 221
Summary of Changes in Standardized Measure of Discounted Future Net Cash Flows
The following table summarizes the principal sources of change in the standardized measure of discounted future estimated net cash flows at 10% per annum for the years ended February 28, 2022 and 2021, respectively (stated in thousands):
Summary of Changes in Standardized Measure of Discounted Future Net Cash Flows
Increase (decrease):
Beginning of year $ 221 $ 658
Sales of oil produced, net of production costs
Net changes in sales and transfer prices and in production costs and production costs related to future production (220 )
Previously estimated development costs incurred during the period - -
Changes in future development costs (189 ) (29
Revisions of previous quantity estimates due to prices and performance (156 )
Accretion of discount
Discoveries, net of future production and development costs associated with these extensions and discoveries - -
Purchases and sales of minerals in place - -
Timing and other (1,411 )
End of year $ 602 $ 221

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. Controls and Procedures.
Disclosure of Controls and Procedures
(a) Evaluation of disclosure and Control Procedures
We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our reports, filed under the Securities Exchange Act of 1934, 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 chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable and not absolute assurance of achieving the desired control objectives. In reaching a reasonable level of assurance, management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures. In addition, the design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Over time, a control may become inadequate because of changes in conditions or the degree of compliance with policies or procedures may deteriorate. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected.
(b) Management’s Report on Internal Controls over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Internal control over financial reporting is defined in Rule 13a-15(f) under the Exchange Act as a process designed by, or under the supervision of, the Company’s principal executive officer and principal financial officer and effected by the Company’s Board of Directors, management and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles and includes those policies and procedures that:
(i) Pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company;
(ii) Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with management authorization; and
(iii) Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company’s assets that could have a material effect on the financial statements.
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.
Our management assessed the effectiveness of our internal control over financial reporting as of February 28, 2022. In making this assessment, the Company’s management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) under the 2013 Internal Control-Integrated Framework.
Based on this assessment, our management concluded that, as of February 28, 2022, our internal control over financial reporting is not effective. In connection with the assessment described above, management identified the following control deficiencies that represent material weaknesses at February 28, 2022:
(i) The Company does not have accounting personnel with extensive experience in maintaining books and records and preparing financial statements in accordance with US GAAP which could lead to untimely identification and resolution of accounting matters inherent in the Company’s financial transactions in accordance with US GAAP.
(ii) The Company does not have policies and procedures in place to ensure the timely review, disclosure and accurate financial reporting for significant agreements and transactions.
(iii) The Company does not have an independent audit committee in place, which would provide oversight of the Company’s officers, operations and financial reporting function.
(iv) The Company does not have sufficient accounting personnel to have a separation of their respective accounting duties.
Management’s Remediation Plan
The management believes that the Company’s financial statements previously filed in the Company’s SEC reports have been properly recorded and disclosed in accordance with US GAAP, notwithstanding the control deficiencies identified above. The Company does not have an active remediation plan in operation at this time. If and when the Company has greater financial resources, it plans to engage additional persons and/or engage consultants to address the various deficiencies that are identified above.
This annual report does not include an attestation report of our 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 the exemption provided to issuers that are neither “large accelerated filers” nor “accelerated filers” under the Dodd-Frank Wall Street Reform and Consumer Protection Act.
(c) Changes in Internal Controls
No change in our internal control over financial reporting occurred during the last fiscal quarter ended February 28, 2022, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information.
None.
PART III

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. Directors, Executive Officers and Corporate Governance
The following table sets forth the names and ages of our principal officers and directors as of May 31, 2022. Our executive officers are elected annually by our Board of Directors. Our executive officers hold their offices until they resign, are removed by the Board, or his successor is elected and qualified.
Name
Age
Position
Patrick L. Norris
Chairman of the Board of Directors, President, Chief Executive Officer, Chief Financial Officer
Ross Henry Ramsey
President of the Oil and Gas Division and Director
Set forth below is a brief description of the background and business experience of our executive officer and director for the past five years.
Patrick L. Norris is the founder of Norris International Services, LLC, a specialty machine shop in New Iberia, Louisiana, that was started in 2004, and serves the oil field petroleum parts, tubulars, and the utility road boring industries. Mr. Norris has been in the specialty manufacturing business for over 39 years.
Mr. Norris’ qualifications to serve on our Board include his experience in the oil and gas industry, and significant investment made into enterprises from his own resources.
Ross Henry Ramsey is a co-founder of the Company and served as the Chief Executive Officer, President, Chief Financial Officer, from inception until 2017. Mr. Ramsey is a Director of the Company, a position that he has held since inception. Mr. Ramsey is currently the President of the Oil and Gas division of the Company. Since 2011, Mr. Ramsey has been the Chief Executive Officer and President of International Western Oil Corporation, making it an active explorer through Central West Texas. He also served as President of the Company, which is the holding company of International Western Oil Corporation. From 2010 to 2011, Mr. Ramsey served as an independent drilling and completion consultant. Mr. Ramsey’s specializes in drilling acreage and establishing PUD’S (Proven Under Development locations) for new drilling locations and multiple recovery methods from primary to and secondary recovery methods. Mr. Ramsey has been involved with over 100 well bores, from drilling and testing, to completion. Mr. Ramsey has been a production specialist as part of the exploration in Young County, Coke County, Fischer County, Jones County and Taylor County, all of which are in Texas.
Mr. Ramsey’s qualifications to serve on our Board include his experience in the oil and gas industry.
Director and Officer Term of Office
Our directors are appointed for a one-year term to hold office until the next annual general meeting of our shareholders or until removed from office in accordance with our bylaws. Our officers hold their offices until they resign, are removed by the Board, or their successor is elected and qualified.
Family Relationships
None.
Promoters and Control Persons
None.
Code of Ethics
The Company has not adopted any formal Code of Ethics.
Committees of the Board of Directors
The Board of Directors does not have any separately designated audit committee, compensation committee, or nominating committee. The functions of those committees are undertaken by our Board of Directors. The Board of Directors believes that the creation of these committees, at this time, would be cumbersome and constitute more form over substance insofar as there are only two directors, and they perform those functions at this time.
Section 16(a) Beneficial Ownership Reporting Compliance
Under Section 16(a) of the Exchange Act, all executive officers, directors, and each person who is the beneficial owner of more than 10% of the common stock of a company that files reports pursuant to Section 12 of the Exchange Act, are required to report the ownership of such common stock, options, and stock appreciation rights (other than certain cash-only rights) and any changes in that ownership with the SEC. Specific due dates for these reports have been established, and the Company is required to report, in this Form 10-K, any failure to comply therewith during the fiscal year ended February 28, 2022. The Company believes that all of these filing requirements were satisfied by its executive officers, directors and by the beneficial owners of more than 10% of the Company’s common stock during the fiscal year ended February 28, 2022. In making this statement, the Company has relied solely on copies of any reporting forms received by it, and upon any written representations received from reporting persons that no Form 5 (Annual Statement of Changes in Beneficial Ownership) was required to be filed under applicable rules of the SEC.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation
Compensation of Executives
During the years ended February 28, 2022, and February 28, 2021. Mr. Patrick Norris received compensation of $1,500 per month for an annual amount of $18,000. Mr. Ross Ramsey was paid a monthly salary of $6,600 from the Company, for an annual amount of $79,200. No other amounts were paid, or benefits provided to Mr. Ross.
The Company does not provide any retirement, pension, profit sharing, insurance programs, long-term incentive plans or other similar programs have been adopted by us for the benefit of our employees. The Company did not have any new equity-based awards program for its directors, officers or employees during the current year.
Compensation of Directors
The current directors, each of whom is an executive officer, are not paid any director fees. Under our by-laws, directors are permitted to receive fixed fees and other compensation for their services as directors. The Board of Directors has the authority to fix the compensation of directors.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
The following table sets forth certain information as of May 31, 2022, with respect to the holdings of: (1) each person known to us to be the beneficial owner of more than 5% of our Common Stock; (2) each of our directors, nominees for director and named executive officers; and (3) all directors and executive officers as a group. To the best of our knowledge, each of the persons named in the table below as beneficially owning the shares set forth therein has sole voting power and sole investment power with respect to such shares, unless otherwise indicated. Unless otherwise specified, the address of each of the persons set forth below is in care of the Company, at the address of the company c/o Norris Industries, Inc., 102 Palo Pinto St. Suite B, Weatherford, Texas 76086.
Name of Beneficial Owner Amount
and
Nature of
Beneficial
Ownership Percent of
Common
Stock (1)
Directors and Executive Officers:
Patrick L. Norris, President, Chairman, Board of Directors and CEO/CFO (2) 57,840,000 65.64 %
Ross Henry Ramsey, President of the Oil and Gas Division, and Director 500,000 0.01 %
All directors and executive officers as a group (2 persons) 58,750,000 64.64 %
5% Stockholders:
Patrick L. Riggs (3) 5,900,000 6.49
(1) Based on 90,883,013 shares of common stock outstanding as of May 31, 2022.
(2) Excludes (i) the number of shares of common stock into which the 1,000,000 Series A Preferred Stock may be converted, which currently is 66,666,667 shares of common stock and (ii) the number of shares of common stock into which the aggregate of $3,600,000 convertible notes, owned by JBB Partners, Inc, may be converted which currently is 18,00,000 shares of common stock.
(3) This information is based upon the Schedule 13D filed by Patrick Riggs and Riggs Capital. The address for Patrick Riggs is 10530 Normont Drive, Houston, TX 77070.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence
International Western Oil Corp. (“IWO”)
Mr. Ramsey is the owner and sole officer of IWO. IWO serves as a Texas-licensed oil and gas operator and on-site consultant for the Company to provide the Company with operating support, full geology reports, on-site survey work, initial reserve analysis and additional geology consulting work on an as-needed basis.
During the years ended February 28, 2022 and February 28, 2021, IWO contributed no capital to the Company.
Series A Preferred Stock
On August 2, 2017, the Company entered into a modification of the secured, promissory note with JBB Partners, Inc., a company controlled by Mr. Patrick Norris, originally entered into on April 11, 2017 (“Note”). The principal amount was increased by $550,000, to a total of $750,000, and the maturity date for all the sums advanced was extended to July 28, 2018. The Note, as amended and extended, was modified to be convertible into the Series A Preferred Stock, which itself is convertible into Common Stock of the Company. The Company paid no cash interest on the Note until the date of conversion to Series A Preferred Stock on February 21, 2019.
The Series A Preferred Stock has certain dividend, liquidation, voting and conversion rights. When and as declared by the Company’s Board of Directors, the holders of Series A Preferred Stock is entitled to participate prior to any dividends paid on the Company’s common stock. The Series A Preferred Stock Original Issuance Price is $0.75 per share. In the event of any liquidation, dissolution or winding up of the Company or any Deemed Liquidation Event (as defined in the Certificate of Designation), the holders of Series A Preferred Stock will be entitled to receive, prior to and in preference to the holders of Common Stock, an amount per share of Series A Preferred Stock equal to three (3) times the Series A Preferred Stock Original Issue Price, plus any declared but unpaid dividends thereon, which is the full principal amount of the Note of $750,000.
The Series A Preferred Stock will vote together with the Common Stock on an as-converted basis and not as a separate class, except as provided in the Certificate of Designation or required by law. The Company will not take the following actions, without the prior approval of the holders owning a majority of the issued and outstanding Series A Preferred Stock: (i) dissolve or liquidate the Company; (ii) amend, alter or repeal any provision of the Articles of Incorporation or bylaws of the Company in any manner that adversely affects the powers, privileges or preferences of the Series A Preferred Stock; (iii) reclassify, alter or amend any existing equity security of the Company that is pari passu with or junior to the Series A Preferred Stock; (iv) purchase or redeem any capital stock of the Company, other than (a) redemptions of or dividends or distributions on the Series A Preferred Stock as expressly authorized therein, (b) dividends or other distributions payable on the Common Stock solely in the form of additional shares of Common Stock, and (c) stock repurchased from former employees, directors or consultants in connection with the cessation of their employment/services, at the lower of fair market value or cost; (v) create or issue any debt security, if the aggregate indebtedness of the Company and its subsidiaries for borrowed money following such action would exceed $250,000; and (vi) enter into any transaction with a “related person” as defined in Item 404 of Regulation S-K under the Securities Exchange Act of 1934.
Holders of the Series A Preferred Stock have the right to convert shares of Series A Preferred Stock, at any time and from time to time, into such number of fully paid and non-assessable shares of Common Stock as is determined by the number of shares Series A Preferred Stock, divided by the product of (i) the Preferred Stock Conversion Price in effect at the time of conversion and (ii) 0.02. The “Preferred Stock Conversion Price” shall initially be equal to $0.75 (as an example: 10,000 shares of Series A Preferred Stock / (0.75 x 0.02) will equal 666,666.66 shares of Common Stock). Such Preferred Stock Conversion Price shall be subject to adjustment as in the event of stock split, merger, reorganization and certain dividend and distribution. There is no mandatory conversion or redemption right by the Company.
JBB Partners, Inc. (“JBB”) Loan Note
On December 28, 2017, the Company borrowed $1,550,000 from JBB to complete the purchases of a series of oil and gas leases (the “Loan Note”). The loan has an interest rate of 3% per annum, a maturity date of December 28, 2018 and is secured by all assets of the Company. The loan is convertible to the Company’s common stock at the conversion rate of $0.20 per share.
On June 26, 2018, the Company and JBB entered into a modification of the existing Loan Note, to add provisions to permit the Company to obtain additional advances under the Loan Note up to a maximum of $1,000,000. The Company may request an advance in increments of $100,000 no more frequently than every 30 days, provided that (i) it provides a description of the use of proceeds for the advance reasonably acceptable to JBB, and (ii) the Company is not otherwise in default of the Loan Note. The original loan amount and the advances are secured by all the assets of the Company and are convertible into common stock of the Company at the rate of $0.20 per common share, subject to adjustment for any reverse and forward stock splits. The Loan Note may be repaid at any time, without penalty, however, any advance that is repaid before maturity may not be re-borrowed as a further advance.
On May 21, 2019, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note to September 30, 2020.
On June 13, 2019, JBB lent the Company $250,000 under a secured promissory note. The funds were used to acquire the remaining working interest in the Marshall Walden oil and gas property from Odyssey Enterprises LLC. The loan has an interest rate of 5% per annum, a maturity date of June 30, 2022, and is secured by all assets of the Company. The loan is convertible into the Company’s common stock at a conversion rate of $0.20 per common share.
On October 1, 2019, the Company entered into another amendment of its Loan Note with JBB to increase the line of credit by an additional $500,000, for a total of $1,500,000, and extend the maturity date for the original note and line of credit to December 31, 2020.
On May 29, 2020, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note to September 30, 2021.
On December 22, 2020, the Company entered into an extension agreement with JBB to extend the maturity of all its outstanding indebtedness under credit line and Loan Note to May 31, 2022.
On May 1, 2021, the Company entered into a new funding agreement with a maturity date of May 31, 2022 and an interest rate of five percent annual percentage rate (5% APR) with JBB for a further $1 million drawable in $100,000 increments at the discretion of JBB to cover the Company’s current and projected working capital requirements in near-term. The loan is convertible into common stock of the Company at the rate of $0.08 per share, subject to adjustment for any reverse and forward stock splits. At February 28, 2022, the Company has availability of $600,000 on its $1,000,000 credit line entered into May 1, 2021.
On May 2, 2022, the Company entered into an extension agreement with JBB to extend the maturity of its outstanding Loan Note and funding agreement to September 30, 2023.
During the year ended February 28, 2021, JBB advanced $500,000 to fund the Company’s operations under the Loan Note. As of February 28, 2021, the Company had availability of $100,000 on its existing credit line with JBB.
During the year ended February 28, 2022, JBB advanced $400,000 to fund the Company’s operations under the Loan Note. As of February 28, 2022, the Company had availability of $600,000 on its existing credit line with JBB.
The Company recognized interest expense of $106,992 and $92,526 for the years ended February 28, 2022 and February 28, 2021, respectively. Accrued interest as of February 28, 2022 and February 28, 2021 was $342,001 and $235,010, respectively. On May 2, 2022, the Company entered into an extension agreement with JBB to extend the accrued interest payable due date to September 30, 2023.. As of February 28, 2022, and February 28, 2021, there was $3,600,000 and $3,200,000, respectively, outstanding under notes payable to JBB.
Director Independence and Committees
Neither Mr. Ross Henry Ramsey nor Mr. Patrick Norris are considered independent because they are both executive officers of the Company, and, in the case of Mr. Patrick Norris, hold beneficially more than 50% of the Company’s shares of common stock outstanding.
We do not currently have a separately designated audit, nominating or compensation committee. The regular function of these committees are handled by the board of directors.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accounting Fees and Services
The following table presents fees for professional services provided by HORNE LLP for the audit of our annual financial statements for the year ended February 28, 2022:
HORNE LLP Year Ended
February 28, 2022
Audit Fees (1) $ 74,000
Audit-Related Fees (2) -
Tax Fees (3) 14,000
All Other Fees (4) -
Total $ 88,000
The following table presents fees for professional services provided by Marcum LLP for the audit of our annual financial statements for the year ended February 28, 2021:
Marcum Year Ended
February 28, 2021
Audit Fees (1) $ 69,420
Audit-Related Fees (2) -
Tax Fees (3) 48,295
All Other Fees (4) -
Total $ 117,715
(1) Audit fees include professional services rendered for (i) the audit of our annual financial statements for the years ended February 28, 2022 and 2021 and (ii) the reviews of the financial statements included in our quarterly reports on Form 10-Q for such years.
(2) Audit-related fees consist of fees billed for professional services that are reasonably related to the performance of the audit or review of our consolidated financial statements but are not reported under “Audit fees.”
(3) Tax fees include professional services relating to preparation of the annual tax return.
(4) Other fees include professional services for review of various filings and issuance of consents.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits, Financial Statement Schedules
(a) List of the following documents filed as part of the report:
(1) See the index to our consolidated financial statements on page for a list of the financial statements being filed in this Annual Report.
(2) All financial statement schedules are omitted because they are not applicable, or the required information is shown in the consolidated financial statements or the notes thereto.
(3) See Item 15(b) below for all exhibits being filed or incorporated by reference herein.
(b) Exhibits:
The Exhibit Index attached to this Annual Report is incorporated by reference herein.
EXHIBITS - NORRIS INDUSTRIES, INC.
Exhibit
Incorporated by Reference
Filed or Furnished
Number
Exhibit Description
Form
Exhibit
Filing Date
Herewith
3.1(a)
Articles of Incorporation
S-1
3.1
6/3/2014
3.1(b)
Amendment to Articles of Incorporation (Change of Name, Increase in Capitalization, Creation of Blank Check Preferred)
8-K
3.1
2/26/2018
3.1(c)
Amendment to Articles of Incorporation (Creation of Series A Preferred Stock
8-K
3.2
2/26/2018
3.2
Bylaws
S-1
3.2
6/3/2014
4.1
Description of Securities
X
10.1
Acquisition Agreement, dated May 4, 2015, by and among International Western Oil Corporation and Norris Industries, Inc.
8-K
2.1
5/20/2015
10.2
Assignment, Conveyance and Bill of Sale between the Company and Cerberus Production, LLC, dated July 29, 2016 (incorporated by reference to Exhibit 10.1 to the Quarterly Report on Form 10-Q filed by the Company with the SEC on October 18, 2016)
10-Q
10.1
10/18/2016
10.3
Retainer Amendment Agreement with International Western Oil, dated October 1, 2015
10-Q
10.2
1/14/2016
21.1
List of Subsidiaries
X
31.1
Certification of Principal Executive Officer pursuant to 18 U. S. C. Section 1350 as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
31.2
Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
32.1
Certification of Principal Executive Officer and Principal Financial Officer, pursuant to 18 U. S. C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
X
32.2
Certification of Principal Financial Officer pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
X
99.1
Reserve report of Kurt Mire, B.Sc.
X
101.INS
Inline XBRL Instance Document
X
101.SCH
Inline XBRL Taxonomy Extension Schema Document
X
101.CAL
Inline XBRL Taxonomy Extension Calculation Linkbase Document
X
101.DEF
Inline XBRL Taxonomy Extension Definition Linkbase Document
X
101.LAB
Inline XBRL Taxonomy Extension Label Linkbase Document
X
101.PRE
Inline XBRL Taxonomy Extension Presentation Linkbase Document
X
Cover Page Interactive Data File (embedded within the Inline XBRL document)
X