As filed with the Securities and Exchange Commission on July 31,October 25, 2023
Registration No. 333-333-268191
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
AMENDMENT NO. 8
to
FORM S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
PERMEX PETROLEUM CORPORATION
(Exact name of Registrant as specified in its charter)
British Columbia, Canada | 1381 | 98-1384682 | ||
(State or other jurisdiction of
| (Primary Standard Industrial
| (I.R.S. Employer Identification Number) |
2911 Turtle Creek Blvd.Blvd, Suite 925
Dallas, Texas75219
(469)804-1306
(Address, including zip code, and telephone number, including area code, of Registrant’s principal executive offices)
Mehran Ehsan
Permex Petroleum Corporation
2911 Turtle Creek Blvd.,Blvd, Suite 925
Dallas, Texas 75219
(469) 804-1306
(Name, address, including zip code, and telephone number, including area code, of agent for service)
Copies to:
Andrew J. Bond, Esq. | Rob Condon, Esq. | |
Nazia J. Khan, Esq. | Dentons US LLP | |
Sheppard, Mullin, Richter & Hampton LLP | 1221 Avenue of the Americas | |
1901 Avenue of the Stars, Suite 1600 Los Angeles, CA 90067 | New York, New York 10020 Telephone: (212) 768-6700 | |
Telephone: (310) 228-3700 |
Andrew J. Bond, Esq.
Nazia J. Khan, Esq.
Sheppard, Mullin, Richter & Hampton LLP
1901 Avenue of the Stars, Suite 1600
Los Angeles, CA 90067
Telephone: (310) 228-3700
Approximate date of commencement of proposed sale to the public: As soon as practicable after the effective date of this Registration Statement.
If any of the securities being registered on this Form are offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act, check the following box. ☒
If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer ☐ | Accelerated filer ☐ | Non-accelerated filer☒ | Smaller reporting company ☒ | |||
Emerging growth company ☒ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided to Section 7(a)(2)(B) of the Securities Act. ☐
The Registrant hereby amends this Registration Statement on such date or dates as may be necessary to delay its effective date until the Registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until the Registration Statement shall become effective on such date as the Commission, acting pursuant to Section 8(a), may determine.
The information contained in this preliminary prospectus is not complete and may be changed. The selling shareholdersThese securities may not sell these securitiesbe sold until the registration statement filed with the Securities and Exchange Commission is effective. This preliminary prospectus is not an offer to sell these securities and it is not soliciting an offer to buy these securities in any state or jurisdiction where the offer or sale is not permitted.
PRELIMINARY PROSPECTUS | SUBJECT TO COMPLETION | DATED |
302,449Up to 1,900,000 Common Units, Each Consisting of a Common Share and a Warrant to Purchase One Common Share
Up to 1,900,000 Pre-funded Units, Each Consisting of a Pre-funded Warrant to Purchase One Common SharesShare and a Warrant to Purchase One Common Share
Permex Petroleum Corporation
This prospectus relates to the resale by certain selling shareholdersis a firm commitment public offering of securities of Permex Petroleum Corporation, consisting of an aggregate of 1,900,000 common units (each, a corporation organized“Common Unit”). Each Common Unit consists of one Common Share, no par value per share (a “Common Share”), and one warrant (each a “Warrant”) at an assumed public offering price of $6.98 per Common Unit, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split (as defined herein). Each Warrant will entitle the holder to purchase one Common Share at an exercise price of $ , equal to 125% of the public offering price of one Common Unit, and expire five years from date of issuance.
A holder will not have the right to exercise any portion of a Warrant if the holder (together with its affiliates) would beneficially own in excess of 4.99% (or, at the election of the holder prior to issuance, 9.99%) of the number of Common Shares outstanding immediately after giving effect to the exercise, as such percentage ownership is determined in accordance with the terms of the Warrants (the “Warrant Exercise Limitation”). However, any holder may increase or decrease such percentage to any other percentage not in excess of 9.99% upon at least 61 days’ prior notice from the holder to us.
We are also offering to those purchasers, if any, whose purchase of Common Units in this offering would otherwise result in the purchaser, together with its affiliates and certain related parties, beneficially owning more than 4.99% (or, at the election of the purchaser, 9.99%) of our outstanding Common Shares immediately following the consummation of this offering, the opportunity to purchase, if the purchaser so chooses, pre-funded units (each a “Pre-funded Unit”) in lieu of Common Units. We are offering a maximum of 1,900,000 Pre-funded Units. Each Pre-funded Unit will consist of one pre-funded warrant to purchase one Common Share at an exercise price of $0.01 per share (each a “Pre-funded Warrant”) and one Warrant. The purchase price of each Pre-funded Unit is equal to the price per Common Unit being sold to the public in this offering, minus $0.01. The Pre-funded Warrants will be immediately exercisable and may be exercised at any time and are subject to the Warrant Exercise Limitation.
For each Pre-funded Unit we sell, the number of Common Units we are offering will be decreased on a one-for-one basis up to 1,900,000. Common Units and Pre-funded Units will not be certificated. The Common Shares included in the Common Units or Pre-funded Units, as the case may be, and the Warrants included in the Common Units or the Pre-funded Units, can only be purchased together in this offering, but the securities contained in the Common Units and Pre-funded Units are immediately separable and will be issued separately.
The offering also includes the Common Shares issuable from time to time upon exercise of the Pre-funded Warrants and Warrants.
We have applied to have the Common Shares and Warrants listed on The Nasdaq Capital Market upon our satisfaction of The Nasdaq Capital Market’s initial listing criteria under the lawstrading symbols “OILS” and “OILSW,” respectively. No assurance can be given that our application will be approved. If our Common Shares and Warrants are not approved for listing on The Nasdaq Capital Market we will not consummate this offering. On November 2, 2022, we effected a 1-for-60 reverse split of British Columbia, Canada (the “Company”), identifiedour outstanding common shares. In order to obtain approval to list our securities on The Nasdaq Capital Market we effected a 1-for-4 reverse stock split of our Common Shares on October 23, 2023. Except as otherwise indicated, information in this prospectus, other than as set forth in our financial statements and the notes thereto, reflects the 1-for-4 reverse stock split of upour Common Shares, which we refer to 302,449 common shares (the “Resale Shares”)as the “Reverse Stock Split,” which was effective on October 23, 2023. The Reverse Stock Split was subject to approval by the Canadian Securities Exchange, which coincided with the effective date of October 23, 2023.
We do not intend to apply for the listing of the Company, no par value, including 295,282 Resale Shares issuable upon exerciseCommon Units, Pre-funded Units or Pre-funded Warrants on any national securities exchange or other trading market. Without an active trading market, the liquidity of outstanding warrants.
The Resale Shares may be sold by the selling shareholders to or through underwriters or dealers, directly to purchasers or through agents designated from time to time. For additional information regarding the methods of sale you should refer to the section entitled “Plan of Distribution” in this prospectus.
The prices at which the selling shareholders may sell the Resale SharesPre-funded Warrants will be determined by the prevailing market price for the Company’s common shares or in privately negotiated transactions. The Company will not receive any proceeds from the sale of the Resalelimited.
Our Common Shares by the selling shareholders; provided, however, the Company will receive the proceeds from any cash exercise of warrants.
The Company will bear all costs relating to the registration of the Resale Shares, other than any selling shareholder’s legal or accounting costs or commissions.
The Company’s common shares are presently listed on the Canadian Securities Exchange and the Frankfurt Stock Exchange under the symbols “OIL” and “75P”, respectively, and quoted on the OTCQB tier of the OTC Markets Group, Inc. under the symbol “OILCF.“OILCD.” The closing price of the Company’s common sharesour Common Shares on July 28,October 20, 2023, as reported by the OTCQB was $2.11$6.98 per share.Common Share after giving effect to the Reverse Stock Split which was effected on October 23, 2023. We have assumed a public offering price of $6.98 per Common Unit (which is based on the closing price of our Common Shares as reported by the OTCQB on October 20, 2023). The final public offering price will be determined through negotiation between us and the representative of the underwriters in the offering and the assumed offering price used throughout this prospectus may not be indicative of the final offering price. At present, there is a very limited market for our Common Shares and there is no established trading market for the Warrants. The trading price of our Common Shares has been, and may continue to be, subject to wide price fluctuations in response to various factors, many of which are beyond our control, including those described in “Risk Factors.”
Quotes of the trading prices of our Common Shares on the OTCQB may not be indicative of the market price of our Common Shares if listed on The Nasdaq Capital Market.
Investing in the Company’s common sharesour securities involves a high degree of risk. See the section entitled “Risk Factors” beginning on page 1517 of this prospectus and elsewhere in this prospectus for a discussion of information that should be considered in connection with an investment in the Company’s common shares.
The Company may amend or supplement this prospectus from time to time by filing amendments or supplements as required. You should read the entire prospectus and any amendments or supplements carefully before you make your investment decision.
The Company is an “emerging growth company” as defined under the federal securities laws and, as such, may elect to comply with certain reduced public company reporting requirements. See “Prospectus Summary - Implications of Being an Emerging Growth Company and a Smaller Reporting Company.”
securities. Neither the United States Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.
Per Common Unit | Per Pre-Funded Unit | Total | ||||||||||
Initial public offering price | $ | $ | $ | |||||||||
Underwriting discounts and commissions(1) | $ | $ | $ | |||||||||
Proceeds to us, before expenses | $ | $ | $ |
(1) | Does not include a non-accountable expense allowance equal to 1% of the gross proceeds of this offering payable to the underwriters. The underwriters will receive compensation in addition to the discounts and commissions. We refer you to “Underwriting” beginning on page 87 of this prospectus for additional information regarding underwriting compensation. |
Prospectus datedWe have granted a 45-day option to the underwriters to purchase up to 285,000 additional Common Shares, and/or up to 285,000 Pre-funded Warrants and/or up to 285,000 Warrants representing 15% of the Common Shares, Pre-funded Warrants and Warrants sold in the offering, solely to cover over-allotments, if any.
The underwriters expect to deliver our securities to purchasers in the offering on or about , 2023.
ThinkEquity
The date of this prospectus is , 2023
INCORPORATION OF CERTAIN INFORMATION BY REFERENCE
The United States Securities and Exchange Commission (the “SEC”) allows us to “incorporate by reference” information that we file with them. Incorporation by reference allows us to disclose important information to you by referring you to those other documents. The information incorporated by reference is an important part of this prospectus, and information that we file later with the SEC will automatically update and supersede this information. We filed a registration statement on Form S-1, of which this prospectus forms a part, under the Securities Act of 1933, as amended (the “Securities Act”), with the SEC with respect to the securities being offered pursuant to this prospectus. This prospectus omits certain information contained in the registration statement, as permitted by the SEC. You should refer to the registration statement, including the exhibits, for further information about us and the securities being offered pursuant to this prospectus. Statements in this prospectus regarding the provisions of certain documents filed with, or incorporated by reference in, the registration statement are not necessarily complete and each statement is qualified in all respects by that reference. We are incorporating by reference the documents listed below, which we have already filed with the SEC, and all documents subsequently filed by us pursuant to Sections 13(a), 13(c), 14 or 15(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), except as to any portion of any future report or document that is not deemed filed under such provisions:
Any statement contained in this prospectus or in a document incorporated or deemed to be incorporated by reference into this prospectus will be deemed to be modified or superseded to the extent that a statement contained in this prospectus or any subsequently filed document that is deemed to be incorporated by reference into this prospectus modifies or supersedes the statement.
You may request, and we will provide you with, a copy of these filings, at no cost, by calling us at (469) 804-1306 or by writing to us at the following address:
Permex Petroleum Corporation
2911 Turtle Creek Blvd, Suite 925
Dallas, Texas 75219
Attn.: Secretary
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TABLE OF CONTENTS
You should rely only onWe and the underwriters have not authorized anyone to provide any information or to make any representations other than those contained in or incorporated by reference in this prospectus or in any free writing prospectusprospectuses prepared by or on behalf of us or to which we may authorize to be delivered or made available tohave referred you. We have nottake no responsibility for, and can provide no assurance as to the selling shareholders have not authorized anyone to provide you with different information. The selling shareholders are offeringreliability of, any other information that others may give you. This prospectus is an offer to sell only the securities offered hereby, but only under circumstances and seeking offers to buy, our common shares only in jurisdictions where offers and sales are permitted.it is lawful to do so. The information contained in or incorporated by reference in this prospectus is accurate only as of theits date of this prospectus, regardless of the time of delivery of this prospectus or of any sale of our common shares.securities.
For investors outsideTo the United States: extent there is a conflict between the information contained in this prospectus, on the one hand, and the information contained in any document incorporated by reference filed with the U.S. Securities and Exchange Commission (the “SEC”) before the date of this prospectus, on the other hand, you should rely on the information in this prospectus. If any statement in a document incorporated by reference is inconsistent with a statement in another document incorporated by reference having a later date, the statement in the document having the later date modifies or supersedes the earlier statement.
Neither we nor the selling shareholdersunderwriters have done anything that would permit this offering or possession or distribution of this prospectus in any jurisdiction other than the United States, where action for that purpose is required. Persons outsiderequired, other than in the United StatesStates. Persons who come into possession of this prospectus mustand any free writing prospectus in jurisdictions outside the United States are required to inform themselves about and to observe any restrictions relatingas to thethis offering of our common shares and the distribution of this prospectus outside the United States.and any free writing prospectus applicable to that jurisdiction.
This prospectus is a part of a registration statement on Form S-1 that we filed withand the Securities and Exchange Commission. The selling shareholders may from time to time sell the common shares covereddocuments incorporated by reference in this prospectus contain market data and in certain circumstances,industry statistics and forecasts that are based on independent industry publications and other publicly available information. Although we believe that these sources are reliable, we do not guarantee the accuracy or completeness of this information and we have not independently verified this information. Although we are not aware of any misstatements regarding the selling shareholders may provide a supplement tomarket and industry data presented or incorporated by reference in this prospectus, that will contain certain specific information aboutthese estimates involve risks and uncertainties and are subject to change based on various factors, including those discussed under the terms of a particular offering by one or more of the selling shareholders or to add information to, or update or change information contained inheading “Risk Factors” and any related free writing prospectus. Accordingly, investors should not place undue reliance on this prospectus. You should read this prospectus or any supplement to this prospectus before deciding to invest in our common shares. You may obtain this information without charge by following the instructions under “Where You Can Find Additional Information” appearing elsewhere in this prospectus.information.
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Unless otherwise indicated in this prospectus, natural gas volumes are stated at the legal pressure base of the state or geographic area in which the reserves are located at 60 degrees Fahrenheit. Crude oil and natural gas equivalents are determined using the ratio of six Mcf of natural gas to one barrel of crude oil, condensate or natural gas liquids.
The following definitions shall apply to the technical terms used in this prospectus.
Terms used to describe quantities of crude oil and natural gas:
“Bbl.” One stock tank barrel, of 42 U.S. gallons liquid volume, used herein in reference to crude oil, condensate or NGLs.
“Boe.” A barrel of oil equivalent and is a standard convention used to express crude oil, NGL and natural gas volumes on a comparable crude oil equivalent basis. Gas equivalents are determined under the relative energy content method by using the ratio of 6.0 Mcf of natural gas to 1.0 Bbl of crude oil or NGL.
“MBbl.” One thousand barrels of crude oil, condensate or NGLs.
“MBoe” One thousand barrels of oil equivalent.
“Mcf.” One thousand cubic feet of natural gas.
“MMCF.” one million cubic feet.
“NGLs.” Natural gas liquids. Hydrocarbons found in natural gas that may be extracted as liquefied petroleum gas and natural gasoline.
Terms used to describe our interests in wells and acreage:
“Basin.” A large natural depression on the earth’s surface in which sediments generally brought by water accumulate.
“Completion.” The process of treating a drilled well followed by the installation of permanent equipment for the production of crude oil, NGLs, and/or natural gas.
“Developed acreage.” Acreage consisting of leased acres spaced or assignable to productive wells. Acreage included in spacing units of infill wells is classified as developed acreage at the time production commences from the initial well in the spacing unit. As such, the addition of an infill well does not have any impact on a company’s amount of developed acreage.
“Development well.” A well drilled within the proved area of a crude oil, NGL, or natural gas reservoir to the depth of a stratigraphic horizon (rock layer or formation) known to be productive for the purpose of extracting proved crude oil, NGL, or natural gas reserves.
“Differential.” The difference between a benchmark price of crude oil and natural gas, such as the NYMEX crude oil spot price, and the wellhead price received.
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“Dry hole.” A well found to be incapable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of such production exceed production expenses and taxes.
“Field.” An area consisting of a single reservoir or multiple reservoirs all grouped on, or related to, the same individual geological structural feature or stratigraphic condition. The field name refers to the surface area, although it may refer to both the surface and the underground productive formations.
“Formation.” A layer of rock which has distinct characteristics that differs from nearby rock.
“Gross acres or Gross wells.” The total acres or wells, as the case may be, in which a working interest is owned.
“Held by operations.” A provision in an oil and gas lease that extends the stated term of the lease as long as drilling operations are ongoing on the property.
“Held by production” or “HBP” A provision in an oil and gas lease that extends the stated term of the lease as long as the property produces a minimum quantity of crude oil, NGLs, and natural gas.
“Hydraulic fracturing.” The technique of improving a well’s production by pumping a mixture of fluids into the formation and rupturing the rock, creating an artificial channel. As part of this technique, sand or other material may also be injected into the formation to keep the channel open, so that fluids or natural gases may more easily flow through the formation.
“Infill well.” A subsequent well drilled in an established spacing unit of an already established productive well in the spacing unit. Acreage on which infill wells are drilled is considered developed commencing with the initial productive well established in the spacing unit. As such, the addition of an infill well does not have any impact on a company’s amount of developed acreage.
“Net acres.” The percentage ownership of gross acres. Net acres are deemed to exist when the sum of fractional ownership working interests in gross acres equals one (e.g., a 10% working interest in a lease covering 640 gross acres is equivalent to 64 net acres).
“NYMEX.” The New York Mercantile Exchange.
“Productive well.” A well that is found to be capable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of the production exceed production expenses and taxes.
“Recompletion.” The process of treating a drilled well followed by the installation of permanent equipment for the production of crude oil, NGLs or natural gas or, in the case of a dry hole, the reporting of abandonment to the appropriate agency.
“Reservoir.” A porous and permeable underground formation containing a natural accumulation of producible crude oil, NGLs and/or natural gas that is confined by impermeable rock or water barriers and is separate from other reservoirs.
“Spacing.” The distance between wells producing from the same reservoir. Spacing is often expressed in terms of acres, e.g., 40-acre spacing, and is often established by regulatory agencies.
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“Undeveloped acreage.” Leased acreage on which wells have not been drilled or completed to a point that would permit the production of economic quantities of crude oil, NGLs, and natural gas, regardless of whether such acreage contains proved reserves. Undeveloped acreage includes net acres held by operations until a productive well is established in the spacing unit.
“Unit.” The joining of all or substantially all interests in a reservoir or field, rather than a single tract, to provide for development and operation without regard to separate property interests. Also, the area covered by a unitization agreement.
“Wellbore.” The hole drilled by the bit that is equipped for natural gas production on a completed well. Also called well or borehole.
“Working interest.” The right granted to the lessee of a property to explore for and to produce and own crude oil, NGLs, natural gas or other minerals. The working interest owners bear the exploration, development, and operating costs on either a cash, penalty, or carried basis.
“Workover.” Operations on a producing well to restore or increase production.
Terms used to assign a present value to or to classify our reserves:
“Possible reserves.” The additional reserves which analysis of geoscience and engineering data suggest are less likely to be recoverable than probable reserves.
“Pre-tax PV-10% or PV-10.” The estimated future net revenue, discounted at a rate of 10% per annum, before income taxes and with no price or cost escalation or de-escalation in accordance with guidelines promulgated by the SEC.
“Probable reserves.” The additional reserves which analysis of geoscience and engineering data indicate are less likely to be recovered than proved reserves but which together with proved reserves, are as likely as not to be recovered.
“Proved reserves.” The quantities of crude oil, NGLs and natural gas, which, by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be economically producible, from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations, prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.
“Proved undeveloped reserves” or “PUDs.” Proved Reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Reserves on undrilled acreage are limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. Undrilled locations can be classified as having proved undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances justify a longer time. Estimates for proved undeveloped reserves are not attributed to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, or by other evidence using reliable technology establishing reasonable certainty.
“SEC Pricing” means pricing calculated using oil and natural gas price parameters established by current guidelines of the SEC and accounting rules based on the unweighted arithmetic average of oil and natural gas prices as of the first day of each of the 12 months ended on the given date.
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This summary highlights information contained in this prospectus. It does not contain all of the information that you should consider in making your investment decision. Before investing in our common shares,securities, you should read this entire prospectus carefully, including the sections entitled “Risk Factors,” “Business” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and related notes. Except as otherwise required by the context, references to “Permex,” “the Company,” “we,” “us” and “our” are to Permex Petroleum Corporation, a corporation organized under the laws of British Columbia, Canada, individually, or as the context requires, collectively with its subsidiary. Certain operational terms used in this prospectus are defined in the “Glossary of Terms.” All references to “U.S. Dollars,” “USD” or “$” are to the legal currency of the United States, and all references to “CAD$” and “C$” are to the legal currency of Canada. All references to “M$” are in thousands of dollars.
All information presented in this prospectus has been retrospectively restated to give effect to the Reverse Stock Split which was effected on October 23, 2023 assuming no fractional shares will be issued in connection with the Reverse Stock Split and all such fractional interests will be rounded up or down to the nearest whole number of Common Shares, as applicable.
Company Overview
We are an independent energy company engaged in the acquisition, exploration, development and production of oil and natural gas properties on private, state and federal land in the United States, primarily in the Permian Basin region of West Texas and Southeast New Mexico which includes the Midland – Central Basin and Delaware Basin. We focus on acquiring producing assets at a discount to market, increasing production and cash-flow through recompletion and re-entries, secondary recovery and reducing risk by infill drilling and development. Currently, we own and operate various oil and gas properties as well as royalty interests in 73 wells and five permitted wells across 3,800 acres within the Permian Basin. Overall, we own and operate more than 78 oil and gas wells, have more than 11,700 net acres of production oil and gas assets, 62 shut-in opportunities, 17 salt water disposal wells and two water supply wells allowing for waterflood secondary recovery.
As described in more detail below, according to the 2022 Appraisal Report (defined below), the net present value of net future revenues, (net of royalties, operating costs and capital expenditures, including asset retirement obligations) before income tax, discounted at 10% (“NPV 10%” or “PV10”) of our total proved plus probable reserves is estimated at $428 million, or $221.53 per outstanding share (basis). In particular, based on the information in the 2022 Appraisal Report:
● | Our reserves are comprised of 93% light oil and 7% natural gas; | |
● | Our total proved reserves were | |
● | Our total probable reserves were | |
● | Our total proved and probable reserves were |
The following is a summary of our net oil and gas reserves net present value of revenue as of September 30, 2022:
Reserves MBoe | NPV 10% ($ thousand) | NPV per Boe $/Boe | ||||||||||
Proved Developed Producing | 492.5 | 12,057.6 | 24.48 | |||||||||
Total Proved | 6,739.0 | 198,619.1 | 29.47 | |||||||||
Proved Plus Probable | 15,917.5 | 428,186.5 | 26.90 |
1. | Natural Gas: 5.98 Mcf/Boe | |
2. | The 2022 Appraisal Report used SEC Pricing effective September 30, 2022 |
Oil and Gas Properties
We hired MKM Engineering, who prepared for us an Appraisal of Certain Oil and Gas Interests owned by Permex Petroleum Corporation located in New Mexico and Texas as of September 30, 2022 (the “2022 Appraisal Report”) as well as an Appraisal of Certain Oil and Gas Interests owned by Permex Petroleum Corporation located in New Mexico and Texas as of September 30, 2021 (the “2021 Appraisal Report” and together with the 2022 Appraisal Report the “Appraisal Reports”). MKM Engineering is independent with respect to Permex Petroleum Corporation as provided in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. MKM Engineering’s estimates of our proved and probable reserves in each of the Appraisal Reports were prepared according to generally accepted petroleum engineering and evaluation principles, and each of the Appraisal Reports conform to SEC Pricing. The Appraisal Reports are each filed as an exhibit to the registration statement for which this prospectus is a part.
The Appraisal Reports were each specifically prepared by Michele Mudrone, an employee of MKM Engineering, a registered Professional Engineer in the State of Texas, and a member of the Society of Petroleum Engineers. Ms. Mudrone graduated from the Colorado School of Mines with a Bachelor of Science degree in Petroleum Engineering in 1976 and has been employed in the petroleum industry and directly involved in reservoir engineering, petrophysical analysis, reservoir simulation and property evaluation since that time. Ms. Mudrone certified in each Appraisal Report that she did not receive, nor expects to receive, any direct or indirect interest in the holdings discussed in the report or in the securities of the Company. Because of our current size, we do not have any technical person responsible for overseeing the preparation of the reserve estimates presented herein (or have any internal control policies pertaining to estimates of oil and gas reserves), and consequently, we rely exclusively on the Appraisal Reports in the preparation of the reserve estimates present in this prospectus.
Since all of our reserves are from conventional reservoirs, MKM Engineering assumed for the purposes of its appraisal reports that the technology to be used to develop our reserves would include horizontally drilled wells, fracturing, and acidizing.
The following tables show a summary of our reserves as of September 30, 2022 and September 30, 2021 which have been derived from the Appraisal Reports and conform to SEC Pricing.
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Composite Proved Reserve Estimates and Economic Forecasts for the year ended September 30, 2022
Proved | Proved Developed Producing | Proved Non-Producing | Proved Undeveloped | |||||||||||||||
Net Reserves | ||||||||||||||||||
Oil/Condensate | MBbl | 6,237.1 | 444.6 | 709.3 | 5,083.2 | |||||||||||||
Gas | Mcf | 3,001.2 | 286.2 | 578.6 | 2,136.4 | |||||||||||||
Revenue | ||||||||||||||||||
Oil/Condensate | M$ | 572,090.2 | 40,485.1 | 65,032.6 | 466,572.5 | |||||||||||||
Gas | M$ | 17,390.7 | 1,736.5 | 3,287.4 | 12,366.8 | |||||||||||||
Severance and Ad Valorem Taxes | M$ | 43,493.7 | 3,633.2 | 4,955.7 | 34,904.8 | |||||||||||||
Operating Expenses | M$ | 48,136.3 | 11,893.8 | 5,610.1 | 30,632.4 | |||||||||||||
Investments | M$ | 71,700.0 | 806.9 | 2,074.6 | 68,818.5 | |||||||||||||
Operating Income (BFIT) | M$ | 426,150.9 | 25,887.7 | 55,679.6 | 344,583.6 | |||||||||||||
Discounted @ 10% | M$ | 198,619.1 | 12,057.6 | 34,831.6 | 151,729.9 |
Composite Proved Reserve Estimates and Economic Forecasts for the year ended September 30, 2021
Proved | Proved Developed Producing | Proved Non-Producing | Proved Undeveloped | |||||||||||||||
Net Reserves | ||||||||||||||||||
Oil/Condensate | MBbl | 6,199.4 | 399.3 | 188.1 | 5,612.0 | |||||||||||||
Natural Gas | Mcf | 3,018.3 | 314.4 | 97.5 | 2,606.4 | |||||||||||||
Revenue | ||||||||||||||||||
Oil/Condensate | M$ | 347,051.0 | 21,920.1 | 10,468.6 | 314,662.3 | |||||||||||||
Natural Gas | M$ | 8,906.8 | 949.0 | 286.9 | 7,670.9 | |||||||||||||
Severance and Ad Valorem Taxes | M$ | 26,171.1 | 1,927.3 | 774.5 | 23,469.3 | |||||||||||||
Operating Expenses | M$ | 43,511.4 | 8,048.8 | 3,057.0 | 32,405.6 | |||||||||||||
Investments | M$ | 71,700.0 | 791.9 | 689.6 | 70,218.5 | |||||||||||||
Operating Income (BFIT) | M$ | 214,575.4 | 12,101.2 | 6,234.4 | 196,239.8 | |||||||||||||
Discounted @ 10% | M$ | 100,772.6 | 6,356.0 | 3,644.6 | 90,772.0 |
Composite Probable Reserve Estimates and Economic Forecasts for the year ended September 30, 2022
Probable | Probable Developed Producing | Probable Non-Producing | Probable Undeveloped | |||||||||||||||
Net Reserves | ||||||||||||||||||
Oil/Condensate | MBbl | 7,452.1 | 1.9 | 115.9 | 7,334.3 | |||||||||||||
Gas | Mcf | 10,323.8 | 10.5 | 6.2 | 10,307.1 | |||||||||||||
Revenue | ||||||||||||||||||
Oil/Condensate | M$ | 680,179.1 | 164.4 | 10,469.2 | 669,545.5 | |||||||||||||
Gas | M$ | 62,309.3 | 64.5 | 38.3 | 62,206.5 | |||||||||||||
Severance and Ad Valorem Taxes | M$ | 41,500.1 | 28.4 | 750.3 | 40,721.4 | |||||||||||||
Operating Expenses | M$ | 50,223.2 | 73.9 | 1,112.6 | 49,036.7 | |||||||||||||
Investments | M$ | 107,884.9 | — | — | 107,884.9 | |||||||||||||
Operating Income (BFIT) | M$ | 542,880.1 | 126.6 | 8,644.5 | 534,109.0 | |||||||||||||
Discounted @ 10% | M$ | 229,567.4 | 53.4 | 3,247.1 | 226,266.9 |
Composite Probable Reserve Estimates and Economic Forecasts for the year ended September 30, 2021
Probable | Probable Non-Producing | Probable Undeveloped | ||||||||||||
Net Reserves | ||||||||||||||
Oil/Condensate | MBbl | 7,466.5 | 119.8 | 7,346.7 | ||||||||||
Natural Gas | Mcf | 10,252.1 | 6.3 | 10,245.8 | ||||||||||
Revenue | ||||||||||||||
Oil/Condensate | M$ | 411,745.8 | 6,686.4 | 405,059.4 | ||||||||||
Natural Gas | M$ | 30,171.8 | 18.4 | 30,153.4 | ||||||||||
Severance and Ad Valorem Taxes | M$ | 23,511.2 | 478.1 | 23,033.1 | ||||||||||
Operating Expenses | M$ | 50,336.3 | 1,061.2 | 49,275.1 | ||||||||||
Investments | M$ | 102,884.9 | — | 102,884.9 | ||||||||||
Operating Income (BFIT) | M$ | 265,185.3 | 5,165.5 | 260,019.8 | ||||||||||
Discounted @ 10% | M$ | 123,329.8 | 1,957.5 | 121,372.3 |
Probable reserves are unproven reserves that geologic and engineering analyses suggest are more likely than not to be recoverable. They are not comparable to proved reserves and estimates of oil, condensate, and gas reserves and future net revenue should be regarded only as estimates that may change as further production history and additional information become available. Such reserve and revenue estimates are based on the information currently available, the interpretation of which is subject to uncertainties inherent in applying judgmental factors.
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Conversion of Undeveloped Acreage
Our process for converting undeveloped acreage to developed acreage is tied to whether there is any drilling being conducted on the acreage in question. We have started development and conversion of our undeveloped acreage located in Martin County, Texas. The PPC Eoff #3 well, operated by Permex Petroleum, is the first of two permitted wells that has been drilled and is being completed by us on the 7,780 gross acre Breedlove oilfield. Drilling of the first well commenced on September 14, 2022. Management furthermore expects to commence lateral drilling and completion of the well by September 2023.January 2024, subject to receipt of additional funding.
An aggregate of 5,083 MBoe and 2,136 MMCF of our proved undeveloped reserves as of September 30, 2022, are part of a development plan that has been adopted by management that calls for these undeveloped reserves to be drilled within the next five years, thus resulting in the conversion of such proved undeveloped reserves to developed status within five years of initial disclosure at September 30, 2022. Management currently anticipates spending approximately $10 million in capital expenditures towards developing our proved undeveloped reserves during the 2023 fiscal year, subject to us acquiring the necessary financing.
Proved Undeveloped Reserves Additions
From September 30, 2021 to September 30, 2022, we had no proved undeveloped additions. The specific changes to our proved undeveloped reserves from September 30, 2021 to September 30, 2022 were as follows:
Breedlove | Pittcock & Mary Bullard | Henshaw | Royalty Wells | Total | ||||||||||||||||
Beginning balance at September 30, 2021 (MBoe)(1) | 5,584.14 | 336.09 | — | 0.22 | 5,920.45 | |||||||||||||||
Production (MBoe)(1) | — | — | — | — | — | |||||||||||||||
Revisions or reclassifications of previous estimates (MBoe)(1) | (589.17 | ) | — | — | — | (589.17 | ) | |||||||||||||
Improved Recovery (MBoe)(1) | — | — | — | — | — | |||||||||||||||
Extensions and Discoveries (MBoe)(1) | — | — | — | — | — | |||||||||||||||
Acquisitions/Purchases (MBoe)(1) | — | — | — | — | — | |||||||||||||||
Sales (MBoe)(1) | — | — | — | — | — | |||||||||||||||
Price Change (MBoe) | (28.54 | ) | 6.02 | — | — | (22.52 | ) | |||||||||||||
Ending balance as of September 30, 2022 (MBoe)(1) | 4,966.43 | 342.11 | — | 0.22 | 5,308.76 |
Breedlove | Pittcock & Mary Bullard | Henshaw | Royalty Wells | Total | ||||||||||||||||
Beginning balance at September 30, 2021 (Mboe)(1) | 5,584.14 | 336.09 | — | 0.22 | 5,920.45 | |||||||||||||||
Production (Mboe)(1) | — | — | — | — | — | |||||||||||||||
Revisions or reclassifications of previous estimates (Mboe)(1) | (589.17 | ) | — | — | — | (589.17 | ) | |||||||||||||
Improved Recovery (Mboe)(1) | — | — | — | — | — | |||||||||||||||
Extensions and Discoveries (Mboe)(1) | — | — | — | — | — | |||||||||||||||
Acquisitions/Purchases (Mboe)(1) | — | — | — | — | — | |||||||||||||||
Sales (Mboe)(1) | — | — | — | — | — | |||||||||||||||
Price Change (Mboe) | (28.54 | ) | 6.02 | — | — | (22.52 | ) | |||||||||||||
Ending balance as of September 30, 2022 (Mboe)(1) | 4,966.43 | 342.11 | — | 0.22 | 5,308.76 |
(1) | Natural gas volumes have been converted to Boe based on energy content of six Mcf of gas to one Bbl of oil. Barrels of oil equivalence does not necessarily result in price equivalence. The price of natural gas on a barrel of oil equivalent basis is currently substantially lower than the corresponding price for oil and has been similarly lower for a number of years. For example, in the year ended September 30, 2022, the average prices of WTI (Cushing) oil and NYMEX Henry Hub natural gas were $91.71 per Bbl and $6.126 per Mcf, respectively, resulting in an oil-to-gas ratio of just under 14 to 1. |
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Financing of Proved and Probable Undeveloped Reserves
We currently estimate that the total cost to develop our proved undeveloped reserves of 5,083.2 MBbl of oil and 2,136.4 Mcf of natural gas as of September 30, 2022 is $68,818,530. We expect to finance these capital costs through a combination of current cash on hand, debt financing through a line of credit or similar debt instrument, one or more offerings of debt or equity, and from cash generated from estimated revenues from sales of oil and natural gas produced at our wells.
We currently estimate that the total cost to develop our probable undeveloped reserves of 7,334.3 MBbl of oil and 10,307.1 Mcf of natural gas as of September 30, 2022 is $107,884,900. We expect to finance these capital costs through a combination of joint ventures, farm-in agreements, direct participation programs, one or more offerings of equity, a debt offering or entering into a line of credit, and from cash generated from estimated revenues from sales of oil and natural gas produced at our wells.
Drilling Activities
We drilled one well during the last three fiscal years. As at September 30, 2022, we had 78 gross wells and 14 net productive wells. Our gross developed acreage totaled 5,177 and net developed acreage totaled 3,942 with the following property breakdown:
Property | Gross Developed Acreage | Net Developed Acreage | Gross Productive Wells | Net Productive Wells | Gross Developed Acreage | Net Developed Acreage | Gross Productive Wells | Net Productive Wells | ||||||||||||||||||||||||
Pittcock | 818 | 664.63 | 1 | 0.81 | 818 | 664.63 | 1 | 0.81 | ||||||||||||||||||||||||
Henshaw | 1,880 | 1,353.60 | 6 | 4.32 | 1,880 | 1,353.60 | 6 | 4.32 | ||||||||||||||||||||||||
Oxy Yates | 680 | 489.60 | 5 | 3.60 | 680 | 489.60 | 5 | 3.60 | ||||||||||||||||||||||||
Bullard | 241 | 187.98 | 1 | 0.78 | 241 | 187.98 | 1 | 0.78 | ||||||||||||||||||||||||
Breedlove | 1,558 | 1,246.40 | 16 | 12.80 | 1,558 | 1,246.40 | 16 | 12.80 | ||||||||||||||||||||||||
Royalty Interest Properties | — | — | 73 | 0.01 | — | — | 73 | 0.01 |
We have 6,000 gross undeveloped acres and 4,800 net undeveloped acres. All of our undeveloped acreage is on our Breedlove property.
Our leases are held by production in perpetuity. If a field/lease is undeveloped it typically has a 2, 3 or 5 year term of expiry. We have over 340 leases covering undeveloped acreage and less than 5% of these leases have an expiry date that is less than two years from the date hereof.
Sales and Production
The average sales prices of our oil and gas products sold in the fiscal years ended September 30, 2022, 2021, and 2020 was $89.14/Boe, $54.19/Boe, and $38.51/Boe, respectively.
Our net production quantities by final product sold in the fiscal years ended September 30, 2022, 2021, and 2020, was 12,597.45 Boe, 1,182.70 Boe, and 17,772.14 Boe, respectively.
Our average production costs per unit for the fiscal years ended September 30, 2022, 2021, and 2020, was $65.82/Boe, and $40.94/Boe, and $32.59/Boe, respectively.
The breakdown of production and prices between oil/condensate and natural gas was as follows:
Net Production Volumes | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | |||||||||
Oil/Condensate (Bbl) | 10,670 | 948 | 16,240 | |||||||||
Natural Gas (Mcf) | 11,567 | 1,410 | 9,196 |
Average Sales Price | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | |||||||||
Oil/Condensate ($/Bbl) | 96.18 | 62.37 | 41.09 | |||||||||
Natural Gas ($/Mcf) | 8.36 | 3.54 | 1.44 |
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The breakdown of our production quantities by individual product type for each of our fields that contain 15% or more of our total proved reserves expressed on an oil-equivalent-barrels basis was as follows:
Breedlove
Net Production Volumes | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | ||||||||||||||||||
Oil/Condensate (Bbl) | 6,998 | — | — | 6,998 | — | — | ||||||||||||||||||
Natural Gas (Mcf) | 11,567 | 419 | — | 11,567 | 419 | — |
Henshaw
Net Production Volumes | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | |||||||||
Oil/Condensate (Bbl) | 2,189 | — | — | |||||||||
Natural Gas (Mcf) | — | — | — |
Pittcock -– Mary Bullard
Net Production Volumes | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | ||||||||||||||||||
Oil/Condensate (Bbl) | 1,483 | 847 | 291 | 1,483 | 847 | 291 | ||||||||||||||||||
Natural Gas (Mcf) | — | — | — | — | — | — |
ODC San Andres
Net Production Volumes | Fiscal Year Ended September 30, 2022 | Fiscal Year Ended September 30, 2021 | Fiscal Year Ended September 30, 2020 | |||||||||
Oil/Condensate (Bbl) | — | — | 15,948 | |||||||||
Natural Gas (Mcf) | — | — | 2,605 |
Texas Properties
Breedlove “B” Clearfork Leases
In September 2021, we, through our wholly-owned subsidiary, Permex Petroleum US Corporation, acquired a 100% Working Interest and an 81.75% Net Revenue Interest in the Breedlove “B” Clearfork leases located in Martin County, Texas. We issued 416,666 common shares104,164 Common Shares and 208,33352,082 share purchase warrants as consideration for this acquisition. The Breedlove “B” Clearfork properties situated in Martin County, Texas are over 12 contiguous sections for a total of 7,870.23 gross and 7,741.67 net acres, of which 98% is held by production in the core of the Permian Basin. It is bounded on the north by Dawson County, on the east by Howard County, on the south by Glasscock and Midland Counties, and on the west by Andrews County. There is a total of 25 vertical wells of which 12 are producers, 4 are saltwater disposal wells and 9 that are shut-in opportunities. In January 2022, we began the pilot re-entry on the Carter Clearfork well #5, which is one of 67 shut-in wells that we currently own. The re-entry involved targeting the Clearfork formation at a depth of 7,200 feet. Due to the high water concentrating in the fluid entry, management plans to install appropriate flow-lines from this well to the injections wells on the property prior to putting the well back on pump. By doing so management plans to reduce unnecessary operating expenses from water disposal in third party disposal facilities.
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Pittcock Leases
The Pittcock Leases are situated in Stonewall County which is in Northwest Texas, in the central part of the North Central Plains and consists of the Pittcock North property, the Pittcock South property and the Windy Jones Property. It is bounded on the north by King County, on the east by Haskell County, on the south by Fisher and Jones Counties, and on the west by Kent County. The Pittcock North property covers 320 acres held by production. There is currently one producing well, ten shut-in wells, two saltwater disposal wells, and a water supply well. We hold a 100% working interest in the Pittcock North Property and an 81.25% net revenue interest. The Pittcock South property covers 498 acres in four tracts. There are currently 19 shut-in wells and two saltwater disposal wells. We hold a 100% working interest in the lease and a 71.90% net revenue interest. The Windy Jones Property consists of 40 acres and includes two injection wells and two suspended oil wells. The sole purpose of the Windy Jones property is to provide waterflood to the offset wells being the Pittcock wells located east boundary of the Windy Jones Property. We hold a 100% working interest in the Windy Jones Property and a 78.9% net revenue interest.
Mary Bullard Property
We acquired the Mary Bullard Property in August 2017 for cash consideration of approximately $50,000. The Mary Bullard Property is located in Stonewall County, about 5 ½ miles south west of Aspermont, Texas. It is bounded on the north by King County, on the east by Haskell County, on the south by Fisher and Jones Counties, and on the west by Kent County. The asset is situated on the Eastern Shelf of the Midland Basin in the central part of the North Central Plains. The Mary Bullard Property covers 241 acres held by production and is productive in the Clearfork formation at a depth of approximately 3,200 feet. There is currently one producing well, four shut-in wells, and two water injection wells. We hold a 100% working interest in the Mary Bullard Property and a 78.625% net revenue interest.
New Mexico Properties
In December 2017, Permex Petroleum US Corporation, our wholly-owned subsidiary, acquired the West Henshaw Property and the Oxy Yates Property for $170,000 from Permex Petroleum Company LLC (“PPC”). An additional $95,000 was transferred by us to PPC to purchase reclamation bonds in connection with the future operation of the properties.
West Henshaw Property
The West Henshaw Property is located in Eddy County, New Mexico, 12 miles northeast of Loco Hills in the Delaware Basin. Eddy County is in Southeast New Mexico. It is bounded by Chaves County to the north, Otero County to the east, Loving County, Texas to the south, and Lea County to the west. The West Henshaw Property covers 1,880 acres held by production. There are two producing wells, seven shut-in wells and four saltwater disposal wells. We hold a 100% working interest in the West Henshaw Property and a 72% net revenue interest.
In January 2022, we began the pilot re-entry on the West Henshaw well #15-3, one out of the 67 shut-in wells we currently owns. The re-entry and re-stimulation involved the West Henshaw property targeting the Grayburg formation at a depth of 2,850 feet. The recompletion was successful and came online at an initial rate of 30 bopd and has stabilized at 15 bopd.
In April 2022, we began the re-entry on the West Henshaw well #6-10. The re-entry and re-stimulation involved the West Henshaw property targeting the Grayburg formation at a depth of 2,850 feet. The recompletion was successful and came online at an initial rate of 15 bopd and has stabilized at 10 bopd.
The remaining 67 shut-in wells that we plan to re-enter have potential to yield similar results increasing our total daily production solely by re-entering shut-in wells.
Oxy Yates Property
The Oxy Yates Property is located in Eddy County, approximately eight miles north of Carlsbad, New Mexico in the Delaware Basin. It is bounded by Chaves County to the north, Otero County to the east, Loving County, Texas to the south, and Lea County to the west. The Oxy Yates Property covers 680 acres held by production. There is one producing well and nine shut-in wells. The Yates formation is located at an average depth of 1,200 feet and overlies the Seven River formation and underlies the Tansill formation. We hold a 100% working interest in the Oxy Yates Property and a 77% net revenue interest.
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Royalty Interest Properties
During the year ended September 30, 2021, we acquired royalty interests in 73 producing oil and gas wells located in Texas and New Mexico for $179,095. There are no changes to the royalty interests held by the Company in fiscal 2022.
Business Strategy
The principal elements of our business strategy include the following:
● | Grow production and reserves in a capital efficient manner using internally generated levered free cash flow. We intend to allocate capital in a disciplined manner to projects that we anticipate will produce predictable and attractive rates of return. We plan to direct capital to our oil-oriented and reduced-risk development opportunities while focusing on driving cost efficiencies across our asset base with the primary objective of internally funding our capital budget and growth plan. We may also use our capital flexibility to pursue value-enhancing, bolt-on acquisitions to opportunistically improve our positions in existing basins. | |
● | Maximize ultimate hydrocarbon recovery from our assets by optimizing drilling, completion and production techniques and investigating deeper reservoirs and areas beyond our known productive areas. While we intend to utilize proven techniques and technologies, we will also continuously seek efficiencies in our drilling, completion and production techniques in order to optimize ultimate resource recoveries, rates of return and cash flows. We will explore innovative enhanced oil recovery (“EOR”) techniques to unlock additional value and have allocated capital towards next generation technologies. For example, we have already completed extensive waterflood EOR studies in Pittcock North and Pittcock South. Through these studies, we will seek to expand our development beyond our known productive areas in order to add probable and possible reserves to our inventory at attractive all-in costs as of the time of our studies. | |
● | Pursue operational excellence with a sense of urgency. We plan to deliver low cost, consistent, timely and efficient execution of our drilling campaigns, work programs and operations. We intend to execute our operations in a safe and environmentally responsible manner, focus on reducing our emissions, apply advanced technologies, and continuously seek ways to reduce our operating cash costs on a per barrel basis. | |
● | Pursue strategic acquisitions that maintain or reduce our break-even costs. We intend to actively pursue accretive acquisitions, mergers and dispositions that are intended to improve our margins, returns, and break-even costs of our investment portfolio. Financial strategies associated with these efforts will focus on delivering competitive adjusted per share returns. |
Development
We believe that there is significant value to be created by drilling the identified undeveloped opportunities on our properties in conjunction with the stimulation and rework of our shut-in wells. While our near-term plans are focused towards drilling wells on our existing acreage to develop the potential contained therein, our long-term plans also include continuing to evaluate acquisition and leasing opportunities that can earn attractive rates of return on capital employed.
Risk Factor Summary
Our business is subject to a number of risks of which you should be aware before making an investment decision. You should carefully consider all of the information set forth in this prospectus and, in particular, should evaluate the specific factors set forth under “Risk Factors” in deciding whether to invest in our common shares.securities. Among these important risks are the following:
● | If we fail to obtain the capital necessary to fund our operations, we will be unable to continue our operations and you will likely lose your entire investment. Even if we can raise additional funding, we may be required to do so on terms that are dilutive to you. | |
● | Our independent registered public accounting firm has expressed substantial doubt about our ability to continue as a going concern, which may hinder our ability to obtain future financing. |
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● | Oil and gas prices are volatile, and declines in prices may adversely affect our financial position, financial results, cash flows, access to capital and ability to grow. |
● | The actual quantities and present value of our proved oil, gas, and NGL reserves may be less than we have estimated. | |
● | Our acquisition strategy may subject us to certain risks associated with the inherent uncertainty in evaluating properties. | |
● | We may be unable to successfully integrate recently acquired assets or any assets we may acquire in the future into our business or achieve the anticipated benefits of such acquisitions. | |
● | Drilling for and producing oil, natural gas and NGLs are high risk activities with many uncertainties that could adversely affect our financial condition or results of operations. | |
● | Our future success depends on our ability to replace reserves. | |
● | Our business depends on third-party transportation and processing facilities and other assets that are owned by third parties. | |
● | The development of our proved undeveloped reserves may take longer and may require higher levels of capital expenditures than we currently anticipate. Therefore, our undeveloped reserves may not be ultimately developed or produced. | |
● | Weather conditions, which could become more frequent or severe due to climate change, could adversely affect our ability to conduct drilling, completion and production activities in the areas where we operate. | |
● | We may incur losses as a result of title defects in the properties in which we invest. | |
● | Fuel conservation measures, technological advances and negative shift in market perception towards the oil and natural gas industry could reduce demand for oil and natural gas. | |
● | Our operations are concentrated in the Permian and Delaware Basins, making us vulnerable to risks associated with operating in a limited geographic area. | |
● | Increased attention to environmental, social and governance matters may impact our business. |
● | ||
We are substantially dependent on a limited number of customers. | ||
● | The unavailability, high cost or shortages of rigs, equipment, raw materials, supplies or personnel may restrict or result in increased costs for operators related to developing and operating our properties. | |
● | Our business is highly regulated and governmental authorities can delay or deny permits and approvals or change legal requirements governing our operations, including well stimulation, enhanced production techniques and fluid injection or disposal, that could increase costs, restrict operations and delay our implementation of, or cause us to change, our business strategy. | |
● | Failure to comply with environmental laws and regulations could result in substantial penalties and adversely affect our business. | |
● | The market price of our | |
● | Even if we meet the initial listing requirements of The Nasdaq Capital Market, there can be no assurance that we will be able to comply with The Nasdaq Capital Market’s continued listing standards, a failure of which could result in a de-listing of our Common Shares and Warrants. | |
● | Our principal shareholders and management own a significant percentage of our shares and may be able to exert significant control over matters subject to shareholder approval. | |
● | We are a British Columbia company and it may be difficult for you to enforce judgments against us or certain of our directors or officers. | |
● | An investment in our securities, and certain subsequent transactions with respect to our securities, may result in uncertain or adverse U.S. federal income tax consequences for an investor. |
Corporate History
We were incorporated on April 24, 2017 under the laws of British Columbia, Canada. At June 30, 2023, we have one wholly-owned subsidiary, Permex Petroleum US Corporation, a corporation incorporated under the laws of New Mexico (Permex U.S.).Mexico. We own and operate oil and gas properties in Texas (Breedlove “B” Property, Pittcock North Property, Pittcock South Property, and Mary Bullard Property), and Permex U.S.Petroleum US Corporation owns and operates oil and gas properties in New Mexico (Henshaw Property and the Oxy Yates Property).
Implications of Being an Emerging Growth Company and a Smaller Reporting Company
We are an “emerging growth company,” as defined in Section 2(a) of the Securities Act of 1933, as amended (the “Securities Act”), as modified by the Jumpstart Our Business Startups Act of 2012 (“JOBS Act”). As such, we are eligible to take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not “emerging growth companies” including, but not limited to, not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act of 2002, as amended (“Sarbanes-Oxley Act”), and the requirement to present only two years of audited financial statements and only two years of related Management’s Discussion and Analysis of Financial Condition and Results of Operations in the registration statement of which this prospectus forms a part. We are currently utilizing or intend to utilize both of these exemptions. We have not made a decision whether to take advantage of any other exemptions available to emerging growth companies. We do not know if some investors will find our securities less attractive as a result of our utilization of these or other exemptions. The result may be a less active trading market for our securities and our share price may be more volatile.
In addition, Section 107 of the JOBS Act also provides that an “emerging growth company” can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, such an “emerging growth company” can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We have chosen to take advantage of the extended transition periods available to emerging growth companies under the JOBS Act for complying with new or revised accounting standards until those standards would otherwise apply to private companies provided under the JOBS Act. As a result, our consolidated financial statements may not be comparable to those of companies that comply with public company effective dates for complying with new or revised accounting standards.
We will remain an “emerging growth company” until the earliest of (a) the last day of the first fiscal year in which our annual gross revenues exceed $1.235 billion, (b) the date that we become a “large accelerated filer” as defined in Rule 12b-2 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), (c) the date on which we have issued more than $1.0 billion in nonconvertible debt during the preceding three-year period or (d) the last day of our fiscal year containing the fifth anniversary of the date on which we completed our initial public offering of securities.
We have elected to take advantage of certain of the reduced disclosure obligations in this prospectus and in our filings with the SEC. As a result, the information that we provide to our shareholders may be different than you might receive from other public reporting companies in which you hold equity interests.
We are also a “smaller reporting company” as defined under the Securities Act and Exchange Act. We may continue to be a smaller reporting company so long as either (i) the market value of our common sharesCommon Shares held by non-affiliates is less than $250 million or (ii) our annual revenue was less than $100 million during the most recently completed fiscal year and the market value of our common sharesCommon Shares held by non-affiliates is less than $700 million. If we are a smaller reporting company at the time we cease to be an emerging growth company, we may continue to rely on exemptions from certain disclosure requirements that are available to smaller reporting companies. Specifically, as a smaller reporting company, we may choose to present only the two most recent fiscal years of audited financial statements in our Annual Report on Form 10-K and have reduced disclosure obligations regarding executive compensation, and, similar to emerging growth companies, if we are a smaller reporting company under the requirements of (ii) above, we would not be required to obtain an attestation report on internal control over financial reporting issued by our independent registered public accounting firm.
THE OFFERING
The following summary is provided solely for convenience and is not intended to be complete. You should read the full text and more specific details contained elsewhere in this prospectus.
Common Units offered by us | Up to 1,900,000 Common Units, each Common Unit consisting of one Common Share and one Warrant, with each Warrant exercisable for one Common Share at an assumed public offering price of $6.98 per Common Unit, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split. The Warrants offered as part of the Common Units are exercisable immediately, at an exercise price of $ , equal to 125% of the public offering price of one Common Unit, and expire five years from the date of issuance. The securities contained in the Common Units are immediately separable and will be issued separately in this offering.
The number of
Except as otherwise indicated herein, all information in this prospectus reflects or assumes:
On November 2, 2022, we effected a 1-for-60 reverse split of our outstanding common shares. In order to obtain approval to list our securities on The Nasdaq Capital Market we effected the Reverse Stock Split on October 23, 2023. Except as otherwise indicated, information in this prospectus, other than as set forth in our financial statements and the notes thereto, reflects the 1-for-4 reverse stock split of our Common Shares which was effected on October 23, 2023. The Reverse Stock Split was subject to approval by the Canadian Securities Exchange, which coincided with the effective date of October 23, 2023. SUMMARY FINANCIAL DATA The following tables set forth our consolidated financial data as of the dates and for the periods indicated. We have derived the summary consolidated statements of operations data for the years ended September 30, 2022 and 2021 from our audited consolidated financial statements included elsewhere in this prospectus. We have derived the summary consolidated statements of operations data for the nine months ended June 30, 2023 and 2022 and our balance sheet data as of June 30, 2023 from our unaudited interim consolidated financial statements included elsewhere in this prospectus. The unaudited interim consolidated financial statements have been prepared on the same basis as the audited consolidated financial statements and reflect, in the opinion of management, all adjustments of a normal, recurring nature that are necessary for a fair presentation of the unaudited interim consolidated financial statements. Our historical results are not necessarily indicative of the results that may be expected in the future, and the results in the nine months ended June 30, 2023 are not necessarily indicative of results to be expected for the full year or any other period. The following summary financial data should be read with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and related notes and other information included elsewhere in this prospectus. Consolidated Statements of Operations Data:
Balance Sheet Data:
RISK FACTORS Investing in our Risks Related to Our Financial Position and Need for Capital If we fail to obtain the capital necessary to fund our operations, we will be unable to continue our operations and you will likely lose your entire investment. We are in the early stages of our operations and have not generated revenue in excess of our expenses. We will likely operate at a loss until our business becomes established, and we Even if we can raise additional funding, we may be required to do so on terms that are dilutive to you. The capital markets have been unpredictable in the recent past. In addition, it is generally difficult for early stage companies to raise capital under current market conditions. The amount of capital that a company such as ours is able to raise often depends on variables that are beyond our control. As a result, we may not be able to secure financing on terms attractive to us, or at all. If we are able to consummate a financing arrangement, the amount raised may not be sufficient to meet our future needs and may be dilutive to our current shareholders. If adequate funds are not available on acceptable terms, or at all, our business, including our results of operations, financial condition and our continued viability will be materially adversely affected. We have a limited operating history. We have a limited operating history and our business is subject to all of the risks inherent in the establishment of a new business enterprise. Our likelihood of success must be considered in light of the problems, expenses, difficulties, complications and delays frequently encountered in connection with development and expansion of a new business enterprise. If we are unable to achieve profitability, we may be unable to continue our operations. Our independent registered public accounting firm has expressed substantial doubt about our ability to continue as a going concern, which may hinder our ability to obtain future financing. Our financial statements as of September 30, 2022 have been prepared under the assumption that we will continue as a going concern for the next twelve months. Our independent registered public accounting firm included in its opinion for the year ended September 30, 2022 an explanatory paragraph referring to our significant losses from operations and expressing substantial doubt in our ability to continue as a going concern without additional capital becoming available. Our ability to continue as a going concern is dependent upon our ability to obtain additional equity or debt financing, reduce expenditures and to generate significant revenue. Our financial statements as of September 30, 2022 did not include any adjustments that might result from the outcome of this uncertainty. The reaction of investors to the inclusion of a going concern statement by our auditors, and our potential inability to continue as a going concern, in future years could materially adversely affect the price of our securities and our ability to raise new capital. Risks Related to Our Business Oil and gas prices are volatile, and declines in prices may adversely affect our financial position, financial results, cash flows, access to capital and ability to grow. The prices we receive for our oil and natural gas production heavily influence our revenue, operating results, profitability, access to capital, future rate of growth and carrying value of our properties. Oil and natural gas are commodities, and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand, as well as costs and terms of transport to downstream markets. Historically, the commodities markets had volatile prices, and these markets will likely continue to be volatile in the future. If the prices of oil and natural gas experience a substantial decline, our operations, financial condition and level of expenditures for the development of our oil and natural gas reserves may be materially and adversely affected. The prices we receive for our production, and the levels of our production, depend on numerous factors beyond our control and include the following:
Volatile oil and natural gas prices make it difficult to estimate the value of producing properties for acquisition and often cause disruption in the market for oil and natural gas producing properties, as buyers and sellers have difficulty agreeing on such value. Price volatility also makes it difficult to budget for and project the return on acquisitions and development and exploitation projects. Our revenues, operating results, profitability and future rate of growth depend primarily upon the prices we receive for oil and, to a lesser extent, natural gas that we sell. Prices also affect the amount of cash flow available for capital expenditures and our ability to borrow money or raise additional capital. In addition, we may need to record asset carrying value write-downs if prices fall. A significant decline in the prices of natural gas or oil could adversely affect our financial position, financial results, cash flows, access to capital and ability to grow. The actual quantities and present value of our proved oil, gas, and NGL reserves may be less than we have estimated. There are numerous uncertainties inherent in estimating crude oil and natural gas reserves and their value. Reservoir engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner. Because of the high degree of judgment involved, the accuracy of any reserve estimate is inherently imprecise, and a function of the quality of available data and the engineering and geological interpretation. Our reserves estimates are based on 12-month average prices, except where contractual arrangements exist; therefore, reserves quantities will change when actual prices increase or decrease. In addition, results of drilling, testing, and production may substantially change the reserve estimates for a given reservoir over time. The estimates of our proved reserves and estimated future net revenues also depend on a number of factors and assumptions that may vary considerably from actual results, including:
For these reasons, estimates of the economically recoverable quantities of crude oil and natural gas attributable to any particular group of properties, classifications of those reserves and estimates of the future net cash flows expected from them prepared by different engineers or by the same engineers but at different times may vary substantially. Accordingly, reserves estimates may be subject to upward or downward adjustment, and actual production, revenue and expenditures with respect to our reserves likely will vary, possibly materially, from estimates. Additionally, because some of our reserves estimates are calculated using volumetric analysis, those estimates are less reliable than the estimates based on a lengthy production history. Volumetric analysis involves estimating the volume of a reservoir based on the net feet of pay of the structure and an estimation of the area covered by the structure. In addition, realization or recognition of proved undeveloped reserves will depend on our development schedule and plans. A change in future development plans for proved undeveloped reserves could cause the discontinuation of the classification of these reserves as proved. Our acquisition strategy may subject us to certain risks associated with the inherent uncertainty in evaluating properties. Although we perform a review of properties that we acquire that we believe is consistent with industry practices, such reviews are inherently incomplete. It generally is not feasible to review in-depth every individual property involved in each acquisition. Ordinarily, we will focus our review efforts on the higher-value properties and will sample the remainder. However, even a detailed review of records and properties may not necessarily reveal existing or potential problems, nor will it permit us as a buyer to become sufficiently familiar with the properties to assess fully and accurately their deficiencies and potential. Inspections may not always be performed on every well, and environmental problems, such as groundwater contamination, are not necessarily observable even when an inspection is undertaken. Even when problems are identified, we often assume certain environmental and other risks and liabilities in connection with acquired properties. There are numerous uncertainties inherent in estimating quantities of proved oil and gas reserves and future production rates and costs with respect to acquired properties, and actual results may vary substantially from those assumed in the estimates. In addition, there can be no assurance that acquisitions will not have an adverse effect upon our operating results, particularly during the periods in which the operations of acquired businesses are being integrated into our ongoing operations.
We may be unable to successfully integrate recently acquired assets or any assets we may acquire in the future into our business or achieve the anticipated benefits of such acquisitions. Our ability to achieve the anticipated benefits of our acquisitions will depend in part upon whether we can integrate the acquired assets into our existing business in an efficient and effective manner. We may not be able to accomplish this integration process successfully. The successful acquisition of producing properties requires an assessment of several factors, including:
The accuracy of these assessments is inherently uncertain. In connection with these assessments, we have performed reviews of the subject properties that we believe to be generally consistent with industry practices. The reviews are based on our analysis of historical production data, assumptions regarding capital expenditures and anticipated production declines without review by an independent petroleum engineering firm. Data used in such reviews are typically furnished by the seller or obtained from publicly available sources. Our review may not reveal all existing or potential problems or permit us to fully assess the deficiencies and potential recoverable reserves for all of the acquired properties, and the reserves and production related to the acquired properties may differ materially after such data is reviewed by an independent petroleum engineering firm or further by us. Inspections will not always be performed on every well, and environmental problems are not necessarily observable even when an inspection is undertaken. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or a portion of the underlying deficiencies. The integration process may be subject to delays or changed circumstances, and we can give no assurance that our acquired assets will perform in accordance with our expectations or that our expectations with respect to integration or cost savings as a result of such acquisitions will materialize. Drilling for and producing oil, natural gas and NGLs are high risk activities with many uncertainties that could adversely affect our financial condition or results of operations. Our drilling activities are subject to many risks, including the risk that they will not discover commercially productive reservoirs. Drilling for oil or natural gas can be uneconomical, not only from dry holes, but also from productive wells that do not produce sufficient revenues to be commercially viable. In addition, drilling and producing operations on our acreage may be curtailed, delayed or canceled as a result of other factors, including:
In addition to causing curtailments, delays and cancellations of drilling and producing operations, many of these events can cause substantial losses, including personal injury or loss of life, damage to or destruction of property, natural resources and equipment, pollution, environmental contamination, loss of wells and regulatory penalties. The occurrence of an event that is not fully covered by insurance could have a material adverse impact on our business activities, financial condition and results of operations.
Our future success depends on our ability to replace reserves. Because the rate of production from oil and natural gas properties generally declines as reserves are depleted, our future success depends upon our ability to economically find or acquire and produce additional oil and natural gas reserves. Except to the extent that we acquire additional properties containing proved reserves, conduct successful exploration and development activities or, through engineering studies, identify additional behind-pipe zones or secondary recovery reserves, our proved reserves will decline as our reserves are produced. Future oil and natural gas production, therefore, is highly dependent upon our level of success in acquiring or finding additional reserves that are economically recoverable. We cannot assure you that we will be able to find or acquire and develop additional reserves at an acceptable cost. We may acquire significant amounts of unproved property to further our development efforts. Development and exploratory drilling and production activities are subject to many risks, including the risk that no commercially productive reservoirs will be discovered. We seek to acquire both proved and producing properties as well as undeveloped acreage that we believe will enhance growth potential and increase our earnings over time. However, we cannot assure you that all of these properties will contain economically viable reserves or that we will not abandon our initial investments. Additionally, we cannot assure you that unproved reserves or undeveloped acreage that we acquire will be profitably developed, that new wells drilled on our properties will be productive or that we will recover all or any portion of our investments in our properties and reserves. Our business depends on third-party transportation and processing facilities and other assets that are owned by third parties. The marketability of our oil and natural gas depends in part on the availability, proximity, capacity and cost of pipeline and gathering systems, processing facilities, oil trucking and barging fleets and rail transportation assets as well as storage facilities owned by third parties. The lack of available capacity on these systems and facilities, whether as a result of proration, growth in demand outpacing growth in capacity, physical damage, scheduled maintenance or other reasons could result in a substantial increase in costs, declines in realized commodity prices, the shut-in of producing wells or the delay or discontinuance of development plans for our properties. In addition, our wells may be drilled in locations that are serviced to a limited extent, if at all, by gathering and transportation pipelines, which may or may not have sufficient capacity to transport production from all of the wells in the area. As a result, we rely on third-party oil trucking to transport a significant portion of our production to third-party transportation pipelines, rail loading facilities and other market access points. In addition, concerns about the safety and security of oil and gas transportation by pipeline may result in public opposition to pipeline development or continued operation and increased regulation of pipelines by the Pipeline and Hazardous Materials Safety Administration, The development of our proved undeveloped reserves may take longer and may require higher levels of capital expenditures than we currently anticipate. Therefore, our undeveloped reserves may not be ultimately developed or produced. Approximately 80.7% of our estimated net proved reserves volumes were classified as proved undeveloped as of September 30, 2022. Development of these reserves may take longer and require higher levels of capital expenditures than we currently anticipate. Delays in the development of our reserves or increases in costs to drill and develop such reserves will reduce the PV-10 value of our estimated proved undeveloped reserves and future net revenues estimated for such reserves and may result in some projects becoming uneconomic. In addition, delays in the development of reserves could cause us to have to reclassify our proved reserves as unproved reserves.
Weather conditions, which could become more frequent or severe due to climate change, could adversely affect our ability to conduct drilling, completion and production activities in the areas where we operate. Our exploration and development activities and equipment can be adversely affected by severe weather such as well freeze-offs, which may cause a loss of production from temporary cessation of activity or lost or damaged equipment. Our planning for normal climatic variation, insurance programs, and emergency recovery plans may inadequately mitigate the effects of such weather conditions, and not all such effects can be predicted, eliminated, or insured against. In addition, demand for oil and gas are, to a degree, dependent on weather and climate, which impact the price we receive for the commodities we produce. These constraints could delay or temporarily halt our operations and materially increase our operation and capital costs, which could have a material adverse effect on our business, financial condition and results of operations. We may incur losses as a result of title defects in the properties in which we invest. The existence of a material title deficiency can render a lease worthless. In the course of acquiring the rights to develop natural gas, we typically execute a lease agreement with payment to the lessor subject to title verification. In many cases, we incur the expense of retaining lawyers to verify the rightful owners of the gas interests prior to payment of such lease bonus to the lessor. There is no certainty, however, that a lessor has valid title to their lease’s gas interests. In those cases, such leases are generally voided and payment is not remitted to the lessor. As such, title failures may result in fewer net acres to us. Prior to the drilling of a natural gas well, however, it is the normal practice in our industry for the person or company acting as the operator of the well to obtain a preliminary title review to ensure there are no obvious defects in title to the well. Frequently, as a result of such examinations, certain curative work must be done to correct defects in the marketability of the title, and such curative work entails expense. Our failure to cure any title defects may delay or prevent us from utilizing the associated mineral interest, which may adversely impact our ability in the future to increase production and reserves. Accordingly, undeveloped acreage has greater risk of title defects than developed acreage. If there are any title defects or defects in assignment of leasehold rights in properties in which we hold an interest, we will suffer a financial loss. Additionally, hydrocarbons or other fluids in one reservoir may migrate to another stratum or reservoir, resulting in disputes regarding ownership, the entitlement to produce, and responsibility for consequences of such migration of the fluids. We conduct business in a highly competitive industry. The oil and natural gas industry is highly competitive. The key areas in respect of which we face competition include: acquisition of assets offered for sale by other companies; access to capital (debt and equity) for financing and operational purposes; purchasing, leasing, hiring, chartering or other procuring of equipment and contractors that may be scarce; and employment of qualified and experienced skilled management and oil and natural gas professionals. Competition in our markets is intense and depends, among other things, on the number of competitors in the market, their financial resources, their degree of geological, geophysical, engineering and management expertise and capabilities, their pricing policies, their ability to develop properties on time and on budget, their ability to select, acquire and develop reserves and their ability to foster and maintain relationships with the relevant authorities. Our competitors also include those entities with greater technical, physical and financial resources. In some markets, our products compete with other sources of energy, or other fuels (e.g., hydroelectricity) that may from time to time become more abundant or experience decreased prices. Finally, companies and certain private equity firms not previously investing in oil and natural gas may choose to acquire reserves to establish a firm supply or simply as an investment. Any such companies will also increase market competition which may directly affect us. If we are unsuccessful in competing against other companies, our business, results of operations, financial condition or prospects could be materially adversely affected. Decommissioning costs are unknown and may be substantial. Unplanned costs could divert resources from other projects. We may become responsible for costs associated with plugging, repairing, abandoning and reclaiming wells, pipelines and other facilities that we use for production of oil and natural gas reserves. Abandonment and reclamation of these facilities and the costs associated therewith is often referred to as “decommissioning.” We accrue a liability for decommissioning costs associated with our wells, but have not established any cash reserve account for these potential costs in respect of any of our properties. If decommissioning is required before economic depletion of our properties or if our estimates of the costs of decommissioning exceed the value of the reserves remaining at any particular time to cover such decommissioning costs, we may have to draw on funds from other sources to satisfy such costs. The use of other funds to satisfy such decommissioning costs could impair our ability to focus capital investment in other areas of our business. Decommissioning costs’ predictability is challenging as more focus and demand is placed on decommissioning activities in the future than was previously the case, and because we do not have lengthy operating experience with our wells.
Fuel conservation measures, technological advances and negative shift in market perception towards the oil and natural gas industry could reduce demand for oil and natural gas. Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to oil and natural gas, technological advances in fuel economy and energy generation devices, and the increased competitiveness of alternative energy sources could reduce demand for oil and natural gas. Additionally, the increased competitiveness of alternative energy sources (such as electric vehicles, wind, solar, geothermal, tidal, fuel cells and biofuels) could reduce demand for oil and natural gas and, therefore, our revenues. Additionally, certain segments of the investor community have recently expressed negative sentiment towards investing in the oil and natural gas industry. Recent equity returns in the sector versus other industry sectors have led to lower oil and natural gas representation in certain key equity market indices. Some investors, including certain pension funds, university endowments and family foundations, have stated policies to reduce or eliminate their investments in the oil and natural gas sector based on social and environmental considerations. Furthermore, certain other stakeholders have pressured commercial and investment banks to stop funding oil and gas projects. With the continued volatility in oil and natural gas prices, and the possibility that interest rates will rise in the near term, increasing the cost of borrowing, certain investors have emphasized capital efficiency and free cash flow from earnings as key drivers for energy companies, especially shale producers. This may also result in a reduction of available capital funding for potential development projects, further impacting our future financial results. Some states attorneys general have accused large legacy E&P companies of purposefully obscuring consequences of combusting hydrocarbons. The impact of the changing demand for oil and natural gas services and products, together with a change in investor sentiment, may have a material adverse effect on our business, financial condition, results of operations and cash flows. Furthermore, if we are unable to achieve the desired level of capital efficiency or free cash flow within the timeframe expected by the market, our share price may be adversely affected. Major utilities, sometimes at the instigation of states or investors, have announced plans to radically reduce emissions, or goals to achieve “net-zero” carbon emissions by deadlines as early as 2035. Diminution of available markets (for instance by bans on the consumption of natural gas as a fuel for power plants) or prohibitions on use of natural gas in new construction as early as 2027 also may affect our markets, profitability and cash flow. Our operations are concentrated in the Permian and Delaware Basins, making us vulnerable to risks associated with operating in a limited geographic area. All of our producing properties are geographically concentrated in the Permian and Delaware Basins. As a result, we may be disproportionately exposed to various factors, including, among others: (i) the impact of regional supply and demand factors, (ii) delays or interruptions of production from wells in such areas caused by governmental regulation, (iii) processing, gathering or transportation capacity constraints, (iv) market limitations, (v) availability of equipment and personnel, (vi) fluid shortages or other drought related conditions or (vii) interruption of the processing, gathering or transportation of natural gas. This concentration in a limited geographic area also increases our exposure to changes in local laws and regulations, certain lease stipulations designed to protect wildlife and unexpected events that may occur in the regions such as natural disasters, seismic events, industrial accidents or labor difficulties. Any one of these factors has the potential to cause producing wells to be shut-in, delay operations, decrease cash flows, increase operating and capital costs and prevent development of lease inventory before expirations. Any of the risks described above could have a material adverse effect on our business, financial condition, results of operations and cash flow. Increased attention to environmental, social and governance (“ESG”) matters may impact our business. Increasing attention to climate change, increasing societal expectations on companies to address climate change, increasing investor and societal expectations regarding voluntary ESG disclosures, and potential increasing consumer demand for alternative forms of energy may result in increased costs, reduced demand for our products, reduced profits, increased investigations and litigation, and negative impacts on our access to capital markets. Increasing attention to climate change, for example, may result in demand shifts for natural gas and oil products and additional governmental investigations and private litigation against us. To the extent that societal pressures or political or other factors are involved, it is possible that such liability could be imposed without regard to our causation of or contribution to the asserted damage, or to other mitigating factors. In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings and recent activism directed at shifting funding away from companies with energy-related assets could lead to increased negative investor sentiment toward us and our industry and to the diversion of investment to other industries, which could have a negative impact on our share price and our access to and costs of capital, or negative tax or other cost consequences. Under some analyses, the world already produces more fossil fuel from existing sources than can be consumed over remaining resources service lives, if incremental global warming is to be kept under 1.5 degrees Celsius. Financing may be increasingly challenging, as pension funds (e.g., for major municipalities such as Boston, MA) and financial institutions divest fossil fuel investments. The loss of any member of our management team, upon whose knowledge, relationships with industry participants, leadership and technical expertise we rely could diminish our ability to conduct our operations and harm our ability to execute our business plan. Our success depends heavily upon the continued contributions of those members of our management team whose knowledge, relationships with industry participants, leadership and technical expertise would be difficult to replace. In particular, our ability to successfully acquire additional properties, to increase our reserves, to participate in drilling opportunities and to identify and enter into commercial arrangements depends on developing and maintaining close working relationships with industry participants. In addition, our ability to select and evaluate suitable properties and to consummate transactions in a highly competitive environment is dependent on our management team’s knowledge and expertise in the industry. To continue to develop our business, we rely on our management team’s knowledge and expertise in the industry. The members of our management team may terminate their employment with our Company at any time. If we were to lose members of our management team, we may not be able to replace the knowledge or relationships that they possess and our ability to execute our business plan could be materially harmed.
We are substantially dependent on a limited number of For the years ended September 30, 2022 and 2021, we had three and one significant Our business could be negatively affected by security threats, including cybersecurity threats and other disruptions. As an oil and gas producer, we face various security threats, including cybersecurity threats to gain unauthorized access to sensitive information or to render data or systems unusable; threats to the security of our facilities and infrastructure or third-party facilities and infrastructure, such as processing plants and pipelines; and threats from terrorist acts. The potential for such security threats has subjected our operations to increased risks that could have a material adverse effect on our business. In particular, our implementation of various procedures and controls to monitor and mitigate security threats and to increase security for our information facilities and infrastructure may result in increased capital and operating costs. Moreover, there can be no assurance that such procedures and controls will be sufficient to prevent security breaches from occurring. If any of these security breaches were to occur, they could lead to losses of sensitive information, critical infrastructure or capabilities essential to our operations and could have a material adverse effect on our reputation, financial position, results of operations or cash flows. Cybersecurity attacks in particular are becoming more sophisticated and include, but are not limited to, malicious software, attempts to gain unauthorized access to data and systems and other electronic security breaches that could lead to disruptions in critical systems, unauthorized release of confidential or otherwise protected information, and corruption of data. These events could lead to financial losses from remedial actions, loss of business or potential liability. The unavailability, high cost or shortages of rigs, equipment, raw materials, supplies or personnel may restrict or result in increased costs for operators related to developing and operating our properties. The oil and natural gas industry is cyclical, which can result in shortages of drilling rigs, equipment, raw materials (particularly water and sand and other proppants), supplies and personnel. When shortages occur, the costs and delivery times of rigs, equipment and supplies increase and demand for, and wage rates of, qualified drilling rig crews also rise with increases in demand. We cannot predict whether these conditions will exist in the future and, if so, what their timing and duration will be. In accordance with customary industry practice, our operators rely on independent third-party service providers to provide many of the services and equipment necessary to drill new wells. If our operators are unable to secure a sufficient number of drilling rigs at reasonable costs, our financial condition and results of operations could suffer. Shortages of drilling rigs, equipment, raw materials, supplies, personnel, trucking services, tubulars, fracking and completion services and production equipment could delay or restrict our operators’ exploration and development operations, which in turn could have a material adverse effect on our financial condition, results of operations and free cash flow. If we are unable to acquire adequate supplies of water for our future drilling and operations or are unable to dispose of the water we use at a reasonable cost and pursuant to applicable environmental rules, our ability to produce oil and natural gas commercially and in commercial quantities could be impaired. We will be using a substantial amount of water in future drilling programs and hydraulic fracturing operations. Our inability to obtain sufficient amounts of water at reasonable prices, or treat and dispose of water after drilling and hydraulic fracturing, could adversely impact our operations. Moreover, the imposition of new environmental initiatives and regulations could include restrictions on our ability to conduct certain operations such as (i) hydraulic fracturing, including, but not limited to, the use of fresh water in such operations, or (ii) disposal of waste, including, but not limited to, the disposal of produced water, drilling fluids and other wastes associated with the exploration, development and production of oil and natural gas. Opponents of hydraulic fracturing contend that either the drilling process or the sub-surface injection of fluids, such as water and drilling fluids, as part of accessing hydrocarbons, or disposing of used injection fluids, creates or magnifies seismic disturbances, and should such contentions be given credence with regard to our Company, our operations could experience more regulation, higher costs or greater delays in accessing hydrocarbon resources, or claims of parties asserting damage arising from seismic activity. Furthermore, future environmental regulations and permitting requirements governing the withdrawal, storage and use of surface water or groundwater necessary for hydraulic fracturing of wells could increase operating costs and cause delays, interruptions or termination of operations, the extent of which cannot be predicted, and all of which could have an adverse effect on our business, financial condition, results of operations and cash flows. While we intend to conduct our operations with the level of care necessary to avoid such claims, if the structural integrity of non-producing subsurface strata are impaired by hydraulic fracturing, we could face claims for damages (e.g., claims that we are producing from other geologic strata to which we do not have production rights). Risks Related to Legal and Regulatory Matters Our business is highly regulated and governmental authorities can delay or deny permits and approvals or change legal requirements governing our operations, including well stimulation, enhanced production techniques and fluid injection or disposal, that could increase costs, restrict operations and delay our implementation of, or cause us to change, our business strategy. Our operations are subject to complex and stringent federal, state, local and other laws and regulations relating to environmental protection and the exploration and development of our properties, as well as the production, transportation, marketing and sale of our products. See “Business—Governmental Regulation and Environmental Matters” for a further discussion of the laws and regulations related to our operations. Federal, state and local agencies may assert overlapping authority to regulate in these areas. In addition, certain of these laws and regulations may apply retroactively and may impose strict or joint and several liability on us for events or conditions over which we and our predecessors had no control, without regard to fault, legality of the original activities, or ownership or control by third parties. To operate in compliance with these laws and regulations, we must obtain and maintain permits, approvals and certificates from federal, state and local government authorities for a variety of activities including siting, drilling, completion, stimulation, operation, maintenance, transportation, marketing, site remediation, decommissioning, abandonment, fluid injection and disposal and water recycling and reuse. These permits are generally subject to protest, appeal or litigation, which could in certain cases delay or halt projects, production of wells and other operations. Additionally, failure to comply may result in the assessment of administrative, civil and criminal fines and penalties and liability for noncompliance, costs of corrective action, cleanup or restoration, compensation for personal injury, property damage or other losses, and the imposition of injunctive or declaratory relief restricting or limiting our operations. Under certain environmental laws and regulations, we could be subject to strict or joint and several liability for the removal or remediation of contamination, including on properties over which we and our predecessors had no control, without regard to fault, legality of the original activities, or ownership or control by third parties. Our operations may also be adversely affected by seasonal or permanent restrictions on drilling activities designed to protect various wildlife. Such restrictions may limit our ability to operate in protected areas and can intensify competition for drilling rigs, oilfield equipment, services, supplies and qualified personnel, which may lead to periodic shortages when drilling is allowed. Permanent restrictions imposed to protect threatened or endangered species or their habitat could prohibit drilling in certain areas or require the implementation of expensive mitigation measures. Costs of compliance may increase, and operational delays or restrictions may occur as existing laws and regulations are revised or reinterpreted, or as new laws and regulations become applicable to our operations. Government authorities and other organizations continue to study health, safety and environmental aspects of oil and natural gas operations, including those related to air, soil and water quality, ground movement or seismicity and natural resources. Government authorities have also adopted or proposed new or more stringent requirements for permitting, well construction and public disclosure or environmental review of, or restrictions on, oil and natural gas operations. Such requirements or associated litigation could result in potentially significant added costs to comply, delay or curtail our exploration, development, fluid injection and disposal or production activities, and preclude us from drilling, completing or stimulating wells, or venting excess production of methane which could have an adverse effect on our expected production, other operations and financial condition. Failure to comply with environmental laws and regulations could result in substantial penalties and adversely affect our business. As an owner or lessee and operator of oil and gas properties, we are subject to various federal, state, local, and foreign country laws and regulations relating to discharge of materials into, and protection of, the environment. See “Business—Governmental Regulation and Environmental Matters”. Changing law or regulations may impact market demand for our product. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up and other remediation activities resulting from operations, subject the lessee to liability for pollution and other damages, limit or constrain operations in affected areas, and require suspension or cessation of operations in affected areas. Our efforts to limit our exposure to such liability and cost may prove inadequate and result in significant adverse effects to our results of operations. In addition, it is possible that the increasingly strict requirements imposed by environmental laws and enforcement policies could require us to make significant capital expenditures. Such capital expenditures could adversely impact our free cash flows and our financial condition.
Certain U.S. federal income tax deductions currently available with respect to natural gas and oil exploration and development may be eliminated as a result of future legislation. From time to time, legislation has been proposed that would, if enacted into law, make significant changes to U.S. tax laws, including certain key U.S. federal income tax provisions currently available to oil and gas companies. Such legislative changes have included, but not been limited to, (i) the repeal of the percentage depletion allowance for natural gas and oil properties, (ii) the elimination of current deductions for intangible drilling and development costs, and (iii) an extension of the amortization period for certain geological and geophysical expenditures. Although these provisions were largely unchanged in the most recent federal tax legislation, certain of these changes were considered for inclusion in the proposed “Build Back Better Act” and Congress could consider, and could include, some or all of these proposals as part of future tax reform legislation. Moreover, other more general features of any additional tax reform legislation, including changes to cost recovery rules, may be developed that also would change the taxation of oil and gas companies. It is unclear whether these or similar changes will be enacted in future legislation and, if enacted, how soon any such changes could take effect. The passage of any legislation as a result of these proposals or any similar changes in U.S. federal income tax laws could eliminate or postpone certain tax deductions that currently are available with respect to oil and gas development or increase costs, and any such changes could have an adverse effect on our financial position, results of operations and cash flows. Our business involves the selling and shipping by rail of crude oil, which involves risks of derailment, accidents and liabilities associated with cleanup and damages, as well as potential regulatory changes that may adversely impact our business, financial condition or results of operations. A portion of our crude oil production is transported to market centers by rail. Derailments in North America of trains transporting crude oil have caused various regulatory agencies and industry organizations, as well as federal, state and municipal governments, to focus attention on transportation by rail of flammable liquids. Any changes to existing laws and regulations, or promulgation of new laws and regulations, including any voluntary measures by the rail industry, that result in new requirements for the design, construction or operation of tank cars used to transport crude oil could increase our costs of doing business and limit our ability to transport and sell our crude oil at favorable prices at market centers throughout the United States, the consequences of which could have a material adverse effect on our financial condition, results of operations and cash flows. In addition, any derailment of crude oil involving crude oil that we have sold or are shipping may result in claims being brought against us that may involve significant liabilities. Furthermore, some rail lines are not subject to material competitive pressure which would act as a brake on rates for rail transportation service. Federal and state legislative and regulatory initiatives could result in increased costs and additional operating restrictions or delays. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production. The hydraulic fracturing process is typically regulated by state oil and natural gas commissions. Any federal or state legislative or regulatory changes with respect to hydraulic fracturing could cause us to incur substantial compliance costs or result in operational delays, and the consequences of any failure to comply could have a material adverse effect on our financial condition and results of operations. In addition, in response to concerns relating to recent seismic events near underground disposal wells used for the disposal by injection of flowback and produced water or certain other oilfield fluids resulting from oil and natural gas activities (so-called “induced seismicity”), regulators in some states have imposed, or are considering imposing, additional requirements in the permitting of produced water disposal wells or otherwise to assess any relationship between seismicity and the use of such wells. States may, from time to time, develop and implement plans directing certain wells where seismic incidents have occurred to restrict or suspend disposal well operations. These developments could result in additional regulation and restrictions on the use of injection wells by our operators to dispose of flowback and produced water and certain other oilfield fluids. Increased regulation and attention given to induced seismicity also could lead to greater opposition to, and litigation concerning, oil and natural gas activities utilizing injection wells for waste disposal. Until such pending or threatened legislation or regulations are finalized and implemented, it is not possible to estimate their impact on our business. Any of the above risks could impair our ability to manage our business and have a material adverse effect on our operations, cash flows and financial position.
The adoption of climate change legislation or regulations restricting emissions of greenhouse gases could result in increased operating costs and reduced demand for the oil and natural gas we produce. Shortly after taking office in January 2021, President Biden issued a series of executive orders designed to address climate change and requiring agencies to review environmental actions taken by the Trump administration, as well as a memorandum to departments and agencies to refrain from proposing or issuing rules until a departmental or agency head appointed or designated by the Biden administration has reviewed and approved the rule. In November 2021, the Biden Administration released “The Long-Term Strategy of the United States: Pathways to Net-Zero Greenhouse Gas Emissions by 2050,” which establishes a roadmap to net zero emissions in the United States by 2050 through, among other things, improving energy efficiency; decarbonizing energy sources via electricity, hydrogen, and sustainable biofuels; and reducing non-carbon dioxide greenhouse gas (“GHG”) emissions, such as methane and nitrous oxide. These executive orders and policy priorities may result in the development of additional regulations or changes to existing regulations, certain of which could negatively impact our financial position, results of operations and cash flows. In addition, the United States is one of almost 200 nations that, in December 2015, agreed to the Paris Agreement, an international climate change agreement in Paris, France that calls for countries to set their own GHG emissions targets and be transparent about the measures each country will take to achieve its GHG emissions targets. President Biden has recommitted the United States to the Paris Agreement and, in April 2021, announced a goal of reducing the United States’ emissions by 50-52% below 2005 levels by 2030. In November 2021, the international community gathered again in Glasgow at the 26th Conference to the Parties on the UN Framework Convention on Climate Change during which multiple announcements were made, including a call for parties to eliminate certain fossil fuel subsidies and pursue further action on non-carbon dioxide GHGs. Relatedly, the United States and European Union jointly announced the launch of the “Global Methane Pledge,” which aims to cut global methane pollution at least 30% by 2030 relative to 2020 levels, including “all feasible reductions” in the energy sector. In addition, several states and geographic regions in the United States have also adopted legislation and regulations regarding climate change-related matters, and additional legislation or regulation by these states and regions, U.S. federal agencies, including the Environmental Protection Agency (“EPA”), and/or international agreements to which the United States may become a party could result in increased compliance costs for us and our customers. Failure to comply with these laws and regulations can lead to the imposition of remedial liabilities, administrative, civil or criminal fines or penalties or injunctions limiting our operations in affected areas. Moreover, multiple environmental laws provide for citizen suits which allow environmental organizations to act in the place of the government and sue operators for alleged violations of environmental law. We consider the responsibility and costs of environmental protection and safety and health compliance fundamental, manageable parts of our business. We cannot predict with any reasonable degree of certainty our future exposure concerning such matters. Several states have adopted or are considering adopting regulations that could impose more stringent permitting, public disclosure and/or well construction requirements on hydraulic fracturing operations. We cannot predict whether additional federal, state or local laws or regulations applicable to hydraulic fracturing will be enacted in the future and, if so, what actions any such laws or regulations would require or prohibit. If additional levels of regulation or permitting requirements were imposed on hydraulic fracturing operations, our business and operations could be subject to delays, increased operating and compliance costs and potential bans. Additional regulation could also lead to greater opposition to hydraulic fracturing, including litigation. Restrictions on GHG emissions that may be imposed could adversely affect the oil and gas industry. The adoption of legislation or regulatory programs to reduce GHG emissions could require us to incur increased operating costs, such as costs to purchase and operate emissions control systems, to acquire emissions allowances or to comply with new regulatory requirements. Any GHG emissions legislation or regulatory programs applicable to power plants or refineries could also increase the cost of consuming, and potentially reduce demand for, the oil and natural gas we produce. Consequently, legislation and regulatory programs to reduce GHG emissions could have an adverse effect on our business, financial condition and results of operations. See “Business—Governmental Regulation and Environmental Matters” and “—Climate Change” for a further discussion of the laws and regulations related to GHGs and of climate change. We may be involved in legal proceedings that could result in substantial liabilities. Similar to many oil and natural gas companies, we may be involved in various legal and other proceedings from time to time, such as title, royalty or contractual disputes, regulatory compliance matters and personal injury or property damage matters, in the ordinary course of our business. Such legal proceedings are inherently uncertain and their results cannot be predicted. Regardless of the outcome, such proceedings could have a material adverse impact on us because of legal costs, diversion of management and other personnel and other factors. In addition, resolution of one or more such proceedings could result in liability, loss of contractual or other rights, penalties or sanctions, as well as judgments, consent decrees or orders requiring a change in our business practices. Accruals for such liability, penalties or sanctions may be insufficient, and judgments and estimates to determine accruals or range of losses related to legal and other proceedings could change from one period to the next, and such changes could be material.
Legislation or regulatory initiatives intended to address seismic activity could restrict our operators’ drilling and production activities, which could have a material adverse effect on our business. State and federal regulatory agencies have recently focused on a possible connection between hydraulic fracturing related activities, particularly the underground injection of wastewater into disposal wells, and the increased occurrence of seismic activity, and regulatory agencies at all levels are continuing to study the possible linkage between oil and gas activity and induced seismicity. For example, in 2015, the United States Geological Study identified eight states, including Texas, with areas of increased rates of induced seismicity that could be attributed to fluid injection or oil and gas extraction. In addition, a number of lawsuits have been filed alleging that disposal well operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. In response to these concerns, regulators in some states are seeking to impose additional requirements, including requirements in the permitting of produced water disposal wells or otherwise to assess the relationship between seismicity and the use of such wells. For example, in October 2014, the Texas Railroad Commission published a new rule governing permitting or re-permitting of disposal wells that would require, among other things, the submission of information on seismic events occurring within a specified radius of the disposal well location, as well as logs, geologic cross sections and structure maps relating to the disposal area in question. If the permittee or an applicant of a disposal well permit fails to demonstrate that the produced water or other fluids are confined to the disposal zone or if scientific data indicates such a disposal well is likely to be or determined to be contributing to seismic activity, then the agency may deny, modify, suspend or terminate the permit application or existing operating permit for that well. The Texas Railroad Commission has used this authority to deny permits for waste disposal wells. In some instances, regulators may also order that disposal wells be shut in. The adoption and implementation of any new laws or regulations that restrict our operators’ ability to use hydraulic fracturing or dispose of produced water gathered from drilling and production activities by limiting volumes, disposal rates, disposal well locations or otherwise, or requiring them to shut down disposal wells, could have a material adverse effect on our business, financial condition and results of operations. Continuing political and social discussion of the issue of climate change has resulted in legislative, regulatory and other initiatives to reduce greenhouse gas emissions, such as carbon dioxide and methane. Policy makers at both the U.S. federal and state levels have introduced legislation and proposed new regulations designed to quantify and limit the emission of greenhouse gases through inventories, limitations and/or taxes on GHG emissions. The EPA has issued regulations for the control of methane emissions, which also include leak detection and repair requirements, for the oil and gas industry and are likely to create additional regulations regarding such matters. In November 15, 2021, the EPA proposed new regulations to establish comprehensive standards of performance and emission guidelines for methane and volatile organic compound emissions from new and existing operations in the oil and gas sector, including the exploration and production, transmission, processing, and storage segments. EPA hopes to finalize the proposed regulations by the end of 2022. Once finalized, the regulations are likely to be subject to legal challenge, and will also need to be incorporated into the states’ implementation plans, which will need to be approved by the EPA in individual rulemakings that could also be subject to legal challenge. As a result, we cannot predict the scope of any final methane regulatory requirements or the cost to our operations. The Inflation Reduction Act of 2022 (the “IRA”), which was signed into law in August 2022, imposes an escalating charge on methane emissions from inter alia onshore petroleum and natural gas production, and natural gas processing, gathering, transmission, underground storage, and LNG storage/ import/export equipment. The charges apply only to facilities emitting 25,000 metric tons of CO2 annually The IRA also funds grants to facilities subject to the methane charge and “marginal conventional wells” to improve equipment and processes. The IRA also creates generous tax credits, benefitting even non-profit entities, that likely will create more supply and demand for alternative non-hydrocarbon energy which may diminish demand, or prices obtained, for natural gas and oil. These statutory provisions will also be subject to legal challenge. The cumulative effect upon our business’ results of the IRA’s grants, charges, and incentives to non-hydrocarbon energy assets and fuels, is uncertain. Future additional federal GHG regulations of the oil and gas industry remain a significant possibility. Some states have imposed limitations designed to reduce methane emissions from oil and gas exploration and production activities. Legislative and state initiatives to date have generally focused on the development of renewable energy standards and/or cap-and-trade and/or carbon tax programs. Renewable energy standards (also referred to as renewable portfolio standards) require electric utilities to provide a specified minimum percentage of electricity from eligible renewable resources, with potential increases to the required percentage over time. The development of a federal renewable energy standard, or the development of additional or more stringent renewable energy standards at the state level, or continuing implementation of increasingly disadvantageous (from our industry’s perspective) renewable energy requirements embedded in existing legislation could reduce the demand for oil and gas, thereby adversely impacting our earnings, cash flows and financial position. A cap-and-trade program generally would cap overall greenhouse gas emissions on an economy-wide basis and require major sources of greenhouse gas emissions or major fuel producers to acquire and surrender emission allowances. A federal cap and trade program or expanded use of cap and trade programs at the state level could impose direct costs on us through the purchase of allowances and could impose indirect costs by incentivizing consumers to shift away from fossil fuels. In addition, federal or state carbon taxes could directly increase our costs of operation and similarly incentivize consumers to shift away from fossil fuels.
In addition, opponents of fossil fuels claiming concern about the potential effects of climate change have directed their attention at sources of funding for fossil-fuel energy companies, which has resulted in an increasing number of financial institutions, funds and other sources of capital restricting or eliminating their investment in oil and natural gas activities. Ultimately, this would make it more difficult and expensive to secure funding for exploration and production activities. Members of the investment community have also begun to screen companies such as ours for sustainability performance, including practices related to GHGs and climate change, before investing in our These various legislative, regulatory and other activities addressing greenhouse gas emissions could adversely affect our business, including by imposing reporting obligations on, or limiting emissions of greenhouse gases from, our equipment and operations, which could require us to incur costs to reduce emissions of GHGs associated with our operations. Limitations on GHG emissions could also adversely affect demand for oil and gas, which could lower the value of our reserves and have a material adverse effect on our profitability, financial condition and liquidity. Some of our properties are in areas that may have been partially depleted or drained by offset wells and certain of our wells may be adversely affected by actions we or other operators may take when drilling, completing, or operating wells that we or they own. Some of our properties are in reservoirs that may have already been partially depleted or drained by earlier offset drilling. The owners of leasehold interests adjoining any of our properties could take actions, such as drilling and completing additional wells, which could adversely affect our operations. When a new well is completed and produced, the pressure differential in the vicinity of the well causes the migration of reservoir fluids toward the new wellbore (and potentially away from existing wellbores). As a result, the drilling and production of these potential locations by us or other operators could cause depletion of our proved reserves and may inhibit our ability to further develop our proved reserves. In addition, completion operations and other activities conducted on adjacent or nearby wells by us or other operators could cause production from our wells to be shut in for indefinite periods of time, could result in increased lease operating expenses and could adversely affect the production and reserves from our wells after they re-commence production. We have no control over the operations or activities of offsetting operators. Risks Related to this Offering and our The market price of our Securities markets have a high level of price and volume volatility, and the market price of securities of many companies has experienced substantial volatility in the past. This volatility may affect the ability of holders of our In addition, financial markets have historically, at times, experienced significant price and volume fluctuations that have particularly affected the market prices of equity securities of companies and that have often been unrelated to the operating performance, underlying asset values, or prospects of such companies. If there is extreme market volatility and trading patterns in our securities, it may create several risks for investors, including the following:
Accordingly, the market price of our
We have broad discretion in the use of the net proceeds from this offering and may not use them effectively. Our management will have broad discretion in the application of the net proceeds to us from this offering and could spend the proceeds in ways that do not improve our results of operations or enhance the value of our securities. The failure by our management to apply these funds effectively could result in financial losses that could have a material adverse effect on our business, cause the price of our securities to decline. There is no assurance that an investment in our There is no assurance that an investment in our Even if we meet the initial listing requirements of The Nasdaq Capital Market,there can be no assurance that we will be able to comply with The Nasdaq Capital Market’scontinued listing standards, a failure of which could result in a de-listing of our securities. Our Common Shares are currently quoted on the OTCQB. We have applied to list our Common Shares and Warrants on The Nasdaq Capital Market. There is no assurance that our Common Shares and Warrants will ever be listed on The Nasdaq Capital Market or that we will be able to comply with such applicable listing standards. Should our Common Shares and Warrants become listed on The Nasdaq Capital Market, in order to maintain that listing, The Nasdaq Capital Market requires that we satisfy minimum financial and other continued listing requirements and standards, including those regarding director independence and independent committee requirements, minimum stockholders’ equity, and certain corporate governance requirements. If we are unable to satisfy these requirements or standards, we could be subject to delisting, which would have a negative effect on the price of our Common Shares and Warrants and would impair your ability to sell or purchase our Common Shares and Warrants when you wish to do so. In the event of a delisting, we would expect to take actions to restore our compliance with the listing requirements, but we can provide no assurance that any such action taken by us would allow our Common Shares and Warrants to become listed again, stabilize the market price or improve the liquidity of our Common Shares and Warrants or prevent future non-compliance with the listing requirements. If, for any reason, we should fail to maintain compliance with these listing standards and Nasdaq should delist our securities from trading on its exchange and we are unable to obtain listing on another national securities exchange, a reduction in some or all of the following may occur, each of which could have a material adverse effect on our shareholders:
We have never paid cash dividends and have no plans to pay cash dividends in the future. Holders of our
Sales of a substantial number of our Common Shares in the public market or otherwise following this offering, or the perception that such sales could occur, could adversely affect the We may need to raise additional funds to support our business operations or to finance future acquisitions, including through the issuance of equity or debt securities, which could have a material adverse effect on our ability to grow our business, and may dilute your ownership in us. If we do not generate sufficient cash from operations or do not otherwise have sufficient cash and cash equivalents to support our business operations or to finance future acquisitions, we may need raise addition capital through the issuance of debt or equity securities. We do not have any arrangements for any credit facility, or any other sources of capital. We may not be able to raise cash in future financing on terms acceptable to us, or at all. Financings, if available, may be on terms that are dilutive to our shareholders, and the prices at which new investors would be willing to purchase our securities may be lower than the current price of our We have issued options and warrants and may continue to issue additional securities in the future. The exercise of these securities and the sale of the As of If you purchase our securities in this offering, you may in the future incur dilution in the book value of your shares. Although you will not incur immediate dilution as a result of this offering, to the extent outstanding options or warrants are exercised, you may experience future dilution of your equity interests in the Company. As a result of possible future dilution, investors purchasing Common Units in this offering may receive significantly less than the purchase price paid in this offering, if anything, in the event of our liquidation.
There is no public market for either the Warrants or the Pre-funded Warrants being sold in this offering. There is no established public trading market for either the Warrants or the Pre-funded Warrants being sold in this offering. We intend to list the Warrants on The Nasdaq Capital Market, however there is no assurance that any market will develop. We will not list the Pre-funded Warrants on any securities exchange or nationally recognized trading system, including The Nasdaq Capital Market. Therefore, we do not expect a market to ever develop for the Pre-funded Warrants. Without an active market, the liquidity of the Pre-funded Warrants will be limited. The Warrants and Pre-funded Warrants are speculative in nature. Neither the Warrants nor the Pre-funded Warrants confer any rights of Common Share ownership on their respective holders, such as voting rights or the right to receive dividends, but rather merely represent the right to acquire Common Shares at a fixed price. Commencing on the date of issuance, holders of the Warrants may exercise their right to acquire the Common Shares and pay the stated exercise price per share prior to five years from the date of issuance, after which date any unexercised Warrants will expire and have no further value. Commencing on the date of issuance, holders of the Pre-funded Warrants may exercise their right to acquire the Common Shares and pay the stated exercise price per share until exercised in full. There can be no assurance that the market price of our Common Shares will ever equal or exceed the exercise price of the Warrants offered by this prospectus, and if so, the Warrants would expire without value. The Warrants included in the Common Units and Pre-Funded Units are expected to be listed on The Nasdaq Capital Marketseparately upon the pricing of this offering, and may provide investors with an arbitrage opportunity that could adversely affect the trading price of our Common Shares. Because the Common Units and Pre-Funded Units will never trade as a unit, and the Warrants are expected to be traded on The Nasdaq Capital Market, investors may be provided with an arbitrage opportunity that could depress the price of our Common Shares. In the event that our Common Share price does not exceed the exercise price of the Warrants or the Pre-funded Warrants during the period when the Warrants or the Pre-funded Warrants are exercisable, as applicable, such warrants may not have any value. Until holders of the Warrants and the Pre-funded Warrants acquire Common Shares upon exercise thereof, holders of the Warrants and Pre-funded Warrants will have no rights with respect to our Common Shares. Upon exercise of the Pre-funded Warrants, such holders will be entitled to exercise the rights of a common There is no assurance that any of the Warrants will be exercised and we will receive the exercise proceeds therefrom. The Warrants have an exercise price above the price of a Common Share. If the price of our Common Shares does not exceed the Warrant exercise price, then it is unlikely that the Warrants will be exercised. The Warrants will expire on the fifth anniversary of their issuance, which if they expire without being exercised the Company will not receive any proceeds therefrom. Additionally, for the Warrants to be exercised for cash, we must keep an effective registration statement available for issuance of the Common Shares issuable on exercise of the Warrants. If we fail to maintain an effective registration statement, then the Warrants may be exercised on a cashless basis, and we will not receive any cash amount from their exercise. Our principal shareholders and management own a significant percentage of our shares and may be able to exert significant control over matters subject to shareholder approval.
We are a British Columbia company and it may be difficult for you to enforce judgments against us or certain of our directors or officers. As a corporation organized under the provincial laws of British Columbia, Canada, it may be difficult to bring actions under U.S. federal securities law against us. Some of our directors and officers reside principally in Canada or outside of the United States. Because a portion of our assets and the assets of these persons are located outside of the United States, it may not be possible for investors to effect service of process within the United States upon us or those persons. Furthermore, it may not be possible for investors to enforce against us, or those persons not in the United States, judgments obtained in U.S. courts based upon the civil liability provisions of the U.S. federal securities laws or other laws of the United States. There is doubt as to the enforceability, in original actions in Canadian courts, of liabilities based upon U.S. federal securities laws and as to the enforceability in Canadian courts of judgments of U.S. courts obtained in actions based upon the civil liability provisions of the U.S. federal securities laws. Therefore, it may not be possible to enforce those actions against us or certain of our directors and officers. If securities or industry analysts do not publish research or publish inaccurate or unfavorable research about our business, our share price and trading volume could decline. The trading market for our Common Shares and Warrants will depend in part on the research and reports that securities or industry analysts publish about us or our business. Securities and industry analysts may never publish research on our Company. If no securities or industry analysts cover our Company, the trading price for our Common Shares and Warrants would likely be negatively impacted. In the event securities or industry analysts cover our Company, if one or more of the analysts who covers us downgrades our shares or publishes inaccurate or unfavorable research about our business, our share price may decline. If one or more of these analysts ceases coverage of our Company or fails to publish reports on us regularly, demand for our shares could decrease, which might cause our share price and trading volume to decline. Substantial amounts of our outstanding shares may be sold into the market when lock-up periods end. If there are substantial sales of shares of our Common Shares, the price of our Common Shares could decline. All of our outstanding Common Shares held by our directors and executive officers are subject to contractual lock-up restrictions on resale as more fully described in the section titled “Underwriting” in this prospectus. If these shareholders sell, or indicate an intent to sell, substantial amounts of our Common Shares in the public market after the expiration of the applicable lock-up period, the trading price of our Common Shares could decline significantly and could decline below the public offering price. Unstable market and economic conditions and adverse developments with respect to financial institutions and associated liquidity risk may have serious adverse consequences on our business, financial condition and stock price. The global credit and financial markets have recently experienced extreme volatility and disruptions, including severely diminished liquidity and credit availability, declines in consumer confidence, declines in economic growth, inflationary pressure and interest rate changes, increases in unemployment rates and uncertainty about economic stability. The financial markets and the global economy may also be adversely affected by the current or anticipated impact of military conflict, terrorism or other geopolitical events. Sanctions imposed by the United States and other countries in response to such conflicts may also adversely impact the financial markets and the global economy, and any economic countermeasures by the affected countries or others could exacerbate market and economic instability. More recently, the closures of Silicon Valley Bank and Signature Bank and their placement into receivership with the Federal Deposit Insurance Corporation (“FDIC”) created bank-specific and broader financial institution liquidity risk and concerns. Although the Department of the Treasury, the Federal Reserve, and the FDIC jointly confirmed that depositors at SVB and Signature Bank would continue to have access to their funds, even those in excess of the standard FDIC insurance limits, under a systemic risk exception, future adverse developments with respect to specific financial institutions or the broader financial services industry may lead to market-wide liquidity shortages, impair the ability of companies to access near-term working capital needs, and create additional market and economic uncertainty. There can be no assurance that future credit and financial market instability and a deterioration in confidence in economic conditions will not occur. Our general business strategy may be adversely affected by any such economic downturn, liquidity shortages, volatile business environment or continued unpredictable and unstable market conditions. If the equity and credit markets deteriorate, or if adverse developments are experienced by financial institutions, it may cause short-term liquidity risk and also make any necessary debt or equity financing more difficult, more costly and more dilutive. Failure to secure any necessary financing in a timely manner and on favorable terms could have a material adverse effect on our growth strategy, financial performance and stock price and could require us to delay or abandon our business plans. An investment in our An investment in our
We may be treated as a passive foreign investment company (“PFIC”), which could result in adverse U.S. federal income tax consequences to U.S. investors. If we are treated as a PFIC for any taxable year in which a U.S. Holder (as defined in the section of this prospectus captioned “Tax Considerations— We do not intend to provide the information that would otherwise enable U.S. Holders to make a “qualified electing fund” (“
General Risk Factors We are an “emerging growth company” and a “smaller reporting company” and will be able to avail ourselves of reduced disclosure requirements applicable to emerging growth companies and/or smaller reporting companies, which could make our We are an “emerging growth company,” as defined in the JOBS Act and we intend to take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not “emerging growth companies” including not being required to comply with the auditor attestation requirements of Section 404(b) of the Sarbanes-Oxley Act, reduced disclosure obligations regarding executive compensation in our periodic reports and proxy statements, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and shareholder approval of any golden parachute payments not previously approved. In addition, Section 107 of the JOBS Act also provides that an “emerging growth company” can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act, for complying with new or revised accounting standards. In other words, an “emerging growth company” can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We may take advantage of these reporting exemptions until we are no longer an “emerging growth company.” We will remain an “emerging growth company” until the earliest of (i) the last day of the fiscal year in which we have total annual gross revenues of $1.235 billion or more; (ii) the last day of our fiscal year following the fifth anniversary of the date of the completion of our initial public offering; (iii) the date on which we have issued more than $1 billion in nonconvertible debt during the previous three years; or (iv) the date on which we are deemed to be a large accelerated filer under the rules of the SEC. In addition, even if we no longer qualify as an “emerging growth company,” we may still take advantage of certain reduced reporting requirements as a “smaller reporting company.” If we are a smaller reporting company at the time we cease to be an emerging growth company, we may continue to rely on exemptions from certain disclosure requirements that are available to smaller reporting companies. Specifically, as a smaller reporting company, we may choose to present only the two most recent fiscal years of audited financial statements in our Annual Report on Form 10-K and have reduced disclosure obligations regarding executive compensation, and, similar to emerging growth companies, if we are a smaller reporting company, we may not be required to obtain an attestation report on internal control over financial reporting issued by our independent registered public accounting firm. We cannot predict if investors will find our Failure to maintain effective internal control over our financial reporting in accordance with Section 404 of the Sarbanes-Oxley Act could cause our financial reports to be inaccurate. We are required pursuant to Section 404 of the Sarbanes-Oxley Act to maintain internal control over financial reporting and to assess and report on the effectiveness of those controls. This assessment includes disclosure of any material weaknesses identified by our management in our internal control over financial reporting. Although we prepare our financial statements in accordance with accounting principles generally accepted in the United States (“US GAAP”), our internal accounting controls may not meet all standards applicable to companies with publicly traded securities. If we fail to implement any required improvements to our disclosure controls and procedures, we may be obligated to report control deficiencies in which case, we could become subject to regulatory sanction or investigation. Further, these outcomes could damage investor confidence in the accuracy and reliability of our financial statements.
As of
Although management has taken steps to address the deficiencies in our internal controls, we currently do not have sufficient internal controls over financial reporting which could limit investment in our securities and expose the us to SEC fines or administrative sanctions. Additionally, if we fail to implement required improvements to our disclosure controls and procedures, we may be obligated to continue to report control deficiencies in which case, we could become subject to regulatory sanction or investigation. Further, these outcomes could damage investor confidence in the accuracy and reliability of our financial statements. Financial reporting obligations of being a public company in the U.S. are expensive and time-consuming, and our management will be required to devote substantial time to compliance matters. As a publicly traded company we incur significant legal, accounting and other expenses. The obligations of being a public company in the U.S. requires significant expenditures and may place significant demands on our management and other personnel, including costs resulting from public company reporting obligations under the Exchange Act and the rules and regulations regarding corporate governance practices, including those under the Sarbanes-Oxley Act, the Dodd-Frank Wall Street Reform and Consumer Protection Act, and the listing requirements of the stock exchange on which our securities are listed. These rules require the establishment and maintenance of effective disclosure and financial controls and procedures, internal control over financial reporting and changes in corporate governance practices, among many other complex rules that are often difficult to implement, monitor and maintain compliance with. Moreover, despite recent reforms made possible by the JOBS Act, the reporting requirements, rules, and regulations will make some activities more time-consuming and costly, particularly after we are no longer an “emerging growth company” or a “smaller reporting company.” In addition, these rules and regulations may make it more difficult and more expensive for us to obtain director and officer liability insurance. Our management and other personnel will need to devote a substantial amount of time to ensure that we comply with all of these requirements and to keep pace with new regulations, otherwise we may fall out of compliance and risk becoming subject to litigation or being delisted, among other potential problems. CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS The information in this prospectus includes “forward-looking statements.” All statements, other than statements of historical fact included in this prospectus, regarding our strategy, future operations, financial position, estimated revenue and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this prospectus, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on our current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements described under “Risk Factors.” These forward-looking statements are based on management’s current belief, based on currently available information, as to the outcome and timing of future events. Forward-looking statements may include statements about:
We caution you that these forward-looking statements are subject to risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the exploration for and development, production and sale of natural gas. These risks include, but are not limited to, commodity price volatility, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating natural gas reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described under “Risk Factors.” Reserve engineering is a method of estimating underground accumulations of natural gas and oil that cannot be measured in an exact way. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data and price and cost assumptions made by reserve engineers. In addition, the results of drilling, testing and production activities may justify revisions of previous estimates. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of natural gas and oil that are ultimately recovered. Should one or more of the risks or uncertainties described in this prospectus occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, express or implied, included in this prospectus are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this prospectus.
MARKET FOR OUR COMMON Market Information Our
Shareholders As of Securities Authorized for Issuance Under Equity Compensation Plans The following table summarizes information about our equity compensation plans as of September 30, 2022.
Assuming the sale of all of the Common Units in this offering at an assumed offering price of $6.98 per Common Unit (assuming no sale of any Pre-funded Units), the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split effected on October 23, 2023, the Company estimates that the Net Proceeds from the sale of Common Units in this offering will be approximately $11.43 million. If the underwriters fully exercise the over-allotment option, the Net Proceeds will be approximately $13.27 million. “Net Proceeds” is what the Company expects to receive after deducting the underwriting discount and commission and estimated offering expenses payable by the Company. Each $1.00 increase (decrease) in the assumed public offering price of $6.98 per Common Unit would increase (decrease) our Net Proceeds by approximately $1.74 million, assuming that the number of Common Units offered by us, as set forth on the cover page of this prospectus, remains the same. Similarly, each increase (decrease) of 100,000 Common Units in the number of Common Units offered by us at the assumed public offering price of $6.98 per Common Unit, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split, would increase (decrease) the Net Proceeds by approximately $0.64 million.
We intend to use the Net Proceeds of this offering to fund our budgeted capital expenditures to continue to develop our proved undeveloped reserves during for the 2024 fiscal year, as well as for continuing operating expenses and working capital. We believe opportunities may exist from time to time to expand our current business through acquisitions or investments. While we have no current agreements, commitments or understandings for any specific acquisitions or investments, we may also use a portion of the Net Proceeds for these purposes. We believe that the Net Proceeds from this offering, together with our existing cash and cash equivalents, will enable us to fund our operating expenses and capital expenditure requirements through at least the next twelve months from the date of this offering. DIVIDEND POLICY Our board of directors (“Board of We have never paid or declared any cash dividends on our The following table sets forth our
You should read this table in conjunction with the sections titled and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our financial statements and related notes included elsewhere in this prospectus.
Each $1.00 increase (decrease) in the assumed public offering price of $6.98 per Common Unit, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split effected on October 23, 2023, would increase (decrease) the as adjusted amount of each of cash and cash equivalents, working capital, total assets and total stockholders’ equity (deficit) by approximately $1.74 million, assuming that the number of Common Units offered by us, as set forth on the cover page of this prospectus, remains the same and after deducting underwriting discounts and commissions and estimated offering expenses payable by us. Similarly, each increase (decrease) of 100,000 shares in the number of Common Units offered by us at the assumed public offering price of $6.98 per Common Unit, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split effected on October 23, 2023, would increase (decrease) the pro forma as adjusted amount of each of cash and cash equivalents, working capital, total assets and total stockholders’ equity (deficit) by approximately $0.64 million.
The number of
DILUTION All share-related information presented in this section gives effect to the Reverse Stock Split effected on October 23, 2023. If you invest in our Common Units in this offering, your interest will be diluted to the extent of the difference between the public offering price per Common Unit (assuming no value is attributed to the Warrants and no Pre-Funded Warrants are sold in the offering) and the as adjusted net tangible book value per share of our Common Shares immediately after this offering (assuming no value is attributed to the Warrants and no Pre-Funded Warrants are sold in the offering). We calculate net tangible book value per share by dividing our net tangible book value, which is tangible assets less total liabilities, by the number of our outstanding Common Shares as of June 30, 2023. Our net tangible book value as of June 30, 2023, was $7,821,408 or approximately $14.18 per Common Share. After giving effect to our issuance and sale of Common Units in this offering at an assumed public offering price of $6.98 per Common Share, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split, excluding Common Shares that may be issued upon exercise of the underwriter’s over-allotment option and after deducting estimated underwriting discounts and commissions and estimated offering expenses, our as adjusted net tangible book value as of June 30, 2023 would have been $19,252,882, or $7.85 per Common Share. This represents an immediate decrease in net tangible book value of $6.33 per share to existing shareholders and an increase in net tangible book value of $0.87 to purchasers of Common Units in this offering, based on an assumed public offering price of $6.98 per Common Share, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the proposed Reverse Stock Split. The following table illustrates this per share:
The information discussed above is illustrative only, and the dilution information following this offering will be adjusted based on the actual public offering price and other terms of this offering determined at pricing. Each $1.00 increase (decrease) in the assumed public offering price, would increase (decrease) as adjusted net tangible book value per share to new investors by $0.71, and would increase (decrease) dilution per share to new investors in this offering by $0.29, assuming that the number of Common Units offered by us, as set forth on the cover page of this prospectus, remains the same, and after deducting estimated underwriting discounts and commissions and estimated offering expenses payable by us. Similarly, each increase or decrease of 100,000 in the number of Common Units by us would increase (decrease) our as adjusted net tangible book value by approximately $0.06 per share and increase (decrease) the dilution to new investors by $0.06 per share, assuming the assumed public offering price remains the same, and after deducting the estimated underwriting discounts and commissions and estimated offering expenses payable by us. If the underwriters’ over-allotment option to purchase additional Common Shares from the Company is exercised in full, and based on the assumed public offering price of $6.98 per Common Unit, the closing price of our common shares as quoted on the OTCQB on October 20, 2023 after giving effect to the Reverse Stock Split, the as adjusted net tangible book value per share after this offering would be $7.71 per share, the decrease in as adjusted net tangible book value per share to existing shareholders would be $6.47 per share and increase to new investors purchasing shares in this offering of $0.73. The number of Common Shares outstanding is based on 551,503 Common Shares issued and outstanding as of June 30, 2023, and excludes the following as of such date:
MANAGEMENT’S DISCUSSION AND ANALYSIS
You should read the following discussion and analysis of our financial condition and results of operations together with the Company’s consolidated financial statements and the related notes thereto and other financial information included elsewhere in this prospectus. Some of the information contained in this discussion and analysis or set forth elsewhere in this prospectus, including information with respect to our plans and strategy for our business, includes forward-looking statements that involve risks and uncertainties. You should review the “Cautionary Note Regarding Forward-Looking Statements” and “Risk Factors” sections of this prospectus for a discussion of important factors that could cause actual results to differ materially from the results described in or implied by the forward-looking statements contained in the following discussion and analysis. All amounts in this discussion and analysis of our financial condition and results of operations are in U.S. dollars, unless otherwise noted.
Overview The Company was incorporated on April 24, 2017 under the laws of British Columbia, Canada. The Company is an independent energy company engaged in the acquisition, exploration, development and production of oil and gas properties on private, state and federal land in the United States, primarily in the Permian Basin which includes the Midland Basin and Delaware Basin. The Company focuses on acquiring producing assets at a discount to market, increasing production and cash-flow through recompletion and re-entries, secondary recovery and reducing risk by infill drilling and development. Currently, the Company owns and operates various oil and gas properties located in Texas and New Mexico. In addition, the Company holds various royalty interests in 73 wells and 5 permitted wells across 3,800 acres within the Permian Basin of West Texas and southeast New Mexico. Moreover, the Company has more than 11,700 net acres of producing oil and gas assets, 62 shut-in opportunities, and 17 salt water disposal wells allowing for waterflood secondary recovery. Key activities:
Oil And Gas Properties Breedlove “B” Clearfork Leases - Texas In September 2021, the Company, through its wholly-owned subsidiary, Permex Pittcock Leases - Texas The Pittcock Leases are situated in Stonewall County. Stonewall County is in Northwest Texas, in the central part of the North Central Plains and consists of the Pittcock North property, the Pittcock South property and the Windy Jones Property. It is bounded on the north by King County, on the east by Haskell County, on the south by Fisher and Jones Counties, and on the west by Kent County. The Pittcock North property covers 320 acres held by production. There is currently one producing well, ten shut-in wells, two saltwater disposal wells, and a water supply well. The Company holds a 100% working interest in the Pittcock North Property and an 81.25% net revenue interest. The Pittcock South property covers 498 acres in four tracts. There are currently 19 shut-in wells and two saltwater disposal wells. The Company holds a 100% working interest in the lease and a 71.90% net revenue interest. The Windy Jones Property consists of 40 acres and includes two injection wells and two suspended oil wells. The sole purpose of the Windy Jones property is to provide waterflood to the offset wells being the Pittcock wells located east boundary of the Windy Jones Property. The Company holds a 100% working interest in the Windy Jones Property and a 78.9% net revenue interest. Mary Bullard Property - Texas The Company acquired the Mary Bullard Property in August 2017 for a cash consideration of approximately $50,000. The Mary Bullard Property is located in Stonewall County, about 5 ½ miles south west of Aspermont, Texas. It is bounded on the north by King County, on the east by Haskell County, on the south by Fisher and Jones Counties, and on the west by Kent County. The asset is situated on the Eastern Shelf of the Midland Basin in the central part of the North Central Plains. The Mary Bullard Property covers 241 acres held by production and is productive in the Clearfork formation at a depth of approximately 3,200 feet. There is currently one producing well, four shut-in wells, and two water injection wells. The Company holds a 100% working interest in the Mary Bullard Property and a 78.625% net revenue interest. West Henshaw Property - New Mexico The West Henshaw Property is located in Eddy County, New Mexico, 12 miles northeast of Loco Hills in the Delaware Basin. Eddy County is in Southeast New Mexico. It is bounded by Chaves County to the north, Otero County to the east, Loving County, Texas to the south, and Lea County to the west. The West Henshaw Property covers 1,880 acres held by production. There are two producing wells, seven shut-in wells and four saltwater disposal wells. The Company holds a 100% working interest in the West Henshaw Property and a 72% net revenue interest. In January 2022, the Company began the pilot re-entry on the West Henshaw well #15-3, one out of the 67 shut-in wells it currently owns. The re-entry and re-stimulation involved the West Henshaw property targeting the Grayburg formation at a depth of 2,850 feet. The recompletion was successful and came online at an initial rate of 30 bopd and has stabilized at 15 bopd. In April 2022, the Company began the re-entry on the West Henshaw well #6-10. The re-entry and re-stimulation involved the West Henshaw property targeting the Grayburg formation at a depth of 2,850 feet. The recompletion was successful and came online at an initial rate of 15 bopd and has stabilized at 10 bopd. The remaining 67 shut-in wells that the Company plans to re-enter have potential to yield similar results increasing our total daily production solely by re-entering shut-in wells. Oxy Yates Property - New Mexico The Oxy Yates Property is located in Eddy County, approximately eight miles north of Carlsbad, New Mexico in the Delaware Basin. It is bounded by Chaves County to the north, Otero County to the east, Loving County, Texas to the south, and Lea County to the west. The Oxy Yates Property covers 680 acres held by production. There is one producing well and nine shut-in wells. The Yates formation is located at an average depth of 1,200 feet and overlies the Seven River formation and underlies the Tansill formation. The Company holds a 100% working interest in the Oxy Yates Property and a 77% net revenue interest. Royalty Interest Properties
During the year ended September 30, 2021, the Company acquired royalty interests in 73 producing oil and gas wells located in Texas and New Mexico for $179,095.
Conversion of Undeveloped Acreage The Company’s process for converting undeveloped acreage to developed acreage is tied to whether there is any drilling being conducted on the acreage in question. The Company has started development and conversion of its undeveloped acreage located in Martin County, Texas. The PPC Eoff #3 well, operated by Permex Petroleum, is the first of two permitted wells to be drilled by Permex on the 7,780 gross acre Breedlove oilfield. Drilling of the first well commenced on September 14, 2022. Management furthermore expects to commence lateral drilling and completion of the well by January 2024, subject to the Company acquiring the necessary financing. An aggregate of 5,083 MBO and 2,136 MMCF, of the Company’s proved undeveloped reserves as of September 30, 2022, are part of a development plan that has been adopted by management that calls for these undeveloped reserves to be drilled within the next five years, thus resulting in the conversion of such proved undeveloped reserves to developed status within five years of initial disclosure at September 30, 2022. Management currently anticipates spending approximately $10 million in capital expenditures towards developing the Company’s proved undeveloped reserves during the 2023 fiscal year, subject to the Company acquiring the necessary financing.
Financing of Proved and Probable Undeveloped Reserves The Company currently estimates that the total cost to develop the Company’s proved undeveloped reserves of 5,083.2 MBbl of oil and 2,136.4 Mcf of natural gas as of September 30, 2022 is $68,818,530. The Company expects to finance these capital costs through a combination of current cash on hand, debt financing through a line of credit or similar debt instrument, one or more offerings of debt or equity, and from cash generated from estimated revenues from sales of oil and natural gas produced at the Company’s wells. The Company currently estimates that the total cost to develop the Company’s probable undeveloped reserves of 7,334.3 MBbl of oil and 10,307.1 Mcf of natural gas as of September 30, 2022 is $107,884,900. The Company expects to finance these capital costs through a combination of joint ventures, farm-in agreements, direct participation programs, one or more offerings of equity, a debt offering or entering into a line of credit, and from cash generated from estimated revenues from sales of oil and natural gas produced at the Company’s wells. Drilling Activities The Company drilled one well during the last three fiscal years. As at
The Company has 6,000 gross undeveloped acres and 4,800 net undeveloped acres. All of the Company’s undeveloped acreage is on the Company’s Breedlove property. The Company’s leases are held by production in perpetuity. If a field/lease is undeveloped it typically has a 2, 3 or 5 year term of expiry. The Company has over 340 leases covering undeveloped acreage and less than 5% of these leases have an expiry date that is less than two years from the date of the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2023. Selected Annual Information The following table sets out selected financial information for the Company which has been derived from the Company’s audited financial statements for the fiscal years ended September 30, 2022 and 2021.
Factors That Affect the Comparability of the Annual Financial Data Disclosed Above Net losses for the years ended September 30, 2022 and 2021 were mainly attributable to operating expenses (2022 - $3,778,693, 2021 - $1,324,361) and other income/expense (2022 - income of $185,618, 2021 - expense of $13,506), partially offset by revenue from oil and gas sales and royalty income (2022 - $878,459, 2021 - $84,625). The increase in total assets in fiscal 2022 is due to net proceeds of $7,044,472 raised from private placement financings. The change in non-current liabilities in fiscal 2022 is mainly due to the changes in estimates on asset retirement obligations.
Results of Operations Selected Operating Data Annual Sales and Production Results The average sales prices of the Company’s oil and gas products sold in the fiscal years ended September 30, 2022, 2021, and 2020 was $89.14, $54.19, and $38.51, respectively. The Company’s net production quantities by final product sold in the fiscal years ended September 30, 2022, 2021, and 2020, was 12,597.45 Boe, 1,182.70 Boe, and 17,772.14 Boe, respectively. The Company’s average production costs per unit for the fiscal years ended September 30, 2022, 2021, and 2020, was $65.82, $40.94, and $32.59, respectively. The breakdown of production and prices between oil/condensate and natural gas was as follows:
The breakdown of the Company’s production quantities by individual product type for each of the Company’s fields that contain 15% or more of the Company’s total proved reserves expressed on an oil-equivalent-barrels basis was as follows: Breedlove
Henshaw
Pittcock & Mary Bullard
ODC San Andres
During the year ended September 30, 2022, the Company reported a net loss of $2,714,616 as compared to a net loss of $1,253,242 for the year ended September 30, 2021. The net loss for fiscal 2022 was mainly attributable to operating expenses of $3,778,693 compared to operating expenses of $1,324,361 in fiscal 2021, being partially offset by revenue from oil and gas sales and royalty income of $878,459 in fiscal 2022 compared to $84,625 in fiscal 2021. The Company reported oil and gas sales revenue of $815,391 in fiscal 2022 compared with revenue of $46,703 in 2021. The increase was mainly due to revenue generated from sales of oil and gas extracted from our Breedlove “B” Clearfork properties that were acquired at the end of fiscal 2021, which accounted for 70% of the Company’s oil and gas sales in the current year. The Company also brought Pittcock North, Mary Bullard, and West Henshaw wells back online during the second quarter of fiscal 2022. Net oil-equivalent production by final product sold in fiscal 2022 average 34.51 barrels per day, compared with 3.24 barrels per day in fiscal 2021. The production expenses for fiscal 2022 were $829,194 compared with $59,671 in fiscal 2021. The increase was mostly due to the increase in production in 2022 compared to 2021 combined with increased maintenance expenses related to bringing the West Henshaw wells back online in 2022. The general and administrative expenses excluding share-based payment expenses for fiscal 2022 were $2,250,060, compared with $493,511 in fiscal 2021. This increase in 2022 from 2021 was mainly due to the increase in capital raising and marketing activities during 2022. Specifically, the variance in 2022 from 2021 was mainly attributable to:
Depreciation and depletion expenses (2022 - $105,503, 2021 - $60,479) increased in fiscal 2022 from 2021 primarily due to Breedlove acquisition at the end of fiscal 2021 and increased production. The Company also incurred share-based compensation expenses of $546,335 in fiscal 2022 compared to $2,870 in fiscal 2021, mostly as a result of the Company granting 3,300,000 stock options to the Company’s directors and consultants in October 2021. Share-based compensation expenses are a non-cash charge that are the estimated fair value of the stock options granted and vested during the period. The Company used the Black-Scholes option pricing model for the fair value calculation.
Results of Operations Sales and Production The average sales prices of the Company’s oil and gas products sold in the nine months ended June 30, 2023 and 2022, and the fiscal year ended September 30, 2022 was $72.59/Boe, $88.39/Boe, and $89.14/Boe, respectively. The average sales prices of the Company’s oil and gas products sold in the three months ended June 30, 2023 and 2022 was $66.91/Boe and $102.05/Boe, respectively. The Company’s net production quantities by final product sold in the nine months ended June 30, 2023 and 2022, and the fiscal year ended September 30, 2022 was 10,260.71 Boe, 8,903.60 Boe, and 12,597.45 Boe, respectively. The Company’s net production quantities by final product sold in the three months ended June 30, 2023 and 2022 was 3,258.07 Boe and 3,404.75 Boe, respectively. The Company’s average production costs per unit for the nine months ended June 30, 2023 and 2022, and the fiscal year ended September 30, 2022, was $74.33/Boe, $37.33/Boe, and $65.82/Boe, respectively. The Company’s average production costs per unit for the three months ended June 30, 2023 and 2022 was $72.29/Boe and $39.79/Boe, respectively. The breakdown of production and prices between oil/condensate and natural gas was as follows:
The breakdown of the Company’s production quantities by individual product type for each of the Company’s fields that contain 15% or more of the Company’s total proved reserves expressed on an oil-equivalent-barrels basis was as follows: Breedlove
Henshaw
Pittcock & Mary Bullard
Operating Results for the Three and Nine Months Ended June 30, 2023 Compared to June 30, 2022 Three Months Ended June 30, 2023 and 2022 During the three months ended June 30, 2023, the Company reported a net loss of $909,593 as compared to a net loss of $888,669 for the three months ended June 30, 2022 mostly as a result of decreased revenue during the third quarter of 2023 compared to the same quarter in 2022. The Company reported oil and gas sales revenue of $156,716 in the third quarter of the current fiscal year compared with revenue of $258,757 in the same quarter during the last fiscal year. The decrease was mainly due to the decrease in oil and gas prices in the current quarter to $66.91/Boe from $102.05/Boe in the comparative quarter. Net oil-equivalent production by final product sold in the current quarter averaged 35.80 barrels per day, compared with 25.87 barrels per day in the same quarter of the previous fiscal year. The Company’s total operating expenses for the three months ended June 30, 2023 was $1,072,760 compared to $1,247,531 for the same period in 2022. The decrease in total operating expenses in the third quarter of 2023 compared to the third quarter of 2022 was mainly attributable to decreased general and administrative expenses in the current quarter to $788,659 compared to $1,053,070 for the comparative quarter. The most significant decrease was marketing and promotion expenses, which decreased by $380,453 from $469,096 in the third quarter of 2022 to $88,643 in the third quarter of 2023. Nine Months Ended June 30, 2023 and 2022 During the nine months ended June 30, 2023, the Company reported a net loss of $3,330,107 as compared to a net loss of $1,797,785 for the nine months ended June 30, 2022. The increase in net loss for the first three quarters of the current fiscal year compared to the same period in 2022 was mainly attributable to operating expenses increasing to $3,929,106 in the first nine months of the current fiscal year compared to operating expenses of $2,572,367 in the same period in the previous fiscal year, combined with revenue from oil and gas sales and royalty income of $559,599 in the first nine months of the current fiscal years compared to $625,057 in the same period during our 2022 fiscal year. The Company reported oil and gas sales revenue of $541,459 in the first three quarters of the current fiscal year compared with revenue of $577,244 in the same period during the last fiscal year. The decrease was mainly due to the decrease in oil and gas prices in the current period to $72.59/Boe from $88.39/Boe in the comparative period, being partially offset by increased production during first nine months of the Company’s current fiscal year. The production from Breedlove “B” Clearfork properties and Henshaw property increased 10% and 88%, respectively, from the comparative period. Net oil-equivalent production by final product sold in the current period averaged 37.59 barrels per day, compared with 32.49 barrels per day in the same period of the previous fiscal year. The production expenses for the nine months ended June 30, 2023 were $762,668 compared with $332,346 in the nine months ended June 30, 2022. The increase was mostly due to the increase in production in the current fiscal period compared to the same period in the previous fiscal year combined with increased maintenance expenses on the Breedlove and West Henshaw wells. The general and administrative expenses excluding share-based payment expenses for the nine months ended June 30, 2023 were $3,013,987, compared with $1,462,183 in the nine months ended June 30, 2022. The increase was mainly due to the increase in property development and corporate activities in general during in the current fiscal period. Specifically, the variance in the first nine months of the current fiscal year from the same period in the previous fiscal year was mainly attributable to:
Liquidity and Capital Resources As at September 30, 2022, the Company had a cash balance of $3,300,495, an increase of $3,274,689 from the cash balance of $25,806 on September 30, 2021. During the year ended September 30, 2022, cash used in operating activities was $2,024,023. The Company invested $1,685,999 in capital expenditures on its oil and gas assets in fiscal 2022, compared to $265,717 invested in fiscal 2021. Financing activities provided the Company with cash of $6,984,711 mostly as a result of the Company receiving net proceeds of $7,044,472 from private placement financings, being partially offset by the repayment of a loan using $23,600 of cash. The Company had a working capital of $2,051,127 as at September 30, 2022 compared to a working capital deficiency of $465,129 as at September 30, 2021. As at June 30, 2023, the Company had a cash balance of $764,386, a decrease of $2,536,109 from the cash balance of $3,300,495 on September 30, 2022. During the nine months ended June 30, 2023, cash used in operating activities was $1,936,206. The Company invested $1,249,704 in capital expenditures on its oil and gas assets in the first nine months of the current fiscal year, compared to $201,698 invested in the comparative nine months of the previous fiscal year. The Company raised net proceeds of $688,092 from the exercise of warrants and repaid $38,291 of a debenture loan. The Company had a working capital deficiency of $2,501,571 as at June 30, 2023 compared to a working capital of $2,051,127 as at September 30, 2022. Management has currently budgeted approximately $10 million in capital expenditures for the 2024 fiscal year, which the Company plans to finance principally from one or more equity financings and/or a line or credit. The amount and timing of capital expenditures will depend on several factors including, but not limited to, the speed with which we are able to drill and complete our wells, our ability to complete an equity financing or to secure a suitable line of credit, commodity prices, supply/demand considerations and attractive rates of return. There are no guarantees that we will be able to acquire the necessary funds to meet our budgeted capital expenditures, and any postponement of our planned development of our proved undeveloped reserves could materially affect our business, financial condition and results of operations. Although the Company has budgeted investments of additional capital in the continued development of our oil and gas operations, the Company currently does not have any material commitments for capital expenditures. However, the Company does not have sufficient working capital to meet its anticipated operating and capital requirements over the next 12 months from the filing of its Quarterly Report on Form 10-Q for the quarter ended Critical Accounting Estimates The preparation of financial statements in accordance with US GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities at the date of the financial statements and the reported amount of revenue and expenses during the reporting period. Management evaluates these estimates and judgments on an ongoing basis and bases its estimates on experience, current and expected future conditions, third-party evaluations and various other assumptions that management believes are reasonable under the circumstances. Significant estimates have been used by management in conjunction with the following: (i) the fair value of assets when determining the existence of impairment factors and the amount of impairment, if any; (ii) the costs of site restoration when determining decommissioning liabilities; (iii) the useful lives of assets for the purposes of depletion and depreciation; (iv) petroleum and natural gas reserves; and (v) share-based payments. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, and makes adjustments when facts and circumstances dictate. These estimates are based on information available as of the date of the financial statements; therefore, actual results could differ from those estimates.
On We have chosen to Subject to certain conditions set forth in the JOBS Act, as an “emerging growth company,” we BUSINESS Overview
We are an independent energy company engaged in the acquisition, exploration, development and production of oil and natural gas properties on private, state and federal land in the United States, primarily in the Permian Basin region of West Texas and Southeast New Mexico which includes the Midland – Central Basin and Delaware Basin. We focus on acquiring producing assets at a discount to market, increasing production and cash-flow through recompletion and re-entries, secondary recovery and reducing risk by infill drilling and development. Currently, we own and operate various oil and gas properties as well as royalty interests in 73 wells and five permitted wells across 3,800 acres within the Permian Basin. Overall, we own and operate more than 78 oil and gas wells, have more than 11,700 net acres of production oil and gas assets, 62 shut-in opportunities, 17 salt water disposal wells and two water supply wells allowing for waterflood secondary recovery. Business Strategy Oil and Gas Properties The Company hired MKM Engineering, who prepared for the Company the Appraisal Reports. MKM Engineering is independent with respect to Permex Petroleum Corporation as provided in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. MKM Engineering’s estimates of the Company’s proved and probable reserves in each of the Appraisal Reports were prepared according to generally accepted petroleum engineering and evaluation principles, and each of the Appraisal Reports conform to SEC Pricing. The Appraisal Reports are each filed as an exhibit to the registration statement for which this prospectus is a part of. The Appraisal Reports were each specifically prepared by Michele Mudrone, an employee of MKM Engineering, a registered Professional Engineer in the State of Texas, and a member of the Society of Petroleum Engineers. Ms. Mudrone graduated from the Colorado School of Mines with a Bachelor of Science degree in Petroleum Engineering in 1976 and has been employed in the petroleum industry and directly involved in reservoir engineering, petrophysical analysis, reservoir simulation and property evaluation since that time. Ms. Mudrone certified in each Appraisal Report that she did not receive, nor expects to receive, any direct or indirect interest in the holdings discussed in the report or in the securities of the Company. Because the Company’s current size, the Company does not have any technical person at the Company responsible for overseeing the preparation of the reserve estimates presented herein (or have any internal control policies pertaining to estimates of oil and gas reserves), and consequently, the Company relies exclusively on the Appraisal Reports in the preparation of the reserve estimates present in this prospectus. Since all of the Company’s reserves are from conventional reservoirs, MKM Engineering assumed for the purposes of its appraisal reports that the technology to be used to develop the Company’s reserves would include horizontally drilled wells, fracturing, and acidizing. The following tables show a summary of our reserves as of September 30, 2022 and September 30, 2021 which have been derived from the Appraisal Reports and conform to SEC Pricing. Composite Proved Reserve Estimates and Economic Forecasts for the year ended September 30, 2022
Composite Proved Reserve Estimates and Economic Forecasts for the year ended September 30, 2021
Composite Probable Reserve Estimates and Economic Forecasts for the year ended September 30, 2022
Composite Probable Reserve Estimates and Economic Forecasts for the year ended September 30, 2021
Probable reserves are unproven reserves that geologic and engineering analyses suggest are more likely than not to be recoverable. They are not comparable to proved reserves and estimates of oil, condensate, and gas reserves and future net revenue should be regarded only as estimates that may change as further production history and additional information become available. Such reserve and revenue estimates are based on the information currently available, the interpretation of which is subject to uncertainties inherent in applying judgmental factors.
Conversion of Undeveloped Acreage The Company’s process for converting undeveloped acreage to developed acreage is tied to whether there is any drilling being conducted on the acreage in question. The Company has started development and conversion of its undeveloped acreage located in Martin County, Texas. The PPC Eoff #3 well, operated by Permex Petroleum, is the first of two permitted wells to be drilled by the Company on the 7,780 gross acre Breedlove oilfield. Drilling of the first well commenced on September 14, 2022. Management furthermore expects to commence lateral drilling and completion of the well by An aggregate of 5,083 MBO and 2,136 MMCF, of the Company’s proved undeveloped reserves as of September 30, 2022, are part of a development plan that has been adopted by management that calls for these undeveloped reserves to be drilled within the next five years, thus resulting in the conversion of such proved undeveloped reserves to developed status within five years of initial disclosure at September 30, 2022. Management currently anticipates spending approximately $10 million in capital expenditures towards developing the Company’s proved undeveloped reserves during the 2023 fiscal year, subject to the Company acquiring the necessary financing. Proved Undeveloped Reserves Additions From September 30, 2021 to September 30, 2022, the Company had no proved undeveloped reserve additions. The specific changes to the Company’s proved undeveloped reserves from September 30, 2021 to September 30, 2022 were as follows:
Financing of Proved and Probable Undeveloped Reserves The Company currently estimates that the total cost to develop the Company’s proved undeveloped reserves of 5,083.2 MBbl of oil and 2,136.4 Mcf of natural gas as of September 30, 2022 is $68,818,530. The Company expects to finance these capital costs through a combination of current cash on hand, debt financing through a line of credit or similar debt instrument, one or more offerings of debt or equity, and from cash generated from estimated revenues from sales of oil and natural gas produced at the Company’s wells.
The Company currently estimates that the total cost to develop the Company’s probable undeveloped reserves of 7,334.3 MBbl of oil and 10,307.1 Mcf of natural gas as of September 30, 2022 is $107,884,900. The Company expects to finance these capital costs through a combination of joint ventures, farm-in agreements, direct participation programs, one or more offerings of equity, a debt offering or entering into a line of credit, and from cash generated from estimated revenues from sales of oil and natural gas produced at the Company’s wells. Drilling Activities The Company drilled one well during the last three fiscal years. As at September 30, 2022, the Company had 78 gross wells and 14 net productive wells. The Company’s gross developed acreage totaled 5,177 and net developed acreage totaled 3,942 with the following property breakdown:
The Company has 6,000 gross undeveloped acres and 4,800 net undeveloped acres. All of the Company’s undeveloped acreage is on the Company’s Breedlove property. The Company’s leases are held by production in perpetuity. If a field/lease is undeveloped it typically has a 2, 3 or 5 year term of expiry. The Company has over 340 leases covering undeveloped acreage and less than 5% of these leases have an expiry date that is less than two years from the date of this prospectus. Sales and Production The average sales prices of the Company’s oil and gas products sold in the fiscal years ended September 30, 2022, 2021, and 2020 was $89.14/Boe, $54.19/Boe, and $38.51/Boe, respectively. The Company’s net production quantities by final product sold in the fiscal years ended September 30, 2022, 2021, and 2020, was 12,597.45 Boe, 1,182.70 Boe, and 17,772.14 Boe, respectively. The Company’s average production costs per unit for the fiscal years ended September 30, 2022, 2021, and 2020, was $65.82/Boe, and $40.94/Boe, and $32.59/Boe, respectively. The breakdown of production and prices between oil/condensate and natural gas was as follows:
The breakdown of the Company’s production quantities by individual product type for each of the Company’s fields that contain 15% or more of the Company’s total proved reserves expressed on an oil-equivalent-barrels basis was as follows: Breedlove
Henshaw
Pittcock - Mary Bullard
ODC San Andres
Texas Properties Breedlove “B” Clearfork Leases In September 2021, we, through our wholly-owned subsidiary, Permex Pittcock Leases The Pittcock Leases are situated in Stonewall County. Stonewall County is in Northwest Texas, in the central part of the North Central Plains and consists of the Pittcock North property, the Pittcock South property and the Windy Jones Property. It is bounded on the north by King County, on the east by Haskell County, on the south by Fisher and Jones Counties, and on the west by Kent County. The Pittcock North property covers 320 acres held by production. There is currently one producing well, ten shut-in wells, two saltwater disposal wells, and a water supply well. We hold a 100% working interest in the Pittcock North Property and an 81.25% net revenue interest. The Pittcock South property covers 498 acres in four tracts. There are currently 19 shut-in wells and two saltwater disposal wells. We hold a 100% working interest in the lease and a 71.90% net revenue interest. The Windy Jones Property consists of 40 acres and includes two injection wells and two suspended oil wells. The sole purpose of the Windy Jones property is to provide waterflood to the offset wells being the Pittcock wells located east boundary of the Windy Jones Property. We hold a 100% working interest in the Windy Jones Property and a 78.9% net revenue interest. Mary Bullard Property We acquired the Mary Bullard Property in August 2017 for a cash consideration of approximately $50,000. The Mary Bullard Property is located in Stonewall County, about 5 ½ miles south west of Aspermont, Texas. It is bounded on the north by King County, on the east by Haskell County, on the south by Fisher and Jones Counties, and on the west by Kent County. The asset is situated on the Eastern Shelf of the Midland Basin in the central part of the North Central Plains. The Mary Bullard Property covers 241 acres held by production and is productive in the Clearfork formation at a depth of approximately 3,200 feet. There is currently one producing well, four shut-in wells, and two water injection wells. We hold a 100% working interest in the Mary Bullard Property and a 78.625% net revenue interest. New Mexico Properties In December 2017, Permex Petroleum US Corporation, our wholly-owned subsidiary, acquired the West Henshaw Property and the Oxy Yates Property for $170,000 from PPC. An additional $95,000 was transferred by us to PPC to purchase reclamation bonds in connection with the future operation of the properties. West Henshaw Property The West Henshaw Property is located in Eddy County, New Mexico, 12 miles northeast of Loco Hills in the Delaware Basin. Eddy County is in Southeast New Mexico. It is bounded by Chaves County to the north, Otero County to the east, Loving County, Texas to the south, and Lea County to the west. The West Henshaw Property covers 1,880 acres held by production. There are two producing wells, seven shut-in wells and four saltwater disposal wells. We hold a 100% working interest in the West Henshaw Property and a 72% net revenue interest. In January 2022, we began the pilot re-entry on the West Henshaw well #15-3, one out of the 67 shut-in wells we currently owns. The re-entry and re-stimulation involved the West Henshaw property targeting the Grayburg formation at a depth of 2,850 feet. The recompletion was successful and came online at an initial rate of 30 bopd and has stabilized at 15 bopd. In April 2022, we began the re-entry on the West Henshaw well #6-10. The re-entry and re-stimulation involved the West Henshaw property targeting the Grayburg formation at a depth of 2,850 feet. The recompletion was successful and came online at an initial rate of 15 bopd and has stabilized at 10 bopd. The remaining 67 shut-in wells that we plan to re-enter have potential to yield similar results increasing our total daily production solely by re-entering shut-in wells.
Oxy Yates Property The Oxy Yates Property is located in Eddy County, approximately eight miles north of Carlsbad, New Mexico in the Delaware Basin. It is bounded by Chaves County to the north, Otero County to the east, Loving County, Texas to the south, and Lea County to the west. The Oxy Yates Property covers 680 acres held by production. There is one producing well and nine shut-in wells. The Yates formation is located at an average depth of 1,200 feet and overlies the Seven River formation and underlies the Tansill formation. We hold a 100% working interest in the Oxy Yates Property and a 77% net revenue interest.
Royalty Interest Properties During the year ended September 30, 2021,we acquired royalty interests in 73 producing oil and gas wells located in Texas and New Mexico for $179,095. Business Strategy The principal elements of our business strategy include the following:
Industry Operating Environment The oil and natural gas industry is a global market impacted by many factors, such as government regulations, particularly in the areas of taxation, energy, climate change and the environment, political and social developments in the Middle East, demand in Asian and European markets, and the extent to which members of The Organization of Petroleum Exporting Countries and other oil exporting nations manage oil supply through export quotas. Natural gas prices are generally determined by North American supply and demand and are also affected by imports and exports of liquefied natural gas. Weather also has a significant impact on demand for natural gas since it is a primary heating source, and a major fuel for electric generation to power air conditioning. Oil and natural gas prices have been, and we expect may continue to be, volatile. Lower oil and gas prices not only decrease our revenues, but an extended decline in oil or gas prices may affect planned capital expenditures and the oil and natural gas reserves that we can economically produce. While lower commodity prices may reduce our future net cash flow from operations, we expect to have sufficient liquidity to continue development of our oil and gas properties. Development We believe that there is significant value to be created by drilling the identified undeveloped opportunities on our properties in conjunction with the stimulation and rework of our shut-in wells. While our near-term plans are focused towards drilling wells on our existing acreage to develop the potential contained therein, our long-term plans also include continuing to evaluate acquisition and leasing opportunities that can earn attractive rates of return on capital employed.
Competition The oil and natural gas industry is intensely competitive and we compete with numerous other oil and natural gas exploration and production companies, many of which have substantially larger technical teams and greater financial and operational resources than we do and may be able to pay more for exploratory prospects and productive oil and natural gas properties. Many of these companies not only engage in the acquisition, exploration, development, and production of oil and gas reserves, but also have gathering, processing or refining operations, market refined products, provide, dispose of and transport fresh and produced water, own drilling rigs or production equipment, or generate electricity, all of which, individually or in the aggregate, could provide such companies with a competitive advantage. We also compete with other oil and gas companies in securing drilling rigs and other equipment and services necessary for the drilling, completion, and maintenance of wells, as well as for the gathering, transporting, and processing of oil, gas, natural gas liquids, and water. Consequently, we may face shortages, delays, or increased costs in securing these services from time to time. The oil and gas industry also faces competition from alternative fuel sources, including renewable energy sources such as solar and wind-generated energy, and other fossil fuels such as coal. Competitive conditions may also be affected by future energy, environmental, climate-related, financial, or other policies, legislation, and regulations. Our larger or integrated competitors may be better able to absorb the burden of existing, and any changes to federal, state, and local laws and regulations than we can, which would adversely affect our competitive position. Our ability to discover reserves and acquire additional properties in the future is dependent upon our ability and resources to evaluate and select suitable properties and to consummate transactions in this highly competitive environment. Marketing and Customers The market for oil and natural gas that will be produced from our properties depends on many factors, including the extent of domestic production and imports of oil and natural gas, the proximity and availability of capacity and rates and terms of service of pipelines and other transportation and storage facilities, demand for oil and natural gas, the marketing of competitive fuels and the effects of state and federal regulation. The oil and natural gas industry also competes with other industries in supplying the energy and fuel requirements of industrial, commercial and individual consumers. Our oil production is being sold to Energy Transfer Partners and HollyFrontier at prices tied to Argus. Our natural gas production is being sold to DCP Operating Company LP under Henry Hub gas spot prices. For the years ended September 30, 2022 and 2021, we had three and one significant Title to Properties Our oil and natural gas properties are subject to customary royalty and other interests, liens under indebtedness, liens incident to operating agreements, liens for current taxes and other burdens, including other mineral encumbrances and restrictions. We do not believe that any of these burdens materially interfere with the use of our properties or the operation of our business. We believe that we have satisfactory title to or rights in our producing properties. As is customary in the oil and gas industry, minimal investigation of title is made at the time of acquisition of undeveloped properties. In most cases, we investigate title only when we acquire producing properties or before commencement of drilling operations. Seasonality Winter weather conditions and lease stipulations can limit or temporarily halt the drilling and producing activities of our operating partners and other oil and natural gas operations. These constraints and the resulting shortages or high costs could delay or temporarily halt the operations of our operating partners and materially increase our operating and capital costs. Such seasonal anomalies can also pose challenges for meeting well drilling objectives and may increase competition for equipment, supplies and personnel during the spring and summer months, which could lead to shortages and increase costs or delay or temporarily halt our operating partners’ operations. The demand and price for gas frequently increases during winter months and decreases during summer months. To lessen the impact of seasonal gas demand and price fluctuations, pipelines, utilities, local distribution companies, and industrial users regularly utilize gas storage facilities and forward purchase some of their anticipated winter requirements during the summer. However, increased summertime demand for electricity can divert gas that is traditionally placed into storage which, in turn, may increase the typical winter seasonal price. Seasonal anomalies, such as mild winters, or other unexpected impacts, such as the COVID-19 pandemic, sometimes lessen or exacerbate these fluctuations. Principal Agreements Affecting Our Ordinary Business We generally do not own physical real estate, but, instead, our acreage is primarily comprised of leasehold interests subject to the terms and provisions of lease agreements that provide us the right to participate in drilling and maintenance of wells in specific geographic areas. Lease arrangements that comprise our acreage positions are generally established using industry-standard terms that have been established and used in the oil and natural gas industry for many years. Many of our leases are or were acquired from other parties that obtained the original leasehold interest prior to our acquisition of the leasehold interest. In general, our lease agreements stipulate three-to-five year terms. Bonuses and royalty rates are negotiated on a case-by-case basis consistent with industry standard pricing. Once a well is drilled and production established, the leased acreage in the applicable spacing unit is considered developed acreage and is held by production. Other locations within the drilling unit created for a well may also be drilled at any time with no time limit as long as the lease is held by production. Given the current pace of drilling in the areas of our operations, we do not believe lease expiration issues will materially affect our acreage position. Governmental Regulation and Environmental Matters Our operations are subject to various rules, regulations and limitations impacting the oil and natural gas exploration and production industry as whole. Regulation of Oil and Natural Gas Production Our oil and natural gas exploration, production and related operations are subject to extensive rules and regulations promulgated by federal, state, tribal and local authorities and agencies. For example, certain states require permits for drilling operations, drilling bonds and reports concerning operations and impose other requirements relating to the exploration and production of oil and natural gas. Texas and New Mexico also have statutes or regulations addressing conservation matters, including provisions for the unitization or pooling of oil and natural gas properties, and several states regulate the location of wells, the method of drilling and casing wells, the surface use and restoration of properties upon which wells are drilled, the sourcing and disposal of water used in the process of drilling, completion and abandonment, the establishment of maximum rates of production from wells, and the regulation of spacing, plugging and abandonment of such wells. Moreover, the current U.S. federal Administration has indicated that it expects to impose additional federal regulations limiting access to and production from federal lands. The effect of these regulations is to limit the amount of oil and natural gas that registrant can produce from wells and to limit the number of wells or the locations at which drilling can occur. Moreover, many states impose a production or severance tax with respect to the production and sale of oil, natural gas and natural gas liquids within their jurisdictions, and the current federal Administration has proposed increasing royalties payable for production on Federal land. Failure to comply with any such rules and regulations can result in substantial penalties. The regulatory burden on the oil and natural gas industry may increase our cost of doing business and may affect our profitability. Because such rules and regulations are frequently amended or reinterpreted, we are unable to predict the future cost or impact of complying with such laws. Significant expenditures may be required to comply with governmental laws and regulations and may have a material adverse effect on our financial condition and results of operations. Additionally, currently unforeseen environmental incidents may occur or past non-compliance with environmental laws or regulations may be discovered. Therefore, we are unable to predict the future costs or impact of compliance. Additional proposals and proceedings that affect the oil and natural gas industry are regularly considered by Congress, the states, the Federal Energy Regulatory Commission (“FERC”), Pipeline and Hazardous Materials Safety Administration (“PHMSA”), and the courts. We cannot predict when or whether any such proposals may become effective. Regulation of Transportation of Oil Sales of crude oil, condensate and natural gas liquids are not currently regulated and are made at negotiated prices. Nevertheless, Congress could reenact price controls in the future. Our sales of crude oil are affected by the availability, terms and cost of transportation. The transportation of oil by common carrier pipelines is also subject to rate and access regulation. The FERC regulates interstate oil pipeline transportation rates under the Interstate Commerce Act. Interstate oil pipeline rates may be cost-based, although settlement rates agreed to by all shippers are permitted and market-based rates may be permitted in certain circumstances. Effective January 1, 1995, the FERC implemented regulations establishing an indexing system (based on inflation) for transportation rates for oil pipelines that allows a pipeline to increase its rates annually up to a prescribed ceiling, without making a cost of service filing. Every five years, the FERC reviews the appropriateness of the index level in relation to changes in industry costs. On January 20, 2022, the FERC established a new price index for the five-year period which commenced on July 1, 2021. Oil pipelines may also seek market-based rates.
Intrastate oil pipeline transportation rates are subject to regulation by state regulatory commissions. The basis for intrastate oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate oil pipeline rates varies from state to state. Insofar as effective interstate and intrastate rates are equally applicable to all comparable shippers, we believe that the regulation of oil transportation rates will not affect our operations in any way that is of material difference from those of our competitors in the same state who are similarly situated. Further, interstate and intrastate common carrier oil pipelines must provide service on a non-discriminatory basis. Under this open access standard, common carriers must offer service to all similarly situated shippers requesting service on the same terms and under the same rates. When oil pipelines operate at full capacity, access is generally governed by pro-rationing provisions set forth in the pipelines’ published tariffs. Accordingly, we believe that access to oil pipeline transportation services generally will be available to us to the same extent as to our similarly situated competitors. Regulation of Transportation and Sales of Natural Gas Historically, the transportation and sale for resale of natural gas in interstate commerce has been regulated by the FERC under the Natural Gas Act of 1938, the Natural Gas Policy Act of 1978 and regulations issued under those statutes. In the past, the federal government has regulated the prices at which natural gas could be sold. While sales by producers of natural gas can currently be made at market prices, Congress could reenact price controls in the future. Onshore gathering services, which occur upstream of FERC jurisdictional transmission services, are regulated by the states. Although the FERC has set forth a general test for determining whether facilities perform a non-jurisdictional gathering function or a jurisdictional transmission function, the FERC’s determinations as to the classification of facilities is done on a case-by-case basis. State regulation of natural gas gathering facilities generally includes various safety, environmental and, in some circumstances, nondiscriminatory take requirements. Although such regulation has not generally been affirmatively applied by state agencies, natural gas gathering may receive greater regulatory scrutiny in the future. Intrastate natural gas transportation and facilities are also subject to regulation by state regulatory agencies, and certain transportation services provided by intrastate pipelines are also regulated by FERC. The basis for intrastate regulation of natural gas transportation and the degree of state regulatory oversight and scrutiny given to intrastate natural gas pipeline rates and services varies from state to state. Insofar as such regulation within a particular state will generally affect all intrastate natural gas shippers within the state on a comparable basis, we believe that the regulation of similarly situated intrastate natural gas transportation in any state in which we operate and ship natural gas on an intrastate basis will not affect our operations in any way that is of material difference from those of our competitors in that state. Like the regulation of interstate transportation rates, the regulation of intrastate transportation rates affects the marketing of natural gas that we produce, as well as the revenues we receive for sales of our natural gas. Environmental Matters Our operations and properties are subject to extensive and changing federal, state and local laws and regulations relating to environmental protection, including the generation, storage, handling, emission, transportation and discharge of materials into the environment, and relating to safety and health. The recent trend in environmental legislation and regulation generally is toward stricter standards, and this trend will likely continue. These laws and regulations may:
The permits required for our operations may be subject to revocation, modification and renewal by issuing authorities. Governmental authorities have the power to enforce their regulations, and violations are subject to fines or injunctions, or both. In the opinion of management, we are in compliance with current applicable environmental laws and regulations, and have no material commitments for capital expenditures to comply with existing environmental requirements. Nevertheless, changes in existing environmental laws and regulations or in interpretations thereof could have a significant impact on us, as well as the oil and natural gas industry in general. The Comprehensive Environmental, Response, Compensation, and Liability Act (“CERCLA”) and comparable state statutes impose strict, joint and several liability on owners and operators of sites and on persons who disposed of or arranged for the disposal of “hazardous substances” found at such sites. It is not uncommon for the neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment. The Federal Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes govern the disposal of “solid waste” and “hazardous waste” and authorize the imposition of substantial fines and penalties for noncompliance. Although CERCLA currently excludes petroleum from its definition of “hazardous substance,” state laws affecting our operations may impose clean-up liability relating to petroleum and petroleum related products. In addition, although RCRA classifies certain oil field wastes as “non-hazardous,” such exploration and production wastes could be reclassified as hazardous wastes thereby making such wastes subject to more stringent handling and disposal requirements. Recent regulation and litigation that has been brought against others in the industry under RCRA concern liability for earthquakes that were allegedly caused by injection of oil field wastes. The Endangered Species Act (“ESA”) seeks to ensure that activities do not jeopardize endangered or threatened animal, fish and plant species, nor destroy or modify the critical habitat of such species. Under ESA, exploration and production operations, as well as actions by federal agencies, may not significantly impair or jeopardize the species or its habitat. ESA provides for criminal penalties for willful violations of ESA. Other statutes that provide protection to animal and plant species and that may apply to our operations include, but are not necessarily limited to, the Fish and Wildlife Coordination Act, the Fishery Conservation and Management Act, the Migratory Bird Treaty Act and the National Historic Preservation Act. Although we believe that our operations are in compliance with such statutes, any change in these statutes or any reclassification of a species as endangered could subject us (directly or indirectly through our operating partners) to significant expenses to modify our operations or could force discontinuation of certain operations altogether. The Clean Air Act (“CAA”) controls air emissions from oil and natural gas production and natural gas processing operations, among other sources. CAA regulations include New Source Performance Standards (“NSPS”) for the oil and natural gas source category to address emissions of sulfur dioxide and volatile organic compounds (“VOCs”) and a separate set of emission standards to address hazardous air pollutants frequently associated with oil and natural gas production and processing activities. On November 2, 2021, the EPA proposed to revise and add to the NSPS program rules. These rules, if adopted, could have a significant impact on the upstream and midstream oil and gas sectors. The proposed rule would formally reinstate methane emission limitations for existing and modified facilities in the oil and gas sector. Methane is a greenhouse gas. The proposed rules also would regulate, for the first time under the NSPS program, existing oil and gas facilities. Specifically, EPA’s proposed new rule would require states to implement plans that meet or exceed federally established emission reduction guidelines for oil and natural gas facilities. About a year after that proposal, the EPA proposed rules that strengthened and expanded the November, 2021 proposal. The November 2022 EPA statement would require more monitoring of small, high-polluting wells, tracking of “super-emitters”, inspection of abandoned wells until their closure, further reduction in flaring, and use of zero-emissions control equipment on hydrocarbon equipment. Comments regarding the November, 2022 proposal will be presented to the EPA in January, 2023, after which the EPA may act. On August 16, 2022, the IRA was signed into law. The IRA imposes an escalating charge on methane emissions from inter alia onshore petroleum and natural gas production, and natural gas processing, gathering, transmission, underground storage, and LNG storage/ import/export equipment. The charges apply only to facilities emitting 25,000 metric tons of CO2 annually The IRA also funds grants to facilities subject to the methane charge and “marginal conventional wells” to improve equipment and processes. The IRA also creates generous tax credits, benefitting even non-profit entities, that likely will create more supply and demand for alternative non-hydrocarbon energy which may diminish demand, or prices obtained, for natural gas and oil. These statutory provisions will also be subject to legal challenge. The cumulative effect upon our business’ results of the IRA’s grants, charges, and incentives to non-hydrocarbon energy assets and fuels, is uncertain. Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as greenhouse gas cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. At the international level, there exists the United Nations-sponsored Paris Agreement, which is a non-binding agreement for nations to limit their greenhouse gas emissions through individually-determined reduction goals every five years after 2020. While the United States withdrew from the Paris Agreement effective November 4, 2020, President Biden recommitted the United States to the Paris Agreement on January 20, 2021. These regulations and proposals and any other new regulations requiring the installation of more sophisticated pollution control equipment could have a material adverse impact on our business, results of operations and financial condition. The Federal Water Pollution Control Act of 1972, or the Clean Water Act (the “CWA”), imposes restrictions and controls on the discharge of produced waters and other pollutants into waters of the United States (“WOTUS”). Permits must be obtained to discharge pollutants into state and federal waters and to conduct construction activities in waters and wetlands.
The CWA and certain state regulations prohibit the discharge of produced water, sand, drilling fluids, drill cuttings, sediment and certain other substances related to the oil and gas industry into certain coastal and offshore waters without an individual or general National Pollutant Discharge Elimination System discharge permit. In addition, the CWA and analogous state laws require individual permits or coverage under general permits for discharges of storm water runoff from certain types of facilities. CWA jurisdiction depends on the definition of WOTUS. On December 7, 2021, EPA and the Corps of Engineers proposed a rule to revise the definition of WOTUS, that would potentially expand CWA jurisdiction to include more features in areas where oil and gas operations are conducted. Some states also maintain groundwater protection programs that require permits for discharges or operations that may impact groundwater conditions. In 2021, the United States Supreme Court held that the CWA requires a discharge permit if the addition of pollutants through groundwater is the functional equivalent of a direct discharge from the point source into navigable waters. Costs may be associated with the treatment of wastewater and/or developing and implementing storm water pollution prevention plans. The CAA, CWA and comparable state statutes provide for civil, criminal and administrative penalties for unauthorized discharges of oil and other pollutants and impose liability on parties responsible for those discharges, for the costs of cleaning up any environmental damage caused by the release and for natural resource damages resulting from the release. New Mexico implemented in 2021 new standards mandating 98% of natural gas emissions be captured, and a prohibition on natural gas flaring to take effect in 2026. In addition, New Mexico in 2022 implemented restrictions, that are more stringent than federal rules, on emissions of volatile organic compounds and oxides of nitrogen, commonly occurring in connection with production of hydrocarbons. The State of New Mexico characterized the new rules as addressing outsized emissions from smaller, leak-prone wells. The underground injection of oil and natural gas wastes are regulated by the Underground Injection Control program authorized by the Safe Drinking Water Act. The primary objective of injection well operating requirements is to ensure the mechanical integrity of the injection apparatus and to prevent migration of fluids from the injection zone into underground sources of drinking water. Substantially all of the oil and natural gas production in which we have interest is developed from unconventional sources that require hydraulic fracturing as part of the completion process. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into the formation to stimulate gas production. Legislation to amend the Safe Drinking Water Act to repeal the exemption for hydraulic fracturing from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as legislative proposals to require disclosure of the chemical constituents of the fluids used in the fracturing process, were proposed in recent sessions of Congress. The U.S. Congress continues to consider legislation to amend the Safe Drinking Water Act to address hydraulic fracturing operations. Scrutiny of hydraulic fracturing activities continues in other ways. The federal government is currently undertaking several studies of hydraulic fracturing’s potential impacts. Several states have also proposed or adopted legislative or regulatory restrictions on hydraulic fracturing. A number of municipalities in other states have enacted bans on hydraulic fracturing. We cannot predict whether any other legislation will ever be enacted and if so, what its provisions would be. If additional levels of regulation and permits were required through the adoption of new laws and regulations at the federal or state level, it could lead to delays, increased operating costs and process prohibitions that would materially adversely affect our revenue and results of operations. The National Environmental Policy Act (“NEPA”) establishes a national environmental policy and goals for the protection, maintenance and enhancement of the environment and provides a process for implementing these goals within federal agencies. A major federal agency action having the potential to significantly impact the environment requires review under NEPA. In 2021, the Biden Administration proposed a rule to undue changes to NEPA enacted under the Trump Administration that had streamlined NEPA review. The proposed changes would emphasize the need to review federal actions for climate change and environmental justice impacts, among other factors. These proposed changes, if enacted, would affect the assessment of projects ranging from oil and gas leasing to development on public and Indian lands. Climate Change Significant studies and research have been devoted to climate change, and climate change has developed into a major political issue in the United States and globally. Opponents of hydrocarbon production and consumption contend that greenhouse gas emissions contribute to climate change and pose a threat to the environment. Recent scientific research and political debate has focused in part on carbon dioxide and methane incidental to oil and natural gas exploration and production.
In the United States, no comprehensive federal climate change legislation has been implemented to date but the current administration has indicated willingness to pursue new climate change legislation, executive actions, rulemakings or other regulatory initiatives to limit GHG emissions. Interpretation/implementation of existing statutes and common law is evolving. These include rejoining the Paris Agreement treaty on climate change, several executive orders to address climate change, the U.S. Methane Emissions Reduction Action Plan, and a commitment to cut greenhouse gas emissions 50-52 percent of 2005 levels by 2030. Further, legislative and regulatory initiatives are underway to that purpose. The U.S. Congress has considered legislation that would control GHG emissions through a “cap and trade” program and several states have already implemented programs to reduce GHG emissions. The U.S. Supreme Court determined that GHG emissions fall within the CAA definition of an “air pollutant.” Recent litigation has held that if a source was subject to Prevention of Significant Deterioration or Title V based on emissions of conventional pollutants like sulfur dioxide, particulates, nitrogen dioxide, carbon monoxide, ozone or lead, then the EPA could also require the source to control GHG emissions and the source would have to install Best Available Control Technology to do so. As a result, a source may still have to control GHG emissions if it is an otherwise regulated source. The SEC in 2022 proposed rules requiring disclosure of how climate-related risks are likely to materially impact publicly-traded enterprises’ finances, strategies and outlook and the impact of climate-related events upon a company’s consolidated financial statements’ line items. Final action on this proposed rule is pending. Companies must also identify “transition” strategies. Compliance with the proposed rule would increase our costs. In 2014, Colorado was the first state in the nation to adopt rules to control methane emissions from oil and gas facilities. In 2016, the EPA revised and expanded NSPS to include final rules to curb emissions of methane, a greenhouse gas, from new, reconstructed and modified oil and gas sources. Previously, already existing NSPS regulated VOCs, and controlling VOCs also had the effect of controlling methane, because natural gas leaks emit both compounds. However, by explicitly regulating methane as a separate air pollutant, the 2016 regulations were a statutory predicate to propose regulating emissions from existing oil and gas facilities. In September 2020, EPA made technical and policy changes to the methane rules that limited the scope of the rules. In 2021, President Biden issued Executive Order 13990, Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis. In furtherance of this Executive Order, the EPA, on November 2, 2021, proposed rules to regulate methane emissions from the oil and natural gas industry, including, for the first time, reductions from certain upstream and midstream existing oil and gas sources. These regulations also expanded controls to reduce methane emissions, such as enhancement of leak detection and repair provisions. The PHMSA and the Department of Interior continue to focus on regulatory initiatives to control methane emissions from upstream and midstream equipment. To the extent that these regulations or initiatives remain in place and to the extent that our third-party operating partners are required to further control methane emissions, such controls could impact our business. In addition, some of our third-party operating partners are required to report their GHG emissions under CAA rules. Because regulation of GHG emissions continues to evolve, further regulatory, legislative and judicial developments are likely to occur. Such developments may affect how these GHG initiatives will impact us. Moreover, while the U.S. Supreme Court held in its 2011 decision American Electric Power Co. v. Connecticut that, with respect to claims concerning GHG emissions, the federal common law of nuisance was displaced by the CAA, the Court left open the question of whether tort claims against sources of GHG emissions alleging property damage may proceed under state common law. There thus remains litigation risk for such claims. Due to the uncertainties surrounding the regulation of and other risks associated with GHG emissions, we cannot predict the financial impact of related developments on us. The FERC has issued policy statements articulating how it will quantify natural GHG emissions, departing from past practices. Legislation or regulations that may be adopted to address climate change could also affect the markets for our products by making our products more or less desirable than competing sources of energy. To the extent that our products are competing with higher GHG emitting energy sources, our products would become more desirable in the market with more stringent limitations on GHG emissions. To the extent that our products are competing with lower GHG emitting energy sources such as solar and wind, our products would become less desirable in the market with more stringent limitations on GHG emissions. We cannot predict with any certainty at this time how these possibilities may affect our operations.
Depending on the outcome of future carbon emission rulemakings under the CAA targeting new and existing power plants, and demand for hydrocarbons may be reduced. In addition, we anticipate that such regulations will be challenged in federal court prior to their implementation. Depending on the outcome of such judicial review, the hydrocarbon production industry may face alternative efforts from private parties seeking to establish alternative GHG emission limitations from power plants. Alternative GHG emission limitations may arise from litigation under either federal or state common laws or citizen suit provisions of federal environmental statutes that attempt to force federal agency rulemaking or imposing emission limitations. Such lawsuits may also see damages from harm alleged to have resulted from GHG emissions. Physical and Operational Risks. Weather extremes such as drought and high temperature variations are common occurrences in the southwest United States. Large increases in ambient temperatures could require evaluation of certain materials used within its system and may represent a greater challenge. As part of conducting our business, we recognize that the southwestern United States is particularly susceptible to the risks posed by climate change, which over time is projected to exacerbate high temperature extremes and prolong drought in the area. Texas has recently experienced extended droughts. Prolonged and extreme drought conditions can also affect our long-term ability to access water resources. Reductions in the availability of water for injections could negatively impact our financial condition, results of operations or cash flows. Effects of Energy Conservation Measures and Distributed Energy Resources. Some state legislatures and agencies have established rules regarding energy efficiency that mandate energy savings requirements which in turn will impact the demand for electricity. In addition to these rules and requirements, energy efficiency technologies and distributed energy resources continue to evolve, which may have similar impacts on demand for electricity. Reduced demand due to these energy efficiency requirements, distributed energy requirements and other emerging technologies, could have a material adverse impact on the financial condition results of operations and cash flow of our indirect customers. Operational Hazards and Insurance The oil and natural gas business involves a variety of operating risks, including the risk of fire, explosions, well blow-outs, pipe failures, industrial accidents, and, in some cases, abnormally high pressure formations which could lead to environmental hazards such as oil releases, chemical releases, natural gas leaks and the discharge of toxic gases. Any of these risks could adversely affect our ability to conduct operations or result in substantial losses to us, for example, as a result of damage to our property or equipment or injury to our personnel. These operational risks could also result in the spill or release of hazardous materials such as drilling fluids or other chemicals, which may result in pollution, natural resource damages, or other environmental damage and necessitate investigation and remediation costs. As a result, we could be subject to liability under environmental law or common law theories. In addition, these operational risks could result in the suspension or delay of our operations, which could have significant adverse consequences on our business. In accordance with customary industry practices, we maintain insurance against some, but not all, of the operating risks to which our business is exposed. We cannot provide assurance that any insurance we obtain will be adequate to cover our losses or liabilities. Pollution and environmental risks generally are not fully insurable. Under certain circumstances, we may be liable for environmental damage caused by previous owners or operators of properties or repairs/decommissioning of assets that we own, lease or operate. As a result, we may incur substantial liabilities to third parties or governmental entities for environmental matters for which we do not have insurance coverage, which could reduce or eliminate funds available for exploration, development or acquisitions or cause us to incur losses.
The occurrence of an event not fully covered by insurance could have a material adverse effect on our financial position, results of operations and cash flows. Employees As of Facilities Our executive offices are located at 2911 Turtle Creek Blvd, Suite 925, Dallas, Texas 75219 and consists of 2,765 square feet of leased space. We believe our current office space is sufficient to meet our needs and that additional office space can be obtained if necessary. Corporate History We were incorporated on April 24, 2017 under the laws of British Columbia, Canada. At June 30, 2023, we have one wholly-owned subsidiary, Permex Petroleum US Corporation, a corporation incorporated under the laws of New Corporate Information Our principal executive offices are located at 2911 Turtle Creek Blvd, Suite 925, Dallas, Texas 75219 and our website is www.permexpetroleum.com. We do not incorporate the information on our website into this prospectus and you should not consider any such information that can be accessed through our website as part of this prospectus. Directors and Executive Officers Set forth below is the name and position and a brief account of the business experience of each of our directors and executive officers as of
Biographical Information Mehran Ehsan Mehran Ehsan has served as the Chief Executive Officer and President and a member of the Board of Directors of the Company since April 2017. In addition, from July 2010 to June 2019, Mr. Ehsan served as President and Chief Executive Officer of N.A. Energy Resources Corporation, a privately held oil and gas operator. Mr. Ehsan also previously served as the Director of Business Development for West Texas Investment Corp. and a Financial Specialist (Oil and Gas) for Sterling Wealth. Mr. Ehsan received a diploma in marketing management, commercial real estate option from the British Columbia Institute of Technology.
We believe Mr. Ehsan is qualified to serve on our Board of Directors because he brings first-hand knowledge of the Company’s day-to-day operations as well as an understanding of the operational, financial and strategic issues facing our Company. Gregory Montgomery Gregory Montgomery has served as Chief Financial Officer of the Company since May 2022 and served as a member of the Company’s Board of Directors from March 2020 until April 2023. Since June 2021, Mr. Montgomery has served as Vice President, Project Management Office – Private Equity Energy Management of Priority Power Management, LLC. In addition from October 2018 until June 2021, he served as Partner of Vine Advisors, from October 2017 until October 2018, he served as Chief Financial Officer of Oiltanking North America and from March 2013 until October 2017, he served as Chief Financial Officer of Semarus Energy, LLC. Mr. Montgomery also served as Chief Financial Officer for Lion Copolymer, Coast Energy and Laser Midstream, and was a Director of Strategic Planning for Enbridge Energy Partners (EEP: NYSE) and Compliance Officer for Pennzoil Company (PZL: NYSE). Mr. Montgomery is a CPA and member of the Texas Society of CPA’s and American Institute of Certified Public Accountants. Mr. Montgomery holds a Bachelor of Business Administration from the University of Houston – Bauer College of Business. Barry Whelan Barry Whelan has served as the Chief Operating Officer and a member of the Board of Directors of the Company since April 2017. Since May 2017, Mr. Whelan has served as the Chief Operating Officer and a member of the board of directors of N.A. Energy Resources Corporation, a privately held oil and gas operator. Mr. Whelan received his degrees in geology from Western University (London) and McMaster University (Hamilton). He is a past member of the Association of Professional Engineers, Geologists and Geophysicists of Alberta, the Association of Professional Engineers and Geoscientists of British Columbia, the Institute of Geology (London, U.K.) and a Fellow of the Geological Institute of Canada. We believe Mr. Whelan is qualified to serve on our Board of Directors because he brings first-hand knowledge of the Company’s day-to-day operations.
Douglas Charles Urch Douglas Urch has served as a member of the Company’s Board of Directors since November 2018. Since November 2019, Mr. Urch has served as the Executive Vice President and Chief Financial Officer of PetroTal Corp. (OTCQX: PTALF; TSXV: TAL; AIM PTAL), and from December 2017 until October 2019, he served as chair of the board of directors. In addition, from February 2008 until September 2018, Mr. Urch served as Executive Vice President, Finance and Chief Financial Officer of Bankers Petroleum Ltd. Moreover, since April 2017, Mr. Urch has served as a member of the board of directors of Blue Moon Metals Corp. (TSXV: MOON). Mr. Urch is a Chartered Professional Accountant (CPA) and a member of the Institute of Corporate Directors (ICD). He received a Bachelor of Commerce degree (with a major in accounting) from the University of Calgary in 1980.
We believe Mr. Urch is qualified to serve on our Board of Directors because he brings extensive financial and accounting experience in the oil and gas industry. James Perry Bryan James Bryan has served as a member of the Company’s Board of Directors since September 2021. From October 2020 to August 2021, Mr. Lendrum served on the board of directors of Good Work Acquisition Corp., a special purpose acquisition company. Mr. Bryan has been involved in the energy and investment industries for more than five decades, serving as Chief Executive Officer and President of Gulf Canada Resources Limited (1995 - 1998), Chairman (1990 - 1997) and Chief Executive Officer of Nuevo Energy Company (1990 - 1995), Chief Executive Officer of Bellwether Exploration (1987 - 1997), First Vice President of E.F. Hutton & Company and Director of Investment Banking-Southwest Region (1978 - 1981), Chairman and Chief Executive Officer of Torch Energy Advisors, Inc. (1981 - 2012), President and Chief Executive Officer of The Mortgage Banque (1974 - 1978), Executive Vice President and Director of Dominick & Dominick, Inc. (1969 - 1974), and Vice President of Morgan Guaranty Trust Company (1966 - 1969). He received his B.A. from The University of Texas at Austin, his L.L.B. from The University of Texas Law School at Austin and his B.F.T. from the American Institute of Foreign Trade at Phoenix, Arizona. Among his numerous business awards are Texas Entrepreneur of the Year (1994) and Canadian Oil Producer of the Year (1995). We believe Mr. Bryan is qualified to serve on our Board of Directors because he brings extensive experience in the oil and gas industry. John James Lendrum John Lendrum has served as a member of the Company’s Board of Directors since September 2021. Since 2015, Mr. Lendrum has served as the Non-Executive Chairman of Nuevo Midstream Dos, LLC. From 2012 to 2014, he served as the President, Chief Executive Officer and member of the board of directors of Nuevo Midstream Company (“Nuevo”). Nuevo owned and operated gas gathering, processing and treating assets in the Delaware and Permian Basins of West Texas and New Mexico and was sold to an affiliate of Anadarko Petroleum Company in 2014. Since February 2019, Mr. Lendrum serves on the board of Blue Rock Energy Partners. In 2018, he participated along with several other family offices, in the acquisition of Blue Rock from the private equity unit of TudorPickeringHolt. Mr. Lendrum has a B.B.A. in Finance and completed his graduate studies in Accounting Theory at The University of Texas at Austin. We believe Mr. Lendrum is qualified to serve on our Board of Directors because he brings extensive experience in the oil and gas industry. Melissa Folz Melissa Folz has served as a director of the Company’s Board of Directors since October 2022. Ms. Folz is currently the Director of Production Engineering and Optimization at Chord Energy, which is a result of the merger of Oasis Petroleum and Whiting Petroleum effective July 2022. Ms. Folz has been a leader at Oasis Petroleum since 2014 in various production, reservoir, and subsurface assessment management positions. Prior to joining Oasis she worked at Sabine Oil and Gas as a production engineer and Southwestern Energy as a completions engineer. Ms. Folz has over 15 years of experience in oil and gas, graduated as a petroleum engineer from Louisiana State University, and is a licensed professional engineer in the state of Texas. We believe Ms. Folz is qualified to serve on our Board of Directors because she brings extensive experience in the oil and gas industry. Family Relationships There are no family relationships among any of our executive officers or directors. Involvement in Certain Legal Proceedings We are not aware of any of our directors or officers being involved in any legal proceedings in the past ten years relating to any matters in bankruptcy, insolvency, criminal proceedings (other than traffic and other minor offenses), or being subject to any of the items set forth under Item 401(f) of Regulation S-K under the Securities Act. Arrangements between Officers and Directors Except as set forth herein, to our knowledge, there is no arrangement or understanding between any of our officers or directors and any other person pursuant to which the officer or director was selected to serve as an officer or director.
Independence We have determined Douglas Charles Urch, John James Lendrum, James Perry Bryan and Melissa Folz to be “independent” directors within the meaning of the listing standards of the Committees of our Board of Directors Our Board of Directors has a separately designated standing audit committee. Our Board serves in place of a compensation committee, determining the compensation of our officers and directors, and nominating and corporate governance committee, nominating members to our Board of Directors. The functions of a compensation committee and nominating committee are performed exclusively by the independent directors on the Board, meeting separately, and determinations are made by a majority of such independent directors. In lieu of a charter for the compensation committee or Board has adopted resolutions specifying (i) the scope of the compensation committee’s responsibilities, and how it carries out those responsibilities, including structure, processes and membership requirements; (ii) the compensation committee’s responsibility for determining, or recommending to the board for determination, the compensation of the chief executive officer and all other executive officers of the Company; and (iii) that the chief executive officer may not be present during voting or deliberations on his or her compensation. In lieu of a charter for the nominating committee, our Board has adopted resolutions addressing the nominations process and certain other matters related to corporate governance. Audit Committee Our audit committee consists of Douglas Charles Urch (Chair), James Perry Bryan and John James Lendrum. Our Board of Directors has determined that each of Douglas Charles Urch, James Perry Bryan and John James Lendrum meet the definition as an “independent” director within the meaning of the listing standards of the Our audit committee is responsible for overseeing our financial reporting process on behalf of the Board, including overseeing the work of the independent auditors who report directly to the audit committee. The specific responsibilities of our audit committee, among others, include:
Committee Charters and Other Corporate Governance Matters Audit Committee Charter Our Board of Directors has adopted a written charter for our audit committee. Code of Business Conduct and Ethics We have adopted a written Code of Business Conduct and Ethics which addresses issues including, but not limited to: (i) conflicts of interest; (ii) compliance with laws, rules, and regulations; (iii) protection and proper use of corporate opportunities; (iv) protection and proper use of corporate assets; (v)confidentiality of corporate information; (vi) fair dealing with securityholders, customers, competitors, and employees; and (vii) accuracy of business records. The Code of Business Conduct and Ethics applies to all of our directors, officers and employees. Any change or waivers from the provisions of the Code of Business Conduct and Ethics for our executive officers or directors will be made only after approval by the Board of Directors and will be promptly disclosed.
Director Compensation We have no formal policy concerning director compensation; however, options may be granted to directors as compensation for services on the Board, at the discretion of our Board. To date, the we have not paid any cash compensation to our directors for service on the Board. The following table presents the total compensation for each person who served as a member of our Board of Directors (other than Mehran Ehsan, our Chief Executive Officer, whose compensation is summarized below under “Summary Compensation Table”) and received compensation for such service on the Board during the fiscal year ended September 30, 2022.
(1) Scott Kelly served as Chief Financial Officer and Corporate Secretary of the Company until May 2022. In connection with his service as our Chief Financial Officer, Mr. Kelly received cash compensation of $9,360 during the fiscal year ended September 30, 2022. Mr. Kelly resigned from the Board on September 12, 2023. (2) Edward Odishaw served as a director of the Company until May 2, 2022. (3) Gregory Montgomery was appointed as our Chief Financial Officer on May 1, 2022. Pursuant to his employment agreement with the Company, Mr. Montgomery will receive an annual base salary of $50,000 and be eligible to receive an annual cash bonus of up to 100% of this annual salary. Mr. Montgomery received cash compensation of $20,833 during the fiscal year ended September 30, 2022 in connection with his service as our Chief Financial Officer. On April 24, 2023, Mr. Montgomery resigned as a director of the Company. (4) Barry Whelan also serves as our Chief Operating Officer.
For the purposes hereof, a named executive officer (“NEO”) of the Company means the Company’s Chief Executive Officer, Mehran Ehsan, as no other executive officer of the Company received total compensation in Summary Compensation Table The following table sets forth, for the years ended September 30,
Outstanding Equity Awards at Fiscal Year-End The following table provides information regarding option and restricted stock unit awards held by our that were outstanding as of September 30,
(1) Stock options granted to Mehran Ehsan in December 2017 vested immediately upon grant. (2) Stock options granted to Mehran Ehsan in October 2021 vested immediately upon grant.
Stock Option Plans and Other Incentive Plan Other than the Option Plan set forth below, the Company currently does not have any other stock option plan, stock option agreement made outside of a stock option plan, plan providing for the grant of stock appreciation rights, deferred share units or restricted stock units or any other incentive plan or portion of a plan under which awards are granted. The Company’s current stock option plan (the “Option Plan”) was approved by the Board on November 27, 2017 and by the Company’s shareholders on April The Option Plan will be administered by the Board or the compensation committee of the Company, as applicable, which shall, without limitation, have full and final authority in its discretion, but subject to the express provisions of the Option Plan, to interpret the Option Plan, to prescribe, amend and rescind rules and regulations relating to it and to make all other determinations deemed necessary or advisable for the administration of the Option Plan, subject to any necessary shareholder or regulatory approval. The Board may delegate any or all of its authority with respect to the administration of the Option Plan. The Board shall determine to whom options shall be granted, the terms and provisions of the respective option agreements, the time or times at which such options shall be granted and vested, and the number of Under the Option Plan, options will be exercisable over periods of up to ten years as determined by the Board. The exercise price of any option may not be less than the greater of the closing market price of the The maximum number of
The Option Plan permits the Board to specify a vesting schedule in its discretion, subject to minimum vesting requirements imposed by the applicable stock exchange. Unless otherwise specified by the Board at the time of granting an option, and subject to the other limits on option grants set out in the Option Plan, all options granted under the Option Plan shall vest and become exercisable in full upon grant, except Options granted to consultants performing investor relations activities, which options must vest in stages over twelve months with no more than one-quarter of the options vesting in any three month period. The Option Plan provides that if a change of control (as defined in the Option Plan) occurs, or if the Company is subject to a take-over bid, all The Option Plan contains adjustment provisions with respect to outstanding options in cases of share reorganizations, special distributions and other corporation reorganizations including an arrangement or other transaction under which the business or assets of the Company become, collectively, the business and assets of two or more companies with the same shareholder group upon the distribution to the Company’s shareholders, or the exchange with the Company’s shareholders, of securities of the Company or securities of another company.
The Option Plan provides that on the death or disability of an option holder, all vested options will expire at the earlier of 365 days after the date of death or disability and the expiry date of such options. Where an Optionee is terminated for cause, any outstanding options (whether vested or unvested) are cancelled as of the date of termination. If an Optionee retires or voluntarily resigns or is otherwise terminated by the Company other than for cause, then all vested options held by such Optionee will expire at the earlier of (i) the expiry date of such options and (ii) the date which is 90 days (30 days if the Optionee was engaged in investor relations activities) after the Optionee ceases its office, employment or engagement with the Company. The Option Plan contains a provision that if pursuant to the operation of an adjustment provision of the Option Plan, an Optionee receives options (the “New Options”) to purchase securities of another company (the “New Company”) in respect of the Optionee’s options under the Option Plan (the “Subject Options”), the New Options shall expire on the earlier of: (i) the expiry date of the Subject Options; (ii) if the Optionee does not become an eligible person in respect of the New Company, the date that the Subject Options expire pursuant to the applicable provisions of the Option Plan relating to expiration of options in cases of death, disability or termination of employment discussed in the preceding paragraph above (the “Termination Provisions”); (iii) if the Optionee becomes an eligible person in respect of the New Company, the date that the New Options expire pursuant to the terms of the New Company’s stock option plan that correspond to the Termination Provisions; and (iv) the date that is one year after the Optionee ceases to be an eligible person in respect of the New Company or such shorter period as determined by the Board. In accordance with good corporate governance practices and as recommended by National Policy 51-201 – Disclosure Standards, the Company imposes black-out periods restricting the trading of its securities by directors, officers, employees and consultants during periods surrounding the release of annual and interim financial statements and at other times when deemed necessary by management and the Board. In order to ensure that holders of outstanding options are not prejudiced by the imposition of such black-out periods, the Option Plan contains a provision to the effect that any outstanding options with an expiry date occurring during a management imposed black-out period or within five trading days thereafter will be automatically extended to a date that is 10 trading days following the end of the black-out period. The options granted under the Option Plan are non-assignable and non-transferable. Subject to required shareholder approval and the approval of the CSE, or any other stock exchange on which the The Company does not provide any financial assistance to participants in order to facilitate the purchase of A copy of the Option Plan may be inspected at the head office of the Company, 2911 Turtle Creek Blvd, Suite 925, Dallas, Texas 75219, during normal business hours. In addition, a copy of the Option Plan will be mailed, free of charge, to any shareholder who requests a copy, in writing, from the Chief Financial Officer of the Company. Any such requests should be mailed to the Company, at its head office, to the attention of the Chief Financial Officer. Employment, Consulting and Management Agreements Other than the executive employment agreement between the Company and Mehran Ehsan, the material terms of which are set forth below, the Company does not have any compensation agreements or arrangements that the Company or any of its subsidiaries have entered into with respect to services provided by a NEO, a director or any other party in the event such services provided are typically provided by a director or NEO (collectively, “Compensation Arrangements”). The Compensation Arrangements for Mehran Ehsan were initially set forth in the amended employment agreement dated September 1, 2021, as subsequently amended on May 1, 2022, between the Company and Mr. Ehsan (the “CEO Employment Agreement”). Pursuant to the CEO Employment Agreement, the Company employs Mr. Ehsan to serve as CEO of the Company and to perform such duties and have such authority as may from time to time be assigned by the Board. As compensation for the performance of such duties, the Company paid Mr. Ehsan a base salary of $200,000 per year (which increased to $250,000 as of May 1, 2022), which shall be reviewed by the Company annually. Mr. Ehsan is also eligible for cash bonuses and grants of Options under the Option Plan, in the sole discretion of the Board, as well as group health, medical and disability insurance benefits and any other fringe benefit programs that the Company maintains from time to time for the benefit of its employees.
The Company may immediately terminate Mr. Ehsan’s employment at any time for cause, by written notice. The Company may terminate the Mr. Ehsan’s employment at any time without cause by providing him with notice in writing and compensation in lieu of notice as follows:
Mr. Ehsan is required to give the Company not less than two weeks’ notice in the event of his resignation. Upon receipt of his notice of resignation, or at any time thereafter, the Company has the right to elect to pay, in lieu of such notice period, Mr. Ehsan’s salary for the remainder of the notice period and a reasonable amount in lieu of the his benefits for that period. If the Company elects for payment in lieu of notice, the Mr. Ehsan’s employment shall terminate immediately upon such payment. If the Company determines that Mr. Ehsan has suffered a Disability (as defined below) that cannot be accommodated, the Company may terminate his employment by notice. In such case, Mr. Ehsan is entitled to receive, in lieu of all amounts otherwise payable under the CEO Employment Agreement (except for amounts earned but not yet paid to Mr. Ehsan through the date of such Disability), compensation at Mr. Ehsan’s base salary rate for a period of six months following the date of Disability or such greater amount as is required by applicable law. In the CEO Employment Agreement, “Disability” means a physical or mental incapacity of Mr. Ehsan that has prevented him from performing the duties customarily assigned to him for 180 days, whether or not consecutive, out of any 12 consecutive months and that in the opinion of the Company, acting on the basis of advice from a duly qualified medical practitioner, is likely to continue to a similar degree. In the event of death, Mr. Ehsan’s employment shall be deemed to have terminated on the date thereof and the Company shall pay his estate the amounts specified above in respect of termination without cause. Other than pursuant to the CEO Employment Agreement, the Company has not granted any termination or change of control benefits with respect to any Compensation Arrangement and there are no compensatory plans or arrangements with respect to any NEO or director resulting from the resignation, retirement or any other termination of any NEO or director or from a change of any NEO’s or director’s responsibilities following a change of control. In case of termination of NEOs, other than the CEO, common law and statutory law applies. The table below sets forth information with respect to each NEO currently employed by the Company in order to assist the reader in determining the potential payment to each such NEO in the event of the termination of such NEO’s employment by the Company other than for cause or in the event of a change of control. The estimated payments have been calculated on the basis of employment agreements as they exist at the date of this prospectus and assuming that they were in effect on September 30, 2022.
The estimated payments assuming a change of control on September 30,
Oversight and Description of Director and Name Executive Officer Compensation Elements of Compensation Compensation to be awarded or paid to the Company’s directors and/or executive officers, including NEOs consist primarily of management fees, stock options and bonuses. Payments may be made from time to time to executive officers, including NEOs, or companies they control for the provision of consulting or management services. Such services are paid for by the Company at competitive industry rates for work of a similar nature done by reputable arm’s length services providers. The Board will from time to time determine the stock option grants to be made pursuant to the Option Plan. It is also anticipated that the Board may award bonuses, in its sole discretion, to executive officers (including NEOs) from time to time. The most significant components of the Company’s executive compensation plan are base salary and an annual incentive bonus. These components are based upon:
Base Salary The base salary review of any NEO will take into consideration the current competitive market conditions, experience, proven or expected performance, and the particular skills of the NEO. Base salary is not expected to be evaluated against a formal “peer group”. The base salaries for NEOs during the fiscal year ended September 30,
Performance-Based Cash Bonuses Cash bonuses are not a normal part of the Company’s executive compensation. However, the Company may elect to utilize such incentives where the role-related context and competitive environment suggest that such a compensation modality is appropriate. When and if utilized, the amount of cash bonus compensation will normally be paid on the basis of timely achievement of specific pre-agreed milestones. Each milestone will be selected based upon consideration of its impact on shareholder value creation and the ability of the Company to achieve the milestone during a specific interval. The amount of bonus compensation will be determined based upon achievement of the milestone, its importance to the Company’s near and long term goals at the time such bonus is being considered, the bonus compensation awarded to similarly situated executives in similarly situated companies or any other factors the Company may consider appropriate at the time such performance-based bonuses are decided upon.
Stock Options The Company currently has the Option Plan in place for the purposes of attracting and motivating directors, officers, employees, and consultants of the Company and advancing the interests of the Company by affording such persons with the opportunity to acquire an equity interest in the Company through rights granted under the Option Plan. Any grant of options under the Option Plan is within the discretion of the Board, subject to the condition that the maximum number of Options are also an important component of aligning the objectives of the Company’s employees with those of shareholders. The Company expects to provide significant option positions to senior employees and lesser amounts to lower-level employees. Notwithstanding the above, the Company is still in the development stage and has an informal compensation program and strategy. The management team is committed to developing the operations of the Company and will establish a formal compensation program for directors and executive officers once it begins generating revenues sufficient to sustain operations. The Board is responsible for determining, by way of discussions at Board meetings, the ultimate compensation to be paid to the executive officers of the Company. The Company does not have a formal compensation program with set benchmarks; however, the performance of each executive will be considered along with the Company’s ability to pay compensation and its results of operation for the period. The Company relies solely on its Board to determine the executive compensation that is to be paid to NEOs and directors without any formal objectives, criteria, or analysis. Pension Disclosure The Company does not currently provide any pension plan benefits for executive officers, directors, or employees. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT The following table sets forth certain information regarding the beneficial ownership of our capital stock outstanding as of
The percentage ownership information prior to the offering is based on Except as otherwise noted below, the address for each person or entity listed in the table is c/o Permex Petroleum Corporation, 2911 Turtle Creek Blvd., Suite 925, Dallas, Texas 75219.
* less than 1%. (1) Represents (i) (2) Represents (i) (3) Represents (i) (4) Represents (i)
(10) Represents (i) 52,083 Common Shares and (ii) 30,451 Common Shares issuable upon exercise of warrants.
(11) John Lendrum has the right to vote and dispose of the securities held by Petro Americas Resources, LLC.
(12) James Bryan has the right to vote and dispose of the securities held by Pratt Oil and Gas, LLC.
CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS The following includes a summary of transactions during the Company’s last two fiscal years to which we have been a party, including transactions in which the amount involved in the transaction exceeds the lesser of $120,000 or 1% of the average of our total assets at year-end for the last two completed fiscal years and in which any of our directors, executive officers or, to our knowledge, beneficial owners of more than 5% of our capital stock or any member of the immediate family of any of the foregoing persons had or will have a direct or indirect material interest, other than equity and other compensation, termination, change in control and other arrangements which are described elsewhere in this prospectus. We are not otherwise a party to a current related party transaction and no transaction is currently proposed, in which the amount of the transaction exceeds the lesser of $120,000 or 1% of the average of our total assets at year-end for the last two completed fiscal years and in which a related person had or will have a direct or indirect material interest. Transactions with Related Parties In October 2019, the Company issued $76,000 (CAD$100,000) in convertible debenture to a director of the Company for cash. The debenture loan was secured by an interest in all of the Company’s right, title, and interest in all of its oil and gas assets, bore interest at a rate of 12% per annum and had a maturity date of September 30, 2021. During the year ended September 30, 2021, the Company repaid the principal loan amount of CAD$100,000 together with accrued interest of $13,090. During the year ended September 30, 2021, the Company recorded interest of $4,026. In February 2020, the Company issued $76,000 The Company has an employment with the CEO of the Company for an annual base salary of $250,000, with no specified term. The CEO is also eligible on an annual basis for a cash bonus of up to 100% of annual salary. The employment agreement may be terminated with a termination payment equal to three years of base salary and a bonus equal to 20% of the annual base salary. During the years ended September 30, 2022 and September 30, 2021, the Company incurred management fees of $220,834 and $149,806, respectively, to the CEO of the Company. The Company considers this a related party transaction, as it relates to key management personnel and entities over which it has control or significant influence. On May 1, 2022, the Company entered into an employment with the CFO of the Company for an annual base salary of $50,000, with no specified term. The CFO is also eligible on an annual basis for a cash bonus of up to 100% of annual salary. The employment agreement may be terminated with a termination payment equal to two months of base salary. During the years ended September 30, 2022, the Company incurred salaries of $20,835 to the CFO of the Company. The Company considers this a related party transaction, as it relates to key management personnel and entities over which it has control or significant influence. The following description of our share capital summarizes certain provisions of our Articles. The summary does not purport to be complete and is subject to, and is qualified in its entirety by reference to, all of the provisions of our Articles, a copy of which has been filed as an exhibit to the registration statement of which this prospectus forms a part. Prospective investors are urged to read the exhibits to the registration statement of which this prospectus forms a part for a complete understanding of our Articles. Common Units Each Common Unit being offered in this offering consists of one Common Share and one Warrant, each Warrant exercisable for one Common Share. The Common Shares and Warrants that are part of the Common Units are immediately separable and will be issued separately in this offering, although they will have been purchased together in this offering. Pre-funded Units Each Pre-funded Unit being offered in this offering consists of one Pre-funded Warrant and one Warrant, each Pre-funded Warrant and Warrant is exercisable for one Common Share. The Pre-funded Warrants and Warrants that are part of the Pre-funded Units are immediately separable and will be issued separately in this offering, although they will have been purchased together in this offering. Authorized/Issued Capital Our authorized share capital consists of an unlimited number of Common Shares Each Options Our Option Plan provides for us to issue ��
Warrants As of Warrants to be Issued in this Offering The following is a brief summary of certain terms and conditions of the Warrants to be issued in this offering and are subject in all respects to the provisions contained in the Warrants. Form. The Warrants will be issued in electronic book-entry form to the investors. You should review a copy of the form of warrant, which is filed as an exhibit to the registration statement of which this Prospectus forms a part, for a complete description of the terms and conditions applicable to the Warrants. Exercisability. The Warrants are exercisable at any time after their original issuance, and at any time up to the date that is five years after their original issuance. The Warrants will be exercisable, at the option of each holder, in whole or in part by delivering to us a duly executed exercise notice and, at any time a registration statement registering the issuance of the Common Shares underlying the Warrants under the Securities Act is effective and available for the issuance of such shares, by payment in full in immediately available funds for the number of Common Shares purchased upon such exercise. If a registration statement registering the issuance of the Common Shares underlying the Warrants under the Securities Act is not effective or available, the holder may, in its sole discretion, elect to exercise the Warrant through a cashless exercise, in which case the holder would receive upon such exercise the net number of Common Shares determined according to the formula set forth in the Warrant. No fractional Common Shares will be issued in connection with the exercise of a Warrant. In lieu of fractional shares, we will pay the holder an amount in cash equal to the fractional amount multiplied by the exercise price or round up to the next whole share. Exercise Limitation. A holder will not have the right to exercise any portion of the Warrant if the holder (together with its affiliates) would beneficially own in excess of 4.99% (or, at the election of the holder prior to issuance, 9.99%) of the number of Common Shares outstanding immediately after giving effect to the exercise, as such percentage ownership is determined in accordance with the terms of the Warrants. However, any holder may increase or decrease such percentage to any other percentage not in excess of 9.99% upon at least 61 days’ prior notice from the holder to us. Exercise Price. The exercise price per whole Common Share purchasable upon exercise of the Warrants is expected to be $ per Common Share. The exercise price is also subject to appropriate adjustment in the event of certain stock dividends and distributions, stock splits, stock combinations, reclassifications or similar events affecting our Common Shares and also upon any distributions of assets, including cash, stock or other property to our shareholders. Cashless Exercise. If at the time of exercise hereof there is no effective registration statement registering, or the prospectus contained therein is not available for the issuance of the Common Shares to the holder upon exercise of the Warrants, in lieu of making the cash payment otherwise contemplated to be made to us upon such exercise in payment of the aggregate exercise price, the holder may elect instead to receive upon such exercise (either in whole or in part) the net number of Common Shares determined according to a formula set forth in the Warrants. Transferability. Subject to applicable laws, the Warrants may be offered for sale, sold, transferred or assigned without our consent. Exchange Listing. We have applied for the listing of the Warrants offered in this offering on The Nasdaq Capital Marketunder the symbol “OILSW”. No assurance can be given that such listing will be approved or that a trading market will develop. It is a condition precedent to the underwriter’s obligation to purchase the securities being offered in our offering that Nasdaq approve the listing of our Common Shares and Warrants. Accordingly, if Nasdaq does not approve the listing of our Common Shares and Warrants, we will not and cannot proceed with this offering. Fundamental Transactions. In the event of a fundamental transaction, as described in the Warrants and generally including any reorganization, recapitalization or reclassification of our Common Shares, the sale, transfer or other disposition of all or substantially all of our properties or assets, our consolidation or merger with or into another person, the acquisition of more than 50% of our outstanding Common Shares, or any person or group becoming the beneficial owner of 50% of the voting power represented by our outstanding Common Shares, the holders of the Warrants will be entitled to receive upon exercise of the Warrants the kind and amount of securities, cash or other property that the holders would have received had they exercised the Warrants immediately prior to such fundamental transaction.
Rights as a Stockholder. Except as otherwise provided in the Warrants or by virtue of such holder’s ownership of shares of our Common Shares, the holder of a Warrant does not have the rights or privileges of a holder of our Common Shares, including any voting rights, until the holder exercises the Warrant. Pre-funded Warrants The following summary of certain terms and provisions of the Pre-funded Warrants that are being offered hereby in lieu of a Common Share is not complete and is subject to, and qualified in its entirety by, the provisions of the Pre-funded Warrant, the form of which is filed as an exhibit to the registration statement of which this prospectus forms a part. Prospective investors should carefully review the terms and provisions of the form of Pre-funded Warrant for a complete description of the terms and conditions of the Pre-funded Warrants. Duration and Exercise Price. Each Pre-funded Warrant offered hereby will have an initial exercise price per share equal to $0.01. The Pre-funded Warrants will be immediately exercisable and may be exercised at any time until the Pre-funded Warrants are exercised in full or they expire. The exercise price and number of Common Shares issuable upon exercise is subject to appropriate adjustment in the event of stock dividends, stock splits, reorganizations or similar events affecting our Common Shares and the exercise price. Exercisability. The Pre-funded Warrants will be exercisable, at the option of each holder, in whole or in part, by delivering to us a duly executed exercise notice accompanied by payment in full for the number of Common Shares purchased upon such exercise (except in the case of a cashless exercise as discussed below). There is no expiration date for the Pre-funded Warrants. A holder (together with its affiliates) may not exercise any portion of the Pre-funded Warrant to the extent that the holder would own more than 4.99% (or at the election of the holder prior to the issuance of any Pre-funded Warrants, 9.99%) of the outstanding Common Shares immediately after exercise. Any holder may increase such percentage to any percentage not in excess of 9.99% upon at least 61 days’ prior notice to us. No fractional Common Shares will be issued in connection with the exercise of a Pre-funded Warrant. In lieu of fractional Common Shares, we will pay the holder an amount in cash equal to the fractional amount multiplied by the exercise price of such Pre-funded Warrant or round up to the next whole share. Cashless Exercise. In lieu of making the cash payment otherwise contemplated to be made to us upon such exercise in payment of the aggregate exercise price, the holder may elect instead to receive upon such exercise (either in whole or in part) the net number of Common Shares determined according to a formula set forth in the Pre-funded Warrants. Fundamental Transaction. In the event of a fundamental transaction, as described in the Pre-funded Warrants and generally including any reorganization, recapitalization or reclassification of our Common Shares, the sale, transfer or other disposition of all or substantially all of our properties or assets, our consolidation or merger with or into another person, the acquisition of more than 50% of our outstanding Common Shares, or any person or group becoming the beneficial owner of 50% of the voting power represented by our outstanding Common Shares, the holders of the Pre-funded Warrants will be entitled to receive upon exercise of the Pre-funded Warrants the kind and amount of securities, cash or other property that the holders would have received had they exercised the Pre-funded Warrants immediately prior to such fundamental transaction. Transferability. Subject to applicable laws, a Pre-funded Warrant may be transferred at the option of the holder upon surrender of the Pre-funded Warrant to us together with the appropriate instruments of transfer. Exchange Listing. We do not intend to list the Pre-funded Warrants on any securities exchange or nationally recognized trading system. Rights as a Shareholder. Except as otherwise provided in the Pre-funded Warrants or by virtue of such holder’s ownership of Common Shares, the holders of the Pre-funded Warrants do not have the rights or privileges of holders of our Common Shares, including any voting rights, until they exercise their Pre-funded Warrants.
Transfer Agent and Registrar Our transfer agent and registrar is TSX Trust Company whose address is 650 West Georgia Street, Suite 2700, Vancouver, British Columbia, Canada, V6B 4N9. TSX Trust Company maintains our registered list of shareholders. Listing Our We have applied to list our Common Shares and Warrants on The Nasdaq Capital Market under the symbol “OILS” and “OILSW,” respectively; however, no assurance can be given that our Common Shares and Warrants will be approved for listing on The Nasdaq Capital Market. Shareholder Meetings We must hold a general meeting of our shareholders at least once in each calendar year and not more than 15 months after the preceding annual general meeting at such time and place as may be determined by the directors. If all shareholders who are entitled to vote at an annual general meeting consent by a unanimous resolution to all of the business that is required to be transacted at that annual general meeting, the annual general meeting is deemed to have been held on that date of the unanimous resolution. The location for a meeting of shareholders shall be determined by the directors and may be within or outside of the Province of British Columbia, Canada. The Company must send notice of the date, time and location of any meeting of shareholders (including, without limitation, any notice specifying the intention to propose a resolution as an exceptional resolution, a special resolution or a special separate resolution, and any notice to consider approving an amalgamation into a foreign jurisdiction, an arrangement or the adoption of an amalgamation agreement, and any notice of a general meeting, class meeting or series meeting), in the manner provided in the Company’s Articles, or in such other manner, if any, as may be prescribed by ordinary resolution (whether previous notice of the resolution has been given or not), to each shareholder entitled to attend the meeting, to each director and to the auditor of the Company, unless the Articles of the Company otherwise provide, at least 21 days before the meeting if and for so long as the Company is a public company. Limitations on Liability and Indemnification of Directors and Officers Subject to the The failure of a director, alternate director or officer of the Company to comply with the
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE Resignation of Independent Registered Public Accounting Firm On October 31, 2022, Davidson & Company LLP (“Davidson”) resigned as the Company’s independent registered public accounting firm effective October 31, 2022. Davidson audited the Company’s consolidated financial statements as of and for the fiscal years ended September 30, 2021 and 2020. The report of Davidson on the financial statements of the Company for the fiscal years ended September 30, 2021 and 2020, did not contain any adverse opinion or disclaimer of opinion and were not qualified or modified as to uncertainty, audit scope or accounting principles. During the Company’s fiscal years ended September 30, 2021 and 2020, and through the interim period ended October 31, 2022, there were no disagreements between the Company and Davidson on any matter of accounting principles or practices, financial statement disclosure, or auditing scope or procedure, which disagreements, if not resolved to the satisfaction of Davidson, would have caused Davidson to make reference to the subject matter of the disagreements in connection with its audit reports on the Company’s financial statements. During the Company’s two most recent fiscal years ended September 30, 2021 and 2020, and the interim period ended October 31, 2022, Davidson did not advise the Company of any reportable events specified in Item 304(a)(1)(v) of Regulation S-K with respect to the Company. The Company provided Davidson with a copy of the Company’s current report on Form 8-K in accordance with Item 304(a) of Regulation S-K prior to the filing of such report with the Securities and Exchange Commission and requested that Davidson furnish the Company with a letter addressed to the Securities and Exchange Commission stating whether it agrees with the above statements and, if it does not agree, the respects in which it does not agree. A copy of the letter from Davidson is included as Exhibit 16.1 to the registration statement of which this prospectus forms a part.
On October 31, 2022, through and with the approval of its Audit Committee, the Company appointed Marcum LLP (“Marcum”) as its independent registered public accounting firm. During the Company’s two most recently completed fiscal years and through the date of engagement of Marcum, neither the Company nor anyone on behalf of the Company consulted with Marcum regarding (a) the application of accounting principles to a specified transaction, either completed or proposed, or the type of audit opinion that might be rendered on the Company’s financial statements as to which the Company received a written report or oral advice that was an important factor in reaching a decision on any accounting, auditing or financial reporting issue; or (b) any matter that was the subject of a disagreement or a reportable event as defined in Items 304(a)(1)(iv) and (v) of Regulation S-K. TAX CONSIDERATIONS
The following is a summary of the
This summary is for general information purposes only and does not purport to be a complete analysis or listing of all potential U.S. federal income tax considerations that may apply to a U.S. Holder as a result of the acquisition of Common Units or Pre-funded Units pursuant to this offering. In addition, this summary does not take into account the individual facts and circumstances of any particular U.S. Holder that may affect the U.S. federal income tax consequences to such U.S. Holder, including specific tax consequences to a U.S. Holder under an applicable tax treaty. Accordingly, this summary is not intended to be, and should not be construed as, legal or U.S. federal income tax advice with respect to any particular U.S. Holder. This summary does not address the U.S. federal net investment income, U.S. federal alternative minimum, U.S. federal estate and gift, U.S. state and local, and non-U.S. tax consequences to U.S. Holders of the acquisition, ownership, and disposition of
No
Authorities This summary is based on the Internal Revenue Code of 1986, as amended (the “Code”), Treasury Regulations (whether final, temporary, or proposed) promulgated under the Code, published rulings of the IRS, published administrative positions of the IRS and U.S. court decisions, that are in effect and available, as of the date of this document. Any of the authorities on which this summary is based could be changed in a material and adverse manner at any time, and any such change could be applied retroactively. This summary does not discuss the potential effects, whether adverse or beneficial, of any proposed legislation that, if enacted, could be applied on a retroactive or prospective basis.
U.S. For purposes of this summary, the term “U.S. Holder”
Transactions Not Addressed This summary does not address the tax consequences of transactions effected prior or subsequent to, or concurrently with, any purchase of Common Units or Pre-funded Units pursuant to this Prospectus (whether or not any such transactions are undertaken in connection with the purchase of Common Units or Pre-funded Units pursuant to this Prospectus). U.S. Holders Subject to Special U.S. Federal Income Tax Rules Not Addressed This summary does not address the U.S. federal income tax
U.S. Federal Income Tax Consequences of
For this purpose, we will allocate $ of the purchase price for the Common Unit to the Common Share and $ of the purchase price for each Common Unit to the Warrant. However, the IRS will not be bound by such allocation of the purchase price for the Common Units, and therefore, the IRS or a U.S. court may not respect the allocation set forth above. Each U.S. Holder should consult its own tax advisor regarding the allocation of the purchase price for the Common Units. For U.S. federal income tax purposes, the acquisition by a U.S. Holder of a Pre-funded Unit will be treated as the acquisition of one Pre-funded Warrant and one Warrant. The purchase price for each Pre-funded Unit will be allocated between these two components in proportion to their relative fair market values at the time the Pre-funded Unit is purchased by the U.S. Holder. This allocation of the purchase price for each Pre-funded Unit will establish a U.S. Holder’s initial tax basis for U.S. federal income tax purposes in the Pre-funded Warrant and one Warrant that comprise each Pre-funded Unit. For this purpose, we will allocate $ of the purchase price for the Pre-funded Unit to the Pre-funded Warrant and $ of the purchase price for each Pre-funded Unit to the Warrant. However, the IRS will not be bound by such allocation of the purchase price for the Pre-funded Units, and therefore, the IRS or a U.S. court may not respect the allocation set forth above. Each U.S. Holder should consult its own tax advisor regarding the allocation of the purchase price for the Pre-funded Units. Treatment of Pre-funded Warrants Although it is not entirely free from doubt, we believe that a Pre-funded Warrant should be treated as a separate class of our Common Shares for U.S. federal income tax purposes and a U.S. Holder of Pre-funded Warrants should generally be taxed in the same manner as a holder of Common Shares except as described below. Accordingly, no gain or loss should be recognized upon the exercise of a Pre-funded Warrant and, upon exercise, the holding period
Passive Foreign Investment Company Rules
In addition, U.S. Holders of PFICs are required to file an annual report with the IRS containing such information as Treasury Regulations and/or other IRS guidance may require, which filing obligation would generally commence in the first tax year in which In general, the Company will be a PFIC if, for a tax year, (a) 75% or more of Under certain
If the
While there are U.S. federal income tax elections that sometimes can be made to mitigate these adverse tax consequences (including, without limitation, the U.S. Holders should be aware that, for each tax year, if any, that the Company is a PFIC, the Company does not intend to provide U.S. Holders the information
U.S. Federal Income Tax Consequences of the Exercise and Disposition of Warrants The following discussion describes the general rules applicable to the ownership and disposition of the Warrants but is subject in its entirety to the special rules described above under the heading Passive Foreign Investment Company Rules. Exercise of Warrants A U.S. Holder should not recognize gain or loss on the exercise of a Warrant and related receipt of a Warrant Share (unless cash is received in lieu of the issuance of a fractional Warrant Share). A U.S. Holder’s initial tax basis in the Warrant Share received on the exercise of a Warrant should be equal to the sum of (a) such U.S. Holder’s tax basis in such Warrant plus (b) the exercise price paid by such U.S. Holder on the exercise of such Warrant. It is unclear whether a U.S. Holder’s holding period for the Warrant Share received on the exercise of a Warrant would commence on the date of exercise of the Warrant or the day following the date of exercise of the Warrant. If we are a PFIC, a U.S. Holder’s holding period for the Warrant Share for PFIC purposes will begin on the date on which such U.S. Holder acquired its Common Units. In certain limited circumstances, a U.S. Holder may be permitted to undertake a cashless exercise of Warrants into Warrant Shares. The U.S. federal income tax treatment of a cashless exercise of Warrants into Warrant Shares is unclear, and the tax consequences of a cashless exercise could differ from the consequences upon the exercise of a Warrant described in the preceding paragraph. U.S. Holders should consult their own tax advisors regarding the U.S. federal income tax consequences of a cashless exercise of Warrants. Disposition of Warrants A U.S. Holder will recognize gain or loss on the sale or other taxable disposition of a Warrant in an amount equal to the difference, if any, between (a) the amount of cash plus the fair market value of any property received and (b) such U.S. Holder’s tax basis in the Warrant sold or otherwise disposed of. Subject to the PFIC rules discussed above, any such gain or loss generally will be a capital gain or loss, which will be long-term capital gain or loss if the Warrant is held for more than one year. Deductions for capital losses are subject to complex limitations under the Code. Expiration of Warrants Without Exercise Upon the lapse or expiration of a Warrant, a U.S. Holder will recognize a loss in an amount equal to such U.S. Holder’s tax basis in the Warrant. Any such loss generally will be a capital loss and will be long-term capital loss if the Warrants are held for more than one year. Deductions for capital losses are subject to complex limitations under the Code. Certain Adjustments to the Warrants Under Section 305 of the Code, an adjustment to the number of Warrant Shares that will be issued on the exercise of the Warrants, or an adjustment to the exercise price of the Warrants, may be treated as a constructive distribution to a U.S. Holder of the Warrants if, and to the extent that, such adjustment has the effect of increasing such U.S. Holder’s proportionate interest in the “earnings and profits” or our
Distributions on Common Shares, Pre-funded Warrants and Warrant Shares A U.S. Holder that receives a distribution, including a constructive distribution, with respect to a Common Share, Pre-funded Warrant or Warrant Share (as well as any constructive distribution on a Warrant as described above) will be required to include the amount of such distribution in gross income as a dividend (without reduction for any Canadian income tax withheld from such distribution) to the extent of our current and accumulated “earnings and profits”, as computed under U.S. federal income tax principles. A dividend generally will be taxed to a U.S. Holder at ordinary income tax rates if we are a PFIC for the tax year of such distribution or the preceding tax year. To the extent that a distribution exceeds our current and accumulated “earnings and profits”, such distribution will be treated first as a tax-free return of capital to the extent of a U.S. Holder’s tax basis in the Common Shares, Pre-funded Warrants or Warrant Shares and thereafter as gain from the sale or exchange of Sale or Other Taxable Disposition of Common Shares, Pre-funded Warrants and/or Warrant Shares Upon the sale or other taxable disposition of Common Shares, Pre-funded Warrants or Warrant Shares, a U.S. Holder generally will recognize capital gain or loss in an amount equal to the difference between (a) the amount of cash plus the fair market value of any property received and (b) such U.S. Holder’s tax basis in such Common Shares, Pre-funded Warrants or Warrant Shares sold or otherwise disposed of. Gain or loss recognized on such sale or other taxable disposition generally will be long-term capital gain or loss if, at the time of the sale or other taxable disposition, the Common Shares, Pre-funded Warrants or Warrant Shares have been held for more than one year. Preferential tax rates may apply to long-term capital gain of a U.S. Holder that is an individual, estate, or trust. There are no preferential tax rates for long-term capital gain of a U.S. Holder that is a corporation. Deductions for capital losses are subject to significant limitations under the Code.
Additional Tax Considerations Receipt of Foreign Currency The amount of any distribution paid to a U.S. Holder in foreign currency or on the sale, exchange or other taxable disposition of Common Shares, Pre-funded Warrants, Warrants or Warrant Shares generally will be equal to the U.S. dollar value of such foreign currency based on the exchange rate applicable on the date of receipt (regardless of whether such foreign currency is converted into U.S. dollars at that time). If the foreign currency received is not converted into U.S. dollars on the date of receipt, a U.S. Holder will have a tax basis in the foreign currency equal to its U.S. dollar value on the date of receipt. Any U.S. Holder who receives payment in foreign currency and engages in a subsequent conversion or other disposition of the foreign currency may have a foreign currency exchange gain or loss that would be treated as ordinary income or loss, and generally will be U.S. source income or loss for foreign tax credit purposes. Different rules apply to U.S. Holders who use the accrual method of tax accounting. Each U.S. Holder should consult its own U.S. tax advisor regarding the U.S. federal income tax consequences of receiving, owning, and disposing of foreign currency. Foreign Tax Credit Subject to the PFIC rules discussed above, a U.S. Holder that pays (whether directly or through withholding) Canadian income tax with respect to dividends paid on the Common Shares, Pre-funded Warrants or Warrant Shares (or with respect to any constructive dividend on the Warrants) generally will be entitled, at the election of such U.S. Holder, to receive either a deduction or a credit for such Canadian income tax paid. Generally, a credit will reduce a U.S. Holder’s U.S. federal income tax liability on a dollar-for-dollar basis, whereas a deduction will reduce a U.S. Holder’s income subject to U.S. federal income tax. This election is made on a year-by-year basis and applies to all foreign taxes paid or accrued (whether directly or through withholding) by a U.S. Holder during a year. The foreign tax credit rules are complex and involve the application of rules that depend on a U.S. Holder’s particular circumstances. Accordingly, each U.S. Holder should consult its own tax advisor regarding the foreign tax credit rules. Information Reporting; Backup Withholding Tax Under U.S. federal income tax laws certain categories of U.S. Holders must file information returns with respect to their investment in, or involvement in, a foreign corporation. For example, U.S. return disclosure obligations (and related penalties) are imposed on U.S. Holders that hold certain specified foreign financial assets in excess of certain threshold amounts. The definition of specified foreign financial assets includes not only financial accounts maintained in foreign financial institutions, but also, unless held in accounts maintained by a financial institution, any stock or security issued by a non-U.S. person. U. S. Holders may be subject to these reporting requirements unless their Common Shares, Pre-funded Warrants, Warrants, and Warrant Shares are held in an account at certain financial institutions. Penalties for failure to file certain of these information returns are substantial. U.S. Holders should consult their own tax advisors regarding the requirements of filing information returns, including the requirement to file IRS Form 8938. Payments made within the U.S., or
THE ABOVE SUMMARY IS NOT INTENDED TO CONSTITUTE A COMPLETE ANALYSIS OF ALL TAX CONSIDERATIONS APPLICABLE TO U.S. HOLDERS WITH RESPECT TO THE ACQUISITION, OWNERSHIP, AND DISPOSITION OF COMMON UNITS, PRE-FUNDED UNITS, COMMON SHARES, PRE-FUNDED WARRANTS, WARRANTS, AND WARRANT SHARES. U.S. HOLDERS SHOULD CONSULT THEIR OWN TAX ADVISORS AS TO THE TAX CONSIDERATIONS APPLICABLE TO THEM IN LIGHT OF THEIR OWN PARTICULAR CIRCUMSTANCES.
MATERIAL CANADIAN FEDERAL INCOME TAX CONSIDERATIONS The following This summary does not deal with special situations, such as the particular circumstances of traders or dealers or holders who have entered or will enter into a “derivative forward agreement” (as defined in This summary is based upon the current provisions of This summary is of a general nature only and is not intended to be, nor should it be construed to be, legal or tax advice to any particular U.S. Holder and no representation with respect to the federal income tax consequences Currency Conversion In general, for purposes of the Tax Act, all amounts relating to the acquisition, holding or disposition of the Securities must be converted into Canadian dollars based on the applicable exchange rate quoted by the Bank of Canada for the relevant day or such other rate of exchange that is Allocation of Cost A U.S. Holder who acquires Common Units or Pre-Funded Units, as the case may be, will be required to allocate the purchase price paid for each Common Unit or Pre-Funded Unit on Exercise or Expiry of Warrants No gain or loss will be realized by a U.S. Holder in respect of a Warrant or Pre-Funded Warrant upon the exercise of such Warrant or Pre-Funded Warrant for Common Shares. When a Warrant or Pre-Funded Warrant is exercised, the U.S. Holder’s cost of the Common Share acquired thereby will be equal to the adjusted cost base of the Warrant or Pre-Funded Warrant to such U.S. Holder, plus the amount paid by such U.S. Holder on the exercise of the Warrant or Pre-Funded Warrant. For the purpose of computing the adjusted cost base to a U.S. Holder of the Common Shares acquired on the exercise of a Warrant or Pre-Funded Warrant, the cost of such Common Shares must be averaged with the adjusted cost base to such U.S. Holder of all other Common Shares (if any) held by the U.S. Holder as capital property immediately prior to the exercise of such Warrant.
Dispositions Upon the
A U.S. Holder Provided that the Common Shares are listed on a designated stock exchange for purposes of the Tax Act
If a Security is taxable Canadian property U.S. Holders who hold our
CAUTIONARY STATEMENT ON SERVICE OF PROCESS AND THE ENFORCEMENT OF CIVIL LIABILITIES We are a British Columbia, Canada company. As a result, the rights of holders of our
The underwriters are committed to purchase all Common Units and Pre-funded Units offered by us, if any are purchased. The obligations of the underwriters may be terminated upon the occurrence of certain events specified in the underwriting agreement. Furthermore, the underwriting agreement provides that the obligations of the underwriters to pay for and accept delivery of the Common Units and Pre-funded Units offered by us in this prospectus are subject to various representations and warranties and other customary conditions specified in the underwriting agreement, such as receipt by the representative of officers’ certificates and legal opinions. We have agreed to indemnify the underwriters against specified liabilities, including liabilities under the Securities Act, and to contribute to payments the underwriters may be required to make in respect thereof. The underwriters are offering the Common Units and Pre-funded Units subject to prior sale, when, as and if issued to and accepted by them, subject to approval of legal matters by its counsel and other conditions specified in the underwriting agreement. The underwriters reserve the right to withdraw, cancel or modify offers to the public and to reject orders in whole or in part. Discounts, Commissions and Reimbursement The representative has advised us that the underwriters propose to offer the shares to the public at the initial public offering price per share set forth on the cover page of this prospectus. The underwriters may offer Common Units and Pre-funded Units to securities dealers at that price less a concession of not more than $ per security. After the initial offering to the public, the public offering price and The following table summarizes the underwriting discounts and commissions, non-accountable underwriters’ expense allowance and proceeds, before expenses, to us assuming both no exercise and full exercise by the underwriters of their
We estimate that the total expenses of this offering payable by us, not including underwriting discounts and commissions, will be approximately $ . Over-Allotment Option We have granted the representative an over-allotment option. This option, which is exercisable for Representative’s Warrants Upon the closing of this offering, we have agreed to issue to the representative, or its designees, warrants to purchase up to Common Shares equal in the aggregate to 5% of the total Common Shares (or in lieu thereof, the Pre-Funded Warrants) sold in this public offering (the “Representative’s Warrants”). The Representative’s Warrants will be exercisable at a per share exercise price equal to $ , which represents 125% of the public offering price per Common Unit sold in this offering. The Representative’s Warrants are exercisable at any time and from time to time, in whole or in part, during the four-and-½-year period commencing six months after the commencement of sales of this offering. The Representative’s Warrants also provide for one demand registration right of the shares underlying the Representative’s Warrants, and unlimited “piggyback” registration rights with respect to the registration of the Common Shares underlying the Representative’s Warrants and customary antidilution provisions. The demand registration right provided will not be greater than five years from the
Right of First Refusal Until 24 months from the closing of this offering, the representative shall have an irrevocable right of first refusal to act as sole investment banker, sole book-runner, sole financial advisor, sole underwriter and/or sole placement agent, at the representative’s sole discretion, for each and every future public and private equity offerings for our Company, or any successor to or any subsidiary of our Company, including all equity linked financings, on terms customary to the representative. The Discretionary Accounts The underwriters do not intend to confirm sales of the securities offered hereby to any accounts over which they have discretionary authority. Lock-up Agreements The Company has agreed with the representative to be subject to a lock-up period of three months following the date of this prospectus. In addition, each of our officers and directors have agreed with the representative to be subject to a lock-up period of six months following the date of this prospectus. This means that, during the applicable lock-up period, we and such persons may not offer for sale, contract to sell, sell, distribute, grant any option, right or warrant to purchase, pledge, hypothecate or otherwise dispose of, directly or indirectly, any of our Common Shares or any securities convertible into, or exercisable or exchangeable for, Common Shares, subject to customary exceptions. The representative may waive the terms of these lock-up agreements in its sole discretion and without notice. In addition, we have agreed to not issue any securities that are subject to a price reset based on the trading prices of our Common Shares or upon a specified or contingent event in the future, or enter into any agreement to issue securities at a future determined price for a period of two years following the closing date of this offering, subject to an exception. The representative may waive this prohibition in its sole discretion and without notice. Electronic Offer, Sale and Distribution of Securities A prospectus in electronic format may be made available on the websites maintained by the underwriters or selling group members. The underwriters may agree to allocate a number of securities to selling group members for sale to its online brokerage account holders. Internet distributions will be allocated by the underwriters and selling group members that will make internet distributions on the same basis as other allocations. Other than the prospectus in electronic format, the information on these websites is not part of, nor incorporated by reference into, this prospectus or the registration statement of which this prospectus forms a part, has not been approved or endorsed by us, and should not be relied upon by investors. Stabilization In connection with this offering, the underwriters may engage in stabilizing transactions, over-allotment transactions, syndicate-covering transactions, penalty bids and purchases to cover positions created by short sales. Stabilizing transactions permit bids to purchase shares so long as the stabilizing bids do not exceed a specified maximum, and are engaged in for the purpose of preventing or retarding a decline in the market price of the shares while this offering is in progress. Over-allotment transactions involve sales by the underwriters of securities in excess of the number of securities the underwriters are obligated to purchase. This creates a syndicate short position which may be either a covered short position or a naked short position. In a covered short position, the number of securities over-allotted by the underwriters are not greater than the number of securities that they may purchase in the over-allotment option. In a naked short position, the number of securities involved is greater than the number of securities in the over-allotment option. The underwriters may close out any short position by exercising their over-allotment option and/or purchasing securities in the open market.
Syndicate covering transactions involve purchases of securities in the open market after the distribution has been completed in order to cover syndicate short positions. In determining the source of securities to close out the short position, the underwriters will consider, among other things, the price of securities available for purchase in the open market as compared with the price at which it may purchase securities through exercise of the over-allotment option. If the underwriters sell more securities than could be covered by exercise of the over-allotment option and, therefore, have a naked short position, the position can be closed out only by buying securities in the open market. A naked short position is more likely to be created if the underwriters are concerned that after pricing there could be downward pressure on the price of the securities in the open market that could adversely affect investors who purchase in this offering. Penalty bids permit an underwriter to reclaim a selling concession from a syndicate member when the securities originally sold by that syndicate member are purchased in stabilizing or syndicate covering transactions to cover syndicate short positions. These stabilizing transactions, syndicate covering transactions and penalty bids may have the effect of raising or maintaining the market price of our securities or preventing or retarding a decline in the market price of our securities. As a result, the price of our securities in the open market may be higher than it would otherwise be in the absence of these transactions. Neither we nor the underwriters make any representation or prediction as to the effect that the transactions described above may have on the price of our securities. These transactions may be effected in the over-the-counter market or otherwise and, if commenced, may be discontinued at any time. Passive Market Making In connection with this offering, underwriters and selling group members may engage in passive market making transactions in our securities on The Nasdaq Capital Market in accordance with Rule 103 of Regulation M under the Exchange Act, during a period before the commencement of offers or sales of the securities and extending through the completion of the distribution. A passive market maker must display its bid at a price not in excess of the highest independent bid of that security. However, if all independent bids are lowered below the passive market maker’s bid, then that bid must then be lowered when specified purchase limits are exceeded. Other Relationships The underwriters and their affiliates may in the future provide various investment banking, commercial banking and other financial services for us and our affiliates for which they may in the future receive customary fees. The representative of the underwriters acted as the placement agent for our March 2022 offering and received a cash fee equal to 10% of the gross proceeds received by us in the offering and reimbursement of $125,000 for its expenses. Moreover, we issued ThinkEquity LLC and its designees warrants to purchase such number of Common Shares equal to 10% of the units sold in the offering, or warrants to purchase up to 19,628 Common Shares, at an exercise price of $50.40 per share. The representative of the underwriters also received, in connection with our warrant exchange that closed on June 30, 2023, an advisory fee of $62,556 and reimbursement of $25,964 in expenses, and we issued to its designees warrants to purchase up to 5,464 Common Shares at an exercise price of $18.00 per share. Except as disclosed in this prospectus, we have no current arrangements with the underwriters for any further services. Offer Restrictions Outside of the United States Other than in the United States, no action has been taken that would permit a public offering of our securities in any jurisdiction where action for the purpose is required. The securities offered by this prospectus may not be offered or sold, directly or indirectly, nor may this prospectus or any other offering material or advertisements in connection with the offer and sale of any such securities be distributed or published in any jurisdiction, except under circumstances that will result in compliance with the applicable rules and regulations of that country or jurisdiction. Persons into whose possession this prospectus comes are advised to inform themselves about and to observe any restrictions relating to the offering and the distribution of this prospectus. This prospectus does not constitute an offer to sell or a solicitation of an offer to buy any securities offered by this prospectus in any jurisdiction in which such an offer or a solicitation is unlawful.
Australia This prospectus is not a disclosure document under Chapter 6D of the Australian Corporations Act, has not been lodged with the Australian Securities and Investments Commission and does not purport to include the information required of a disclosure document under Chapter 6D of the Australian Corporations Act. Accordingly, (i) the offer of the securities under this prospectus is only made to persons to whom it is lawful to offer the securities without disclosure under Chapter 6D of the Australian Corporations Act under one or more exemptions set out in section 708 of the Australian Corporations Act, (ii) this prospectus is made available in Australia only to those persons as set forth in clause (i) above, and (iii) the offeree must be sent a notice stating in substance that by accepting this offer, the offeree represents that the offeree is such a person as set forth in clause (i) above, and, unless permitted under the Australian Corporations Act, agrees not to sell or offer for sale within Australia any of the securities sold to the offeree within 12 months after its transfer to the offeree under this prospectus. China The information in this document does not constitute a public offer of the securities, whether by way of sale or subscription, in the People’s Republic of China (excluding, for purposes of this paragraph, Hong Kong Special Administrative Region, Macau Special Administrative Region and Taiwan). The securities may not be offered or sold directly or indirectly in the PRC to legal or natural persons other than directly to “qualified domestic institutional investors.” European Economic Area—Belgium, Germany, Luxembourg and Netherlands The information in this document has been prepared on the basis that all offers of securities will be
France This document is not being distributed in the context of a public offering of financial securities (offre au public de titres financiers) in France within the meaning of Article L.411-1 of the French Monetary and Financial Code (Code Monétaire et Financier) and Articles 211-1 et seq. of the General Regulation of the French Autorité des marchés financiers (“AMF”). The securities have not been offered or sold This document and any other offering material relating to the securities have not been, and will not be, submitted to the AMF for approval in France and, accordingly, may not be distributed or caused to distributed, directly or indirectly, to the public in France. Such offers, sales and distributions have been Pursuant to Article 211-3 of the General Regulation of the AMF, investors in France are informed that the securities cannot be distributed (directly or indirectly) to the public by the investors otherwise than in accordance with Articles L.411-1, L.411-2, L.412-1 and L.621-8 to L.621-8-3 of the French Monetary and Financial Code. Ireland The information in this document does not constitute a prospectus under any Irish laws or regulations and this document has not been filed with or approved by any Irish regulatory authority as the information has not been prepared in the context of a public offering of securities in Ireland within the meaning of the Irish Prospectus (Directive 2003/71/EC) Regulations 2005 (the “Prospectus Regulations”). The securities have not been offered or sold, and will not be offered, sold or delivered directly or indirectly in Ireland by way of a public offering, except to (i) qualified investors as defined in Regulation 2(l) of the Prospectus Regulations and (ii) fewer than 100 natural or legal persons who are not qualified investors. Israel The securities offered by this prospectus have not been approved or disapproved by the Israeli Securities Authority (the ISA), nor have such securities been registered for sale in Israel. The shares may not be offered or sold, directly or indirectly, to the Italy The offering of the securities in the Republic of Italy has not been authorized by the Italian Securities and Exchange Commission (Commissione Nazionale per le Società e la Borsa, or “CONSOB”) pursuant to the Italian securities legislation and, accordingly, no offering material relating to the securities may be distributed in Italy and such securities may not be offered or sold in Italy in a public offer within the meaning of Article 1.1(t) of Legislative Decree No. 58 of 24 February 1998 (“Decree No. 58”), other than:
Any subsequent distribution of the securities in Italy must be made in compliance with the public offer and prospectus requirement rules provided under Decree No. 58 and the Regulation No. 11971 as amended, unless an exception from those rules applies. Failure to comply with such rules may result in the sale of such securities being declared null and void and in the liability of the entity transferring the securities for any damages suffered by the investors. Japan The securities have not been and will not be registered under Article 4, paragraph 1 of the Financial Instruments and Exchange Law of Japan (Law No. 25 of 1948), as amended (the “FIEL”) pursuant to an exemption from the registration
Portugal This document is not being distributed in the context of a public offer of financial securities (oferta pública de valores mobiliários) in Portugal, within the meaning of Article 109 of the Portuguese Securities Code (Código dos Valores Mobiliários). The securities have not been offered or sold and will not be offered or sold, directly or indirectly, to the Sweden This document has not been, and will not be, registered with or approved by Finansinspektionen (the Swedish Financial Supervisory Authority). Accordingly, this document may not be made available, nor may the securities be offered for sale in Sweden, other than under circumstances that are deemed not to require a prospectus under the Swedish Financial Instruments Trading Act (1991:980) (Sw. lag (1991:980) om handel med finansiella instrument). Any offering of securities in Sweden is limited to persons who are “qualified investors” (as defined in the Financial Instruments Trading Act). Only such investors may receive this document and they may not distribute it or the information contained in it to any other person. Switzerland The securities may not be publicly offered in Switzerland and will not be listed on the SIX Swiss Exchange (“SIX”) or on any other stock exchange or regulated trading facility in Switzerland. This document has been prepared without regard to the Neither this document nor any other offering material relating to the securities have been or will be This document is personal to
United Kingdom Neither the information in this document nor any other document relating to the offer has been delivered for approval to the Financial Services Authority in the United Kingdom and no prospectus (within the meaning of section 85 of the Any invitation or inducement to engage in investment activity (within the meaning of section 21 of FSMA) received in connection with the issue or sale of the securities has only been communicated or caused to be communicated and will In the United Kingdom, this document is being distributed only to, and is directed at, persons (i) who have Pursuant to section 3A.3 of National Instrument 33-105 Underwriting Conflicts, or NI 33-105, the underwriters are not required to comply with the disclosure requirements of NI 33-105 regarding underwriter conflicts of interest in connection with this LEGAL MATTERS Sheppard, Mullin, Richter & Hampton LLP, Los Angeles, California is acting as counsel to the Company regarding United States securities law matters. The validity of the issuance of the EXPERTS
The consolidated financial statements of Permex Petroleum Corporation as of September 30, 2022 and for the year then ended, The consolidated financial statements of Permex Petroleum Corporation as of September 30, 2021 and for the year ended September 30, 2021, Davidson & Company LLP, British Columbia, Canada is registered with both the Canadian Public Accountability Board and the U.S. Public Company Accounting Oversight Board. Certain estimates of our oil and gas reserves and related information included in this prospectus have been derived from reports prepared by the independent engineering firm, MKM Engineering. All such information has been so included on the authority of such firm as an expert regarding the matters contained in its reports.
WHERE YOU CAN FIND ADDITIONAL INFORMATION We have filed with the SEC a registration statement on Form S-1, including amendments and relevant exhibits and schedules, under the Securities Act covering the We are subject to the periodic reporting and other informational requirements of the Exchange Act, which requires us to file reports, including annual reports, and other information with the SEC. All information filed with the SEC, including the registration statement, will be available at the SEC’s web site at www.sec.gov. We will also make our filings available on our website at www.permexpetroleum.com. The information on our website, however, is not a part of this prospectus. Exclusive Information In evaluating an investment in our
Management Estimates Management estimates are derived in part from information released by independent industry analysts and other third-party sources, as well as data from our internal research, and are based on assumptions made by us upon reviewing such data and our knowledge of such industry and markets, which we believe to be reasonable. Our estimates involve risks and uncertainties, and are subject to change based on various factors, including those discussed in this prospectus under the heading “Risk Factors. These and other factors could cause results to differ materially from those expressed in the estimates made by the independent parties and by our management. See “Cautionary Note Regarding Forward-Looking Statements.” References
All references to “U.S. Dollars,” “USD” or “$” are to the legal currency of the United States; all references to “CAD$” and “C$” are to the legal currency of Canada. All references to “M$” are in thousands of dollars. Trademarks, Service Marks, and Trade Names This prospectus may contain trademarks, service marks, trade names and copyrights of other companies, which are the property of their respective owners. Solely for convenience, the trademarks, service marks, trade names and copyrights referred to in this prospectus are listed without the TM, SM, © and ® symbols, but parties may assert, to the fullest extent under applicable law, their rights to these trademarks, service marks, trade names and copyrights. Date of Information The information contained in this prospectus is accurate only as of the date of this prospectus. Neither the delivery of this prospectus nor any distribution of securities pursuant to this prospectus shall, under any circumstances, create any implication that there has been no change in the information set forth or incorporated by reference into this prospectus or in our affairs since the date of this prospectus. Our business, financial condition, results of operations and prospects may have changed since that date.
CONSOLIDATED FINANCIAL STATEMENTS
YEARS ENDED SEPTEMBER 30, 2022 AND 2021
(EXPRESSED IN UNITED STATES DOLLARS) PERMEX PETROLEUM CORPORATION INDEX TO CONSOLIDATED FINANCIAL STATEMENTS Report of Independent Registered Public Accounting Firm To the Shareholders and Directors of Permex Petroleum Corporation Opinion on the Consolidated Financial Statements We have audited the accompanying consolidated balance sheet of Permex Petroleum Corporation (the “Company”) as of September 30, 2021, and the related consolidated statements of loss and comprehensive loss, equity, and cash flows for the year ended September 30, 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 September 30, 2021, and the results of its operations and its cash flows for the year ended September 30, 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 these 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 entity’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. We have served as the Company’s auditor from 2017 to 2022.
July 14, 2022 (October 24, 2023 and February, 9, 2023 as to the effects of the 1 for 4 and 1 for 60 reverse stock splits discussed in Note 1)
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM To the Shareholders and Board of Directors of Permex Petroleum Corporation Opinion on the Financial Statements We have audited the accompanying consolidated balance sheet of Permex Petroleum Corporation (the “Company”) as of September 30, 2022, the related consolidated statements of loss and comprehensive loss, equity and cash flows for the year ended September 30, 2022, 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 September 30, 2022, and the results of its operations and its cash flows for the year ended September 30, 2022, in conformity with accounting principles generally accepted in the United States of America. Explanatory Paragraph – Going Concern The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As more fully described in Note 2, the Company has incurred significant losses and needs to raise additional funds to sustain its operations. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. Management’s plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty. Basis for Opinion These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our 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. /s/ Marcum llp Marcum llp We have served as the Company’s auditor since 2022. Houston, Texas
PERMEX PETROLEUM CORPORATION CONSOLIDATED BALANCE SHEETS AS AT SEPTEMBER 30
The accompanying notes are an integral part of these consolidated financial statements
PERMEX PETROLEUM CORPORATION CONSOLIDATED STATEMENTS OF LOSS AND COMPREHENSIVE LOSS YEARS ENDED SEPTEMBER 30
The accompanying notes are an integral part of these consolidated financial statements. PERMEX PETROLEUM CORPORATION CONSOLIDATED STATEMENTS OF EQUITY
The accompanying notes are an integral part of these consolidated financial statements. PERMEX PETROLEUM CORPORATION CONSOLIDATED STATEMENTS OF CASH FLOWS YEARS ENDED SEPTEMBER 30
The accompanying notes are an integral part of these consolidated financial statements. PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 1.BACKGROUND Permex Petroleum Corporation (the “Company”) was incorporated on April 24, 2017 under the laws of British Columbia, Canada and maintains its head office at Suite 925, 2911 Turtle Creek Blvd, Dallas, Texas, 75219. Its registered office is located at 10th floor, 595 Howe Street, Vancouver, British Columbia, Canada, V6C 2T5. The Company is primarily engaged in the acquisition, development and production of oil and gas properties in the United States. The Company’s oil and gas interests are located in Texas and New Mexico, USA. The Company is listed on the Canadian Securities Exchange (the “CSE”) under the symbol “OIL” and on the OTCQB under the symbol “OILCD”. On October 26, 2022, the Company’s board of directors approved a reverse stock split of the Company’s issued and outstanding common stock at a 1 for 60 ratio, which was effective November 2, 2022. On September 12, 2023, the Company’s board of directors approved a reverse stock split of the Company’s issued and outstanding common stock at a 1 for 4 ratio, which was effective October 23, 2023. The par value and authorized shares of common stock were not adjusted as a result of the reverse stock split. All issued and outstanding common stock, options, and warrants to purchase common stock and per share amounts contained in the financial statements have been retroactively adjusted to reflect the reverse stock split for all periods presented. 2.SIGNIFICANT ACCOUNTING POLICIES Basis of presentation The Company’s consolidated financial statements are prepared in accordance with generally accepted accounting principles in the United States of America (“US GAAP”) and pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Principles of Consolidation These consolidated financial statements include the accounts of the Company and its wholly owned subsidiary, Permex Petroleum US Corporation. All intercompany balances and transactions have been eliminated. Going concern of operations These consolidated financial statements have been prepared on a going concern basis which assumes that the Company will continue in operation for the foreseeable future and will be able to realize its assets and discharge its liabilities and commitments in the normal course of business. The Company has incurred losses since inception in the amount of $8,260,415 and has not yet achieved profitable operations. The Company has been relying on equity financing and loans from related parties to fund its operation in the past. While the Company has been successful in securing financing to date, there can be no assurances that it will be able to do so in the future. The aforementioned factors raise substantial doubt about the Company’s ability to continue as a going concern within one year after the date that the financial statements are issued. Management plans to fund operations of the Company with its current working capital and through increasing productions from its oil and gas leases. The Company also expects to raise additional funds through equity financings. There are no written agreements in place for such funding or issuance of securities and there can be no assurance that such will be available in the future. Management believes that this plan provides an opportunity for the Company to continue as a going concern. In view of these matters, continuation as a going concern is dependent upon continued operations of the Company, which in turn is dependent upon the Company’s ability to, meets its financial requirements, raise additional capital, and the success of its future operations. The financial statements do not include any adjustments to the amount and classification of assets and liabilities that may be necessary should the Company not continue as a going concern.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Use of Estimates The preparation of financial statements in accordance with US GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities at the date of the financial statements and the reported amount of revenue and expenses during the reporting period. Management evaluates these estimates and judgments on an ongoing basis and bases its estimates on experience, current and expected future conditions, third-party evaluations and various other assumptions that management believes are reasonable under the circumstances. Significant estimates have been used by management in conjunction with the following: (i) petroleum and natural gas reserves; (ii) the fair value of assets when determining the existence of impairment factors and the amount of impairment, if any; (iii) the costs of site restoration when determining asset retirement obligations; (iv) income taxes receivable or payable; (v) the useful lives of assets for the purposes of depreciation; (vi) general credit risk associated with receivables and other assets; and (vii) share-based payments. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, and makes adjustments when facts and circumstances dictate. These estimates are based on information available as of the date of the financial statements; therefore, actual results could differ from those estimates. Cash and cash equivalents The Company considers all highly liquid investments with an original maturity of three months or less when purchased to be cash and cash equivalents. Cash and cash equivalents are recorded at cost, which approximates fair value. Trade and other receivables Trade and other receivables are stated at net realizable value. The majority of customers are not extended credit and the majority of the receivables has payment terms of 30 days or less. On a periodic basis, management evaluates its accounts receivable and determines whether to provide an allowance or if any accounts should be written off based on a past history of write-offs, collections, and current credit conditions. A receivable is considered past due if the Company has not received payments based on agreed-upon terms. Given the nature and balances of the Company’s receivables the Company has no material loss allowance as at September 30, 2022 and September 30, 2021. Property and equipment The Company follows the successful efforts method of accounting for its oil and gas properties. All costs for development wells along with related acquisition costs, the costs of drilling development wells, and related asset retirement obligation (ARO) assets are capitalized. Exploration costs, such as exploratory geological and geophysical costs, and costs associated with non-productive exploratory wells, delay rentals and exploration overhead are expensed. Costs of drilling exploratory wells are capitalized pending determination of whether the wells found proved reserves. Costs of wells that are assigned proved reserves remain capitalized. Costs also are capitalized for exploratory wells that have found crude oil and natural gas reserves even if the reserves cannot be classified as proved when the drilling is completed, provided the exploratory well has found a sufficient quantity of reserves to justify its completion as a producing well and the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project. The Company groups its oil and gas properties with a common geological structure or stratigraphic condition (“common operating field”) for purposes of computing depletion expenses, assessing proved property impairments and accounting for asset dispositions. Capitalized costs of proved oil and gas properties are depleted by individual field using a unit-of-production method based on proved and probable developed reserves. Proved reserves are estimated using reserve engineer reports and represent the estimated quantities of crude oil, natural gas and natural gas liquids, which geological, geophysical and engineering data demonstrate with a specified degree of certainty to be recoverable in future years from known reservoirs and which are considered commercially producible.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Property and equipment (cont’d…) Proved oil and natural gas properties are assessed for possible impairment by comparing their carrying values with their associated undiscounted, future net cash flows. Events that can trigger assessments for possible impairments include write-downs of proved reserves based on field performance, significant decreases in the market value of an asset (including changes to the commodity price forecast or carbon costs), significant change in the extent or manner of use of or a physical change in an asset, and a more-likely-than-not expectation that a long-lived asset or asset group will be sold or otherwise disposed of significantly sooner than the end of its previously estimated useful life. Impaired assets are written down to their estimated fair values, generally their discounted, future net cash flows. For proved oil and natural gas properties, the Company performs impairment reviews on a field basis, annually or as appropriate. Other corporate property and equipment consist primarily of leasehold improvements, vehicle, and office furniture and equipment and are stated at cost less accumulated depreciation. The capitalized costs are generally depreciated on a straight line basis over their estimated useful lives ranging from three to five years. For property dispositions, measurement is at fair value, unless the transaction lacks commercial substance or fair value cannot be reliably measured. Where the exchange is measured at fair value, a gain or loss is recognized in net income. Any deferred consideration recorded on property dispositions are recognized as revenue in the statement of loss and comprehensive loss over the reserve life. Gains or losses are recorded for sales or dispositions of oil and gas properties which constitute an entire common operating field or which result in a significant alteration of the common operating field’s depletion rate. These gains and losses are classified as asset dispositions in the accompanying consolidated statements of loss and comprehensive loss. Partial common operating field sales or dispositions deemed not to significantly alter the depletion rates are generally accounted for as adjustments to capitalized costs with no gain or loss recognized. Impairment of long-lived assets The Company assesses long-lived assets for impairment in accordance with the provisions of the Financial Account Standards Board Accounting Standards Codification (“ASC”) regarding long-lived assets. It requires that long-lived assets be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable through the estimated undiscounted cash flows expected to result from the use and eventual disposition of the assets. Whenever any such impairment exists, an impairment loss will be recognized for the amount by which the carrying value exceeds the fair value. As of September 30, 2022 and September 30, 2021, no impairment charge has been recorded. Asset retirement obligations The Company recognizes asset retirement obligations (“ARO”) associated with tangible assets such as well sites when there is a legal obligation associated with the retirement of such assets and the amount can be reasonably estimated. The ARO are measured at the present value of management’s best estimate of the future remediation expenditures at the reporting date. The initial measurement of an ARO is recorded as a liability at its fair value, with an offsetting asset retirement cost recorded as an increase to the associated property and equipment on the consolidated balance sheet. When the assumption used to estimate a recorded ARO change, a revision is recorded to both the ARO and the asset retirement cost. The ARO is accreted to its then present value each period, and the asset retirement cost is depreciated using a systematic and rational method similar to that used for the associated property and equipment.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Fair value measurement Fair value accounting is applied for all assets and liabilities and nonfinancial assets and liabilities that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). Fair value is defined as the exchange price that would be received for an asset or an exit price that would be paid to transfer a liability in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. The Company follows the established framework for measuring fair value and expands disclosures about fair value measurements. The Company categorizes its assets and liabilities measured at fair value into a three-level hierarchy based on the priority of the inputs to the valuation technique used to determine fair value. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). If the inputs used in the determination of the fair value measurement fall within different levels of the hierarchy, the categorization is based on the lowest level input that is significant to the fair value measurement. Assets and liabilities valued at fair value are categorized based on the inputs to the valuation techniques as follows: Level 1 – Inputs that utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access. Level 2 – Inputs that include quoted prices for similar assets and liabilities in active markets and inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the financial instrument. Fair values for these instruments are estimated using pricing models, quoted prices of securities with similar characteristics, or discounted cash flows. Level 3 – Inputs that are unobservable inputs for the asset or liability, which are typically based on an entity’s own assumptions, as there is little, if any, related market activity. The carrying values of cash and cash equivalents, trade receivable, other current receivables, due from/to related parties, trade payable, other current payables, accrued expenses, convertible debenture and lease liability included in the accompanying consolidated balance sheets approximated fair value at September 30, 2022 and September 30, 2021. The financial statements as of and for the years ended September 30, 2022 and September 30, 2021, do not include any recurring or nonrecurring fair value measurements relating to assets or liabilities. Subsequent to initial recognition, the Company may re-measure the carrying value of assets and liabilities measured on a nonrecurring basis to fair value. Adjustments to fair value usually result when certain assets are impaired. Such assets are written down from their carrying amounts to their fair value. Professional standards allow entities the irrevocable option to elect to measure certain financial instruments and other items at fair value for the initial and subsequent measurement on an instrument-by-instrument basis. The Company has not elected to measure any existing financial instruments at fair value. However, it may elect to measure newly acquired financial instruments at fair value in the future. Basic earnings (loss) per share (“EPS”) is calculated by dividing net income (loss) attributable to common shareholders by the weighted average number of common shares outstanding in the period. The diluted EPS reflects all dilutive potential common share equivalents, in the weighted average number of common shares outstanding during the period, if dilutive. All of the outstanding convertible securities, stock options and warrants were anti-dilutive for the years ended September 30, 2022 and 2021.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Leases At inception of a contract, the Company assesses whether a contract is, or contains a lease based on whether the contract conveys the right to control the use of an identified asset for a period in exchange for consideration. The Company recognizes a right-of-use asset and a lease liability at the lease commencement date. The right-of-use asset is initially measured based on the initial amount of the lease liability adjusted for any lease payments made at or before the commencement date. The lease obligation is initially measured at the present value of the lease payments that are not paid at the commencement date, discounted using the interest rate implicit in the lease or, if that rate cannot be readily determined, the Company’s incremental borrowing rate. Generally, the Company uses its incremental borrowing rate as the discount rate. Variable lease payments that do not depend on an index or rate are not included in the measurement of the lease liability. The lease liability is subsequently measured at amortized cost using the effective interest rate method. The Company records proceeds from the issuance of its common shares as equity. Incremental costs directly attributable to the issue of new common shares are shown in equity as a deduction, net of tax, from the proceeds. Common shares issued for consideration other than cash are valued based on their market value at the date that the shares are issued. The fair value of warrants issued with private placement units is determined using the Black-Scholes option pricing model. Proceeds from the issuance of private placement units are allocated between the private placement warrants and common shares on a relative fair value basis. Share purchase warrants with exercise prices denominated in a currency other than its functional currency are classified as a liability. Proceeds from the issuance of private placement units are first allocated to the warrant liability based on their fair value and the residual is allocated to common shares issued while for equity warrants, proceeds are allocated on a relative fair value basis. The changes in fair value of the warrant liability are recorded in the statement of loss and comprehensive loss. Warrants issued for oil and gas interests and warrants issued as finder’s fees are share-based payments and are measured at fair value on the date of the grant as determined using the Black-Scholes option pricing model. Share-based payments The Company issues stock options and other share-based compensation to directors, employees and others service providers. Equity awards including stock options and share purchase warrants are measured at grant date at the fair value of the instruments issued and amortized over the vesting periods using a graded vesting approach. The number of options expected to vest is reviewed and adjusted at the end of each reporting period such that the amount ultimately recognized as an expense is based on the number of options that eventually vest. The Company has elected to account for forfeitures as they occur rather than estimate expected forfeitures. The fair value of the equity awards is determined using the Black-Scholes option pricing model. Measurement inputs include share price on measurement date, exercise price of the instrument, expected volatility (based on weighted average historic volatility), weighted average expected life of the instruments (based on historical experience), expected dividends, and the risk-free interest rate (based on government bonds).
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Revenue In accordance with ASC 606, Revenue from Contracts with Customers, the Company recognizes revenue when the performance obligation is satisfied, which typically occurs at the point in time when control of the product transfer to the customer. For natural gas, this is generally at the time product enters the pipeline. For crude oil, this is generally at the time the product is loaded into customer operated transports. Revenue is measured net of discounts, customs duties, royalties and withholding tax. Royalty income represents net revenue interests from certain crude oil and natural gas wells and is recognized upon the operators of the properties producing revenue from subject oil and gas wells. The Company records revenue in the month production is delivered to the purchaser. However, production statements for oil and gas sales may not be received until the following month end after the products are purchased, and as a result, the Company is required to estimate the amount of revenue to be received. The Company records the differences between its estimates and the actual amounts received for revenue in the month that payment is received from the customer. Identified differences between the Company’s revenue estimates and actual revenue received are $1,395 and $nil for years ended September 30, 2022 and September 30, 2021, respectively. The Company believes that the pricing provisions of its oil, natural gas and natural gas liquids contracts are customary in the industry. To the extent actual volumes and prices of oil and natural gas sales are unavailable for a given reporting period because of timing or information not received from third parties, the revenue related to sales volumes and prices for those good sold are estimated and recorded. The Company does not have any contract assets or liabilities, or capitalized contract costs. Foreign Currency These consolidated financial statements are presented in United States dollars (“U.S. dollar”). The functional currency of the Company and the subsidiary of the Company is the U.S. dollar. The Company changed its functional currency from Canadian dollars (“CAD”) to the U.S. dollars as at October 1, 2021. The change in functional currency from Canadian dollars to U.S. dollars is accounted for prospectively from October 1, 2021. Management determined that the Company’s functional currency had changed based on the assessment related to significant changes of the Company’s economic facts and circumstances. These significant changes included the fact that the Company’s equity financings and the primary economic environment are now in the U.S. as well as the expectation of the majority of the Company’s expenses will be denominated in U.S. dollars. Moreover, the Company’s place of business and management are now located in the United States. Foreign currency transactions are translated into the functional currency using exchange rates prevailing at the dates of the transactions. At the end of each reporting period, monetary assets and liabilities that are denominated in foreign currencies are translated at the rates prevailing at that date. Non-monetary assets and liabilities are translated using the historical rate on the date of the transaction. Non-monetary assets and liabilities that are stated at fair value are translated using the historical rate on the date that the fair value was determined. All gains and losses on translation of these foreign currency transactions are charged to profit or loss.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Income taxes Current taxes receivable or payable are estimated on taxable income or loss for the current year at the statutory tax rates enacted or substantively enacted at the reporting date. Deferred income tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the tax bases of assets and liabilities and their carrying amounts in the financial statements. Deferred income tax assets and liabilities are measured at the tax rates that have been enacted or substantially enacted at the end of the reporting period and are expected to apply when the related deferred income tax asset is realized or the deferred income tax liability is settled. Deferred income tax assets also result from unused loss carry forwards, resource related pools and other deductions. At the end of each reporting year the Company reassesses unrecognized deferred tax assets. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred income tax assets and deferred income tax liabilities are offset if a legally enforceable right exists to offset current tax assets against current tax liabilities and the deferred tax assets and liabilities relate to income taxes levied by the same taxation authority. New accounting standards There are not currently any new or pending accounting standards that have a significant impact on the Company’s consolidated financial statements. 3.REVENUE Revenue from contracts with customers is presented in “Oil and gas sales” on the Consolidated Statement of Loss and Comprehensive Loss. As of September 30, 2022 and September 30, 2021, receivable from contracts with customers, included in trade and other receivables, were $56,639 and $nil, respectively. The following table present our revenue from contracts with customers disaggregated by product type and geographic areas. SCHEDULE OF REVENUE DISAGGREGATED BY PRODUCT TYPE AND GEOGRAPHIC AREAS
4.CONCENTRATION OF CREDIT RISK The Company’s financial instruments that are exposed to concentrations of credit risk consist primarily of its cash equivalents and trade receivables. The Company’s cash balances sometimes exceed the United States’ Federal Deposit Insurance Corporation insurance limits. The Company mitigates this risk by placing its cash and cash equivalents with high credit quality financial institutions and attempts to limit the amount of credit exposure with any one institution. To date, the Company has not recognized any losses caused by uninsured balances. The majority of the Company’s receivable balance is concentrated in trade receivables, with a balance of $91,928 as of September 30, 2022. Three customers represented $79,942 (87%) of the trade receivable balance. The Company routinely assesses the financial strength of its customers. The non-trade receivable balance consists of GST recoverable of $39,770 and interest receivable of $5,516. GST recoverable is due from the Canadian Government. Interest receivable is due from a financial institution with high credit rating. It is in management’s opinion that the Company is not exposed to significant credit risk. To date, the Company has not recognized any credit losses on its receivables.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 5.ACQUISITION AND DISPOSITION Acquisition During the year ended September 30, 2021, the Company and its wholly owned subsidiary, Permex Petroleum US Corporation, acquired a 100% Working Interest and a 81.75% Net Revenue Interest in the Breedlove “B” Clearfork leases located in Martin County, Texas. The Company issued common shares and share purchase warrants as consideration for this acquisition. The Company valued the common shares issued at a fair value of $2,468,750. The share purchase warrants were valued at $ using the Black-Scholes option pricing model (assuming a risk-free interest rate of %, an expected life of -years, annualized volatility of % and a dividend rate of %). The warrants have an exercise price $ per share (CAD$ ) and are exercisable until September 30, 2031. Disposition During the year ended September 30, 2021, the Company sold its interests in the Peavy leases together with reclamation obligations for $10,000 and recognized a loss of $604,687 from the sale. The Company also recognized a loss of $8,770 from the disposal of equipment. 6. PROPERTY AND EQUIPMENT Property and equipment consisted of the following: SCHEDULE OF PROPERTY AND EQUIPMENT
Depletion and depreciation expense was $105,503 and $60,479 for the years ended September 30, 2022 and September 30, 2021, respectively.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 7.LEASES All of the Company’s right-of-use assets are operating leases related to its office premises. Details of the Company’s right-of-use assets and lease liabilities are as follows: SCHEDULE OF RIGHT OF USE OPERATING LEASES
The following table presents the Company’s total lease cost. SCHEDULE OF LEASE COST
As of September 30, 2022, maturities of the Company’s operating lease liabilities are as follows: SCHEDULE OF FUTURE LEASE PAYMENTS
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 8.ASSET RETIREMENT OBLIGATIONS Asset retirement obligations reflects the estimated present value of the amount of dismantlement, removal, site reclamation, and similar activities associated with the Company’s oil and gas properties. Changes to the asset retirement obligations are as follows: SCHEDULE OF ASSET RETIREMENT OBLIGATIONS
During the year ended September 30, 2022, the Company had revision of estimates totaling $371,212 (2021 - increase of $117,921) primarily due to changes in future cost estimates and retirement dates for its oil and gas assets. Reclamation bonds As of September 30, 2022, the Company held reclamation bonds of $145,000 (September 30, 2021 - $144,847), which are expected to be released after all reclamation work has been completed with regard to its oil and natural gas interests. During the year ended September 30, 2021, the Company wrote off $50,165 of a reclamation deposit forfeited by the Texas State government due to a violation on a previously owned property. 9.DEBT Convertible debenture As of September 30, 2022, the Company had a debenture loan of $73,000 (CAD$100,000) (September 30, 2021 - $78,500) from the CEO of the Company outstanding. The debenture loan is secured by an interest in all of the Company’s right, title, and interest in all of its oil and gas assets, bears interest at a rate of 12% per annum and has a maturity date of December 20, 2022. The debenture is convertible at the holder’s option into units of the Company at $26.28 (CAD$per unit. Each unit will be comprised of one common share of the Company and one share purchase warrant; each warrant entitles the holder to acquire one additional common share for a period of ) three years at an exercise price of $35.04(CAD$ ). During the year ended September 30, 2022, the Company repaid $34,709 of the loan (CAD$47,546). Subsequent to September 30, 2022, the Company repaid the remaining principal loan amount of CAD$52,454. During the years ended September 30, 2022 and September 30, 2021, the Company recorded interest of $9,360 and $13,506, respectively. Loan payable In May 2020, the Company opened a Canada Emergency Business Account (“CEBA”) and received a loan of $28,640 (CAD$40,000) from the Canadian Government. The CEBA program was established to provide interest-free loans of up to CAD$60,000 to small businesses to help them cover operating costs during the COVID-19 pandemic. The loan was unsecured and non-interest bearing with a repayment deadline of December 31, 2023. During the year ended September 30, 2022, the Company repaid the loan balance of $23,600 (CAD$30,000) and recognized a gain of $7,800 (CAD$10,000) on the forgiven amount.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 10.RELATED PARTY TRANSACTIONS
Included in amounts due to related parties are $nil(2021 - $1,321) related to accrued management fee to a director of the Company and $nil (2021 - $131) in advances from the CEO of the Company. Amounts due to related parties are unsecured, non-interest bearing, and have no specific terms of repayment. The calculation of basic and diluted loss per share for the years ended September 30, 2022 and 2021 was based on the net losses attributable to common shareholders. The following table sets forth the computation of basic and diluted loss per share:
As of September 30, 2022, $73,000 (CAD$100,000) of convertible debentures convertible into common shares, (2021 - stock options and (2021 - warrants were excluded from the diluted weighted average number of common shares calculation as their effect would have been anti-dilutive. PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 12.EQUITY Common stock The Company has authorized an no par value. At September 30, 2022 and September 30, 2021, the Company had and common shares issued and outstanding, respectively. number of common shares withDuring the year ended September 30, 2022, the Company:
During the year ended September 30, 2021, the Company:
Share-based payments Stock options The Company has a stock option plan (the “Plan”) in place under which it is authorized to grant options to executive officers and directors, employees and consultants. Pursuant to the Plan, the Company may issue aggregate stock options totaling up to 10% of the issued and outstanding common stock of the Company. Further, the Plan calls for the exercise price of each option to be equal to the market price of the Company’s stock as calculated on the date of grant. The options can be granted for a maximum term of years and vest at the discretion of the Board of Directors at the time of grant. PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Share-based payments (cont’d…) Stock option transactions are summarized as follows: SCHEDULE OF STOCK OPTION TRANSACTIONS
The aggregate intrinsic value of options outstanding and exercisable as at September 30, 2022 was $ (2021 - $ ). The options outstanding as of September 30, 2022 have exercise prices in the range of $ to $and a weighted average remaining contractual life of years. There were options granted during the year ended September 30, 2021. During the years ended September 30, 2022 and 2021, the Company recognized share-based payment expense of $ and $ , respectively, for the portion of stock options that vested during the year. The following weighted average assumptions were used for the Black-Scholes valuation of stock options granted:
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Share-based payments (cont’d…) SCHEDULE OF STOCK OPTIONS OUTSTANDING
Warrants Warrant transactions are summarized as follows: SCHEDULE OF WARRANTS TRANSACTIONS
As September 30, 2022, the following warrants were outstanding: SCHEDULE OF WARRANTS OUTSTANDING
5,515 warrants issued with private placement units during fiscal 2022 have an exercise price denominated in CAD. These warrants were initially valued at $202,009 using the Black-Scholes option pricing model (assuming a risk-free interest rate of , an expected life of years, annualized volatility of and a dividend rate of ) and recorded as a warrant liability. These warrants were subsequently revaluated and a gain on fair value adjustment of $178,509 was recorded during the year ended September 30, 2022. SCHEDULE OF VALUATION OF WARRANTS
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 13.INCOME TAXES SCHEDULE OF RECONCILIATION OF INCOME TAX
Components of the Company’s pre-tax loss and income taxes are as follows: SCHEDULE OF PRE TAX LOSS AND INCOME TAXES
The significant components of the Company’s deferred tax assets and liabilities are as follows: SCHEDULE OF DEFERRED TAX ASSETS AND LIABILITIES
The significant components of the Company’s temporary differences include unamortized financing fees and tax loss carryforwards. The valuation allowance reduces the deferred tax assets to amounts that are, in management’s assessment, more likely than not to be realized. For the years ended September 30, 2022 and 2021, the Company had financing fees of $801,000 and $140,000, respectively, with expiration dates between 2042 and 2047. The Company also had tax loss carryforwards of approximately $4,832,000 in Canada and the United States. For the years ended September 30, 2022 and 2021, the Canada tax losses totaled $4,028,000 and $2,707,000, respectively, with expiration dates ranging from 2037 to 2042 and 2037 to 2041, respectively. The United States tax losses for the years ended September 30, 2022 and 2021 totaled $804,000 and $213,000, respectively, and had no expiration dates. 14.SEGMENT INFORMATION Operating segments The Company operates in a single reportable segment – the acquisition, development and production of oil and gas properties in the United States.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021 15.SUPPLEMENTAL INFORMATION ON OIL AND GAS OPERATIONS (UNAUDITED) Supplemental unaudited information regarding Permex’s oil and gas activities is presented in this note. All of Permex’s reserves are located within the U.S. Costs Incurred in Oil and Gas Producing Activities SCHEDULE OF COST INCURRED IN PRODUCING ACTIVITIES
Results of Operations from Oil and Gas Producing Activities
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Proved Reserves The Company’s proved oil and natural gas reserves have been estimated by the certified independent engineering firm, MKM Engineering. Proved reserves are the estimated quantities that geologic and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are the quantities expected to be recovered through existing wells with existing equipment and operating methods when the estimates were made. Due to the inherent uncertainties and the limited nature of reservoir data, such estimates are subject to change as additional information becomes available. The reserves actually recovered and the timing of production of these reserves may be substantially different from the original estimate. Revisions result primarily from new information obtained from development drilling and production history; acquisitions of oil and natural gas properties; and changes in economic factors. Our proved reserves are summarized in the table below: SCHEDULE OF PROVED RESERVES
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The following information is based on the Company’s best estimate of the required data for the Standardized Measure of Discounted Future Net Cash Flows as of September 30, 2022 and September 30, 2021 in accordance with ASC 932, “Extractive Activities – Oil and Gas” which requires the use of a 10% discount rate. This information is not the fair market value, nor does it represent the expected present value of future cash flows of the Company’s proved oil and gas reserves. Future cash inflows for the years ended September 30, 2022 and September 30, 2021 were estimated as specified by the SEC through calculation of an average price based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for the period from October through September during each respective fiscal year. The resulting net cash flow are reduced to present value by applying a 10% discount factor. SCHEDULE OF NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES
SCHEDULE OF AVERAGE HYDROCARBON PRICES
Future production and development costs, which include dismantlement and restoration expense, are computed by estimating the expenditures to be incurred in developing and producing the Company’s proved crude oil and natural gas reserves at the end of the year, based on year-end costs, and assuming continuation of existing economic conditions.
PERMEX PETROLEUM CORPORATION NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS YEARS ENDED SEPTEMBER 30, 2022 AND 2021
Sources of Changes in Discounted Future Net Cash Flows Principal changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude oil and natural gas reserves, as required by ASC 932, at fiscal year-end are set forth in the table below. SCHEDULE OF CHANGES IN DISCOUNTED FUTURE NET CASH FLOWS
PERMEX PETROLEUM CORPORATION CONDENSED INTERIM CONSOLIDATED BALANCE SHEETS (UNAUDITED)
The accompanying notes are an integral part of these condensed interim consolidated financial statements.
PERMEX PETROLEUM CORPORATION CONDENSED INTERIM CONSOLIDATED STATEMENTS OF LOSS (UNAUDITED)
The accompanying notes are an integral part of these condensed interim consolidated financial statements.
PERMEX PETROLEUM CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED) Three months ended June 30
The accompanying notes are an integral part of these condensed interim consolidated financial statements.
PERMEX PETROLEUM CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED) Nine months ended June 30
The accompanying notes are an integral part of these condensed interim consolidated financial statements.
PERMEX PETROLEUM CORPORATION CONDENSED INTERIM CONSOLIDATED STATEMENTS OF CASH FLOWS NINE MONTHS ENDED JUNE 30 (UNAUDITED)
The accompanying notes are an integral part of these condensed interim consolidated financial statements.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 1. BACKGROUND Permex Petroleum Corporation (the “Company”) was incorporated on April 24, 2017under the laws of British Columbia, Canada and maintains its head office at Suite 925, 2911 Turtle Creek Blvd, Dallas, Texas, 75219. Its registered office is located at 10th floor, 595 Howe Street, Vancouver, British Columbia, Canada, V6C 2T5. The Company is primarily engaged in the acquisition, development and production of oil and gas properties in the United States. The Company’s oil and gas interests are located in Texas and New Mexico, USA. The Company is listed on the Canadian Securities Exchange (the “CSE”) under the symbol “OIL” and on the OTCQB under the symbol “OILCD”. On October 26, 2022, the Company’s board of directors approved a reverse stock split of the Company’s issued and outstanding common stock at a 1 for 60 ratio, which was effective November 2, 2022. The par value and authorized shares of common stock were not adjusted as a result of the reverse stock split. On September 12, 2023, the Company’s board of directors approved a reverse stock split of the Company’s issued and outstanding common stock at a 1 for 4 ratio, which was effective October 23, 2023. All issued and outstanding common stock, options, and warrants to purchase common stock and per share amounts contained in the financial statements have been retroactively adjusted to reflect the reverse stock split for all periods presented. 2. SIGNIFICANT ACCOUNTING POLICIES Basis of presentation The unaudited condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) and applicable rules and regulations of the United States Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. In the opinion of management, the condensed consolidated financial statements include all adjustments necessary, which are of a normal and recurring nature, for the fair presentation of the Company’s financial position and of the results of operations and cash flows for the periods presented. These interim results are not necessarily indicative of the results to be expected for the fiscal year ending September 30, 2023 or for any other interim period or for any other future fiscal year. These condensed consolidated financial statements should be read in conjunction with the Company’s audited financial statements and footnotes for the fiscal year ended September 30, 2022. Principles of Consolidation The accompanying consolidated financial statements include the assets, liabilities, revenue and expenses of the Company’s wholly-owned subsidiary, Permex Petroleum US Corporation. All intercompany balances and transactions have been eliminated.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 2. Significant Accounting Policies (cont’d…) Going concern of operations These consolidated financial statements have been prepared on a going concern basis which assumes that the Company will continue in operation for the foreseeable future and will be able to realize its assets and discharge its liabilities and commitments in the normal course of business. The Company has incurred losses since inception in the amount of $12,133,756 and has not yet achieved profitable operations. The Company has been relying on equity financing and loans from related parties to fund its operation in the past. While the Company has been successful in securing financing to date, there can be no assurances that it will be able to do so in the future. The aforementioned factors raise substantial doubt about the Company’s ability to continue as a going concern within one year after the date that the financial statements are issued. Management plans to fund operations of the Company with its current working capital and through increasing production from its oil and gas leases. The Company also expects to raise additional funds through equity financings. There are no written agreements in place for such funding or issuance of securities and there can be no assurance that such will be available in the future. Management believes that this plan provides an opportunity for the Company to continue as a going concern. In view of these matters, continuation as a going concern is dependent upon continued operations of the Company, which in turn is dependent upon the Company’s ability to meet its financial requirements, raise additional capital, and the success of its future operations. The financial statements do not include any adjustments to the amount and classification of assets and liabilities that may be necessary should the Company not continue as a going concern. Use of Estimates The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amount of assets and liabilities at the date of the financial statements and the reported amount of revenue and expenses during the reporting period. Management evaluates these estimates and judgments on an ongoing basis and bases its estimates on experience, current and expected future conditions, third-party evaluations and various other assumptions that management believes are reasonable under the circumstances. Significant estimates have been used by management in conjunction with the following: (i) the fair value of assets when determining the existence of impairment factors and the amount of impairment, if any; (ii) the costs of site restoration when determining decommissioning liabilities; (iii) the useful lives of assets for the purposes of depletion and depreciation; (iv) petroleum and natural gas reserves; and (v) share-based payments. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment, and makes adjustments when facts and circumstances dictate. These estimates are based on information available as of the date of the financial statements; therefore, actual results could differ from those estimates. New accounting standards There are not currently any new or pending accounting standards that are expected to have a significant impact on the Company’s consolidated financial statements.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 3. REVENUE Revenue from contracts with customers is presented in “Oil and gas sales” on the Consolidated Statements of Loss. As of June 30, 2023 and September 30, 2022, receivable from contracts with customers, included in trade and other receivables, were $52,201 and $56,639, respectively. The following table present our revenue from contracts with customers disaggregated by product type and geographic areas. SCHEDULE OF REVENUE DISAGGREGATED BY PRODUCT TYPE AND GEOGRAPHIC AREAS
4. CONCENTRATION OF CREDIT RISK The Company’s financial instruments that are exposed to concentrations of credit risk consist primarily of its cash equivalents and trade receivables. The Company’s cash balances sometimes exceed the United States’ Federal Deposit Insurance Corporation insurance limits. The Company mitigates this risk by placing its cash and cash equivalents with high credit quality financial institutions and attempts to limit the amount of credit exposure with any one institution. To date, the Company has not recognized any losses caused by uninsured balances. The majority of the Company’s receivable balance is concentrated in trade receivables, with a balance of $94,380 as of June 30, 2023 (September 30, 2022 - $91,928). Two customers represented $57,744 (61%) of the trade receivable balance. The Company routinely assesses the financial strength of its customers. The non-trade receivable balance consists of goods and services tax (“GST”) recoverable of $2,235. GST recoverable is due from the Canadian Government. It is in management’s opinion that the Company is not exposed to significant credit risk. To date, the Company has not recognized any credit losses on its receivables.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 5. PROPERTY AND EQUIPMENT Property and equipment consisted of the following: SCHEDULE OF PROPERTY AND EQUIPMENT
Depletion and depreciation expense was $120,459 and $161,988 for the nine month periods ended June 30, 2023 and June 30, 2022, respectively. Depletion and depreciation expense for the three month periods ended June 30, 2023 and June 30, 2022 was $37,286 and $73,093, respectively. 6. LEASES All of the Company’s right-of-use assets are operating leases related to its office premises. Details of the Company’s right-of-use assets and lease liabilities are as follows: SCHEDULE OF RIGHT OF USE OPERATING LEASES
The following table presents the Company’s total lease cost. SCHEDULE OF LEASE COST
As of June 30, 2023, maturities of the Company’s operating lease liabilities are as follows: SCHEDULE OF FUTURE LEASE PAYMENTS
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 7. ASSET RETIREMENT OBLIGATIONS Asset retirement obligations reflects the estimated present value of the amount of dismantlement, removal, site reclamation, and similar activities associated with the Company’s oil and gas properties. Changes to the asset retirement obligations are as follows: SCHEDULE OF ASSET RETIREMENT OBLIGATIONS
During the year ended September 30, 2022, the Company had revision of estimates totalling $371,212 primarily due to changes in future cost estimates and retirement dates for its oil and gas assets. Reclamation deposits As of June 30, 2023, the Company held reclamation deposits of $145,000 (September 30, 2022 - $145,000), which are expected to be released after all reclamation work has been completed with regard to its oil and natural gas interests.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 8. DEBT Convertible debenture – Related party As of September 30, 2022, the Company had a debenture loan of $73,000 (CAD$100,000) from the CEO of the Company outstanding. The debenture loan was secured by an interest in all of the Company’s right, title, and interest in all of its oil and gas assets, bore interest at a rate of 12% per annum and had a maturity date of December 20, 2022. The debenture was convertible at the holder’s option into units of the Company at $26.28 (CAD$ ) per unit. Each unit would be comprised of one common share of the Company and one share purchase warrant; each warrant entitled the holder to acquire one additional common share for a period of three yearsat an exercise price of $35.04 (CAD$ ). During the year ended September 30, 2022, the Company repaid $34,709 of the loan (CAD$47,546). In November 2022, the Company repaid the remaining principal loan amount of $38,291 (CAD$52,454). The Company recorded interest of $nil and $1,182 for the three and nine months ended June 30, 2023. The Company recorded interest of $2,597 and $6,285 for the three and nine months ended June 30, 2022. Loan payable In May 2020, the Company opened a Canada Emergency Business Account (“CEBA”) and received a loan of $28,640 (CAD$40,000) from the Canadian Government. The CEBA program was established to provide interest-free loans of up to CAD$60,000 to small businesses to help them cover operating costs during the COVID-19 pandemic. The loan was unsecured and non-interest bearing with a repayment deadline of December 31, 2023. During the year ended September 30, 2022, the Company repaid the loan balance of $23,600 (CAD$30,000) and recognized a gain of $7,800 (CAD$10,000) on the forgiven amount. 9. RELATED PARTY TRANSACTIONS The convertible debenture loan from the CEO of the Company mentioned in Note 8 was repaid during the nine months ended June 30, 2023. SCHEDULE OF BASIC AND DILUTED LOSS PER SHARE
For the three and nine months ended June 30, 2023, stock options and warrants were excluded from the diluted weighted average number of common shares calculation as their effect would have been anti-dilutive. For the three and nine months ended June 30, 2022, stock options and warrants were excluded from the diluted weighted average number of common shares calculation as their effect would have been anti-dilutive.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 11. EQUITY Common stock The Company has authorized an number of common shares with nopar value. At June 30, 2023 and September 30, 2022, the Company had and common shares issued and outstanding, respectively, after giving effect to the 60:1 reverse stock split effective November 2, 2022 and 4:1 reverse stock split effective October 23, 2023. During the nine months ended June 30, 2023, the Company announced a warrant exercise incentive program (the “Program”) whereby the Company amended the exercise prices of 253,966warrants (the “Eligible Warrants”) from $50.40 per share to $11.44 per share if the holders of the Eligible Warrants exercised the Eligible Warrants before June 30, 2023 (the “Program Period”). In addition to the repricing, the Company offered, to each warrant holder who exercised the Eligible Warrants during the Program Period, the issuance of one additional common share purchase warrant for each warrant exercised during the Program Period (each, an “Incentive Warrant”). Each Incentive Warrant entitles the warrant holder to purchase one common share of the Company for a period of 5 years from the date of issuance, at a price of $per Share. On June 30, 2023, the Company issued common shares at a price of $per share from the exercise of the Eligible Warrants pursuant to the Program for gross proceeds of $781,953 (net proceeds of $688,092). In connection with the Program, the Company issued Incentive Warrants. The Company also incurred $62,556 and issued 5,470warrants as a finders’ fee to its investment bank. The finder’s warrants are on the same terms as the Incentive Warrants. The Incentive Warrants and finder’s warrants were valued at $449,005 and $35,919, respectively, using the Black-Scholes option pricing model (assuming a risk-free interest rate of %, an expected life of years, annualized volatility of % and a dividend rate of %). The repricing of the Eligible Warrants is accounted for as a modification under ASC 815-40-35-14 through 18. The effect of the modification is $544,164, measured as the excess of the fair value of the repriced warrants over the fair value of the original warrants immediately before it was modified and the fair value of the incentive warrants issued as an additional inducement to exercise the warrants. The fair values were measured using the Black-Scholes option pricing model (assuming a risk-free interest rate of %, an expected life of years, annualized volatility of % and a dividend rate of %). The Company recognized a deemed dividend of $543,234for the fair value of the Incentive Warrants and the portion of inducement related to the equity-classified warrants. The effect of the repricing of the liability-classified warrants was $930 and was recorded in the statement of loss. The Company also incurred legal and other expenses of $31,305 in connection with the Program. During the year ended September 30, 2022, the Company:
Share-based payments Stock options The Company has a stock option plan (the “Plan”) in place under which it is authorized to grant options to executive officers and directors, employees and consultants. Pursuant to the Plan, the Company may issue aggregate stock options totaling up to 10% of the issued and outstanding common stock of the Company. Further, the Plan calls for the exercise price of each option to be equal to the market price of the Company’s stock as calculated on the date of grant. The options can be granted for a maximum term of years and vest at the discretion of the Board of Directors at the time of grant.
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 11. EQUITY (cont’d…) Share-based payments (cont’d…) Stock option transactions are summarized as follows: SCHEDULE OF STOCK OPTION TRANSACTIONS
The aggregate intrinsic value of options outstanding and exercisable as at June 30, 2023 was $ (September 30, 2022 - $ ). The options outstanding as of June 30, 2023 have exercise prices in the range of $to $and a weighted average remaining contractual life of years. During the nine months ended June 30, 2023 and 2022, the Company recognized share-based payment expense of $ and $ , respectively, for the portion of stock options that vested during the period. The share-based payment expense for the three months ended June 30, 2023 and 2022 was $ and $ , respectively. The following weighted average assumptions were used for the Black-Scholes valuation of stock options granted:
SCHEDULE OF STOCK OPTIONS OUTSTANDING
PERMEX PETROLEUM CORPORATION NOTES TO CONDENSED INTERIM CONSOLIDATED FINANCIAL STATEMENTS THREE AND NINE MONTHS ENDED JUNE 30, 2023 (UNAUDITED) 11. EQUITY (cont’d…) Warrants Warrant transactions are summarized as follows: SCHEDULE OF WARRANTS TRANSACTIONS
As June 30, 2023, the following warrants were outstanding: SCHEDULE OF WARRANTS OUTSTANDING
5,515warrants issued with private placement units during fiscal 2022 have an exercise price denominated in CAD. These warrants were initially valued at $202,009 using the Black-Scholes option pricing model (assuming a risk-free interest rate of %, an expected life of years, annualized volatility of % and a dividend rate of %) and recorded as a warrant liability. The fair value of these warrants were remeasured at each reporting period and a gain on fair value of $178,509was recorded during the year ended September 30, 2022. During the nine months ended June 30, 2023, a gain on fair value of $23,500 was recorded (2022 - $152,869). During the three months ended June 30, 2023, a gain on fair value of $1,066 was recorded (2022 - $72,838). SCHEDULE OF VALUATION OF WARRANTS
Up to 1,900,000 Common Units, Each Consisting of a Common Share and a Warrant to Purchase One Common Share Up to 1,900,000 Pre-funded Units, Each Consisting of a Pre-funded Warrant to Purchase One Common Share and a Warrant to Purchase One Common Share Permex Petroleum Corporation
ThinkEquity , 2023 Through and including , 2023 (the 25th day after the date of this offering), all dealers effecting transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to a dealer’s obligation to deliver a prospectus when acting as an underwriter and with respect to an unsold allotment or subscription. PART II INFORMATION NOT REQUIRED IN PROSPECTUS. ITEM 13. OTHER EXPENSES OF ISSUANCE AND DISTRIBUTION. The following table sets forth the costs and expenses payable by the Company in connection with the issuance and distribution of the securities being registered hereunder.
* All amounts are
ITEM 14. INDEMNIFICATION OF DIRECTORS AND OFFICERS. Business Corporations Act The Company is subject to the provisions of Part 5, Division 5 of the BCBCA. Under Section 160 of the BCBCA, the Company may, subject to Section 163 of the BCBCA:
including, subject to certain limited exceptions, the heirs and personal or other legal representatives of that individual (collectively, an “eligible party”), against all eligible penalties, defined below, to which the eligible party is or may be liable; and
Under Section 161 of the BCBCA, and subject to Section 163 of the BCBCA, the Company must, after the final disposition of an eligible proceeding, pay the expenses actually and reasonably incurred by an eligible party in respect of that proceeding if the eligible party (a) has not been reimbursed for those expenses and (b) is wholly successful, on the merits or otherwise, in the outcome of the proceeding or is substantially successful on the merits in the outcome of the proceeding. Under Section 162 of the BCBCA, and subject to Section 163 of the BCBCA, the Company may pay, as they are incurred in advance of the final disposition of an eligible proceeding, the expenses actually and reasonably incurred by an eligible party in respect of the proceeding, provided that the Company must not make such payments unless the Company first receives from the eligible party a written undertaking that, if it is ultimately determined that the payment of expenses is prohibited under Section 163 of the BCBCA, the eligible party will repay the amounts advanced. Under Section 163 of the BCBCA, the Company must not indemnify an eligible party against eligible penalties to which the eligible party is or may be liable or pay the expenses of an eligible party in respect of that proceeding under Sections 160(b), 161 or 162 of the BCBCA, as the case may be, if any of the following circumstances apply:
If an eligible proceeding is brought against an eligible party by or on behalf of the Company or by or on behalf of an associated corporation, we must not either indemnify the eligible party under Section 160(a) of the BCBCA against eligible penalties to which the eligible party is or may be liable, or pay the expenses of the eligible party under Sections 160(b), 161 or 162 of the BCBCA, as the case may be, in respect of the proceeding. Under Section 164 of the BCBCA, and despite any other provision of Part 5, Division 5 of the BCBCA and whether or not payment of expenses or indemnification has been sought, authorized or declined under Part 5, Division 5 of the BCBCA, on application of the Company or an eligible party, the court may do one or more of the following:
Section 165 of the BCBCA provides that the Company may purchase and maintain insurance for the benefit of an eligible party or the heirs and personal or other legal representatives of the eligible party against any liability that may be incurred by reason of the eligible party being or having been a director or officer of, or holding or having held a position equivalent to that of a director or officer of, the Company or an associated corporation. Company’s Articles Under Part 21.2 of our Articles, and subject to the BCBCA, the Company must indemnify a director, former director or alternative director of the Company and his or her heirs and legal personal representatives against all eligible penalties to which such person is or may be liable, and the Company must, after the final disposition of an eligible proceeding, pay the expenses actually and reasonably incurred by such person in respect of that proceeding. Each director and alternate director is deemed to have contracted with the Company on the terms of the indemnity contained in the Company’s Articles. Under Part 21.3 of the Company’s Articles, and subject to any restrictions in the BCBCA, the Company may agree to indemnify and may indemnify any person. Under Part 21.4 of the Company’s Articles, the failure of a director, alternate director or officer of the Company to comply with the BCBCA or the Company’s Articles or, if applicable, any former Companies Act or former Articles, does not invalidate any indemnity to which he or she is entitled under the Company’s Articles. Under Part 21.5 of the Company’s Articles, the Company may purchase and maintain insurance for the benefit of any person (or his or her heirs or legal personal representatives) who:
against any liability incurred by him or her as such director, alternate director, officer, employee or agent or person who holds or held such equivalent position. ITEM 15. RECENT SALES OF UNREGISTERED SECURITIES. The following is a summary of transactions during the three years preceding this offering, involving offers and sales of our securities which took place outside the United States, unless otherwise stated, and were not registered under the Securities Act. 2023 On June 30, 2023, we completed an early warrant exercise program whereby we amended the exercise price of an aggregate of
2022
On March 28 and 29, 2022, the Company closed a brokered private placement of an aggregate of
2021 On June 16, 2021, the Company issued On September 30, 2021, the Company issued On October 7, 2021, the Company granted On November 4, 2021, the Company completed a non-brokered private placement of 2020 On November 18, 2020, the Company issued On March 16, 2020, the Company granted ten year options to purchase up to In February 2020, the Company issued a secured convertible debenture in the principal amount of $75,000 (C$100,000) to the Chief Executive Officer and President of the Company. The debenture is secured by an interest in all of the Company’s right, title, and interest in all of its oil and gas assets, matures no later than August 20, 2022 or an earlier date at the request of the holder thereof upon 30 days written notice, and bears interest at a rate of 12% per annum, payable on maturity. The debenture is convertible at the holder’s option into units of the Company at
ITEM 16. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES. (a) Exhibits * Filed herewith. ** Previously filed. *** To be filed by amendment. + Indicates management contract or compensatory plan or arrangement. (b) Financial Statement Schedules Schedules have been omitted because the information required to be set forth therein is not applicable or is shown in the consolidated financial statements or the notes thereto. ITEM 17. UNDERTAKINGS. The undersigned registrant hereby undertakes: (1) To file, during any period in which offers or sales are being made, a post-effective amendment to this Registration Statement: (i) To include any prospectus required by Section 10(a)(3) of the Securities Act; (ii) To reflect in the prospectus any facts or events arising after the effective date of the Registration Statement (or the most recent post-effective amendment thereof) which, individually or in the aggregate, represent a fundamental change in the information set forth in the Registration Statement. Notwithstanding the foregoing, any increase or decrease in volume of securities offered (if the total dollar value of securities offered would not exceed that which was registered) and any deviation from the low or high end of the estimated maximum offering range may be reflected in the form of prospectus filed with the Commission pursuant to Rule 424(b) if, in the aggregate, the changes in volume and price represent no more than 20% change in the maximum aggregate offering price set forth in the “Calculation of Registration Fee” table in the effective Registration Statement; and (iii) To include any material information with respect to the plan of distribution not previously disclosed in the Registration Statement or any material change to such information in the Registration Statement. (2) That, for the purpose of determining any liability under the Securities Act, each such post-effective amendment shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof. (3) To remove from registration by means of a post-effective amendment any of the securities being registered which remain unsold at the termination of the offering. (4) That, for the purpose of determining liability under the Securities Act of 1933 to any purchaser, if the registrant is subject to Rule 430C, each prospectus filed pursuant to Rule 424(b) as part of a registration statement relating to an offering, other than registration statements relying on Rule 430B or other than prospectuses filed in reliance on Rule 430A, shall be deemed to be part of and included in the registration statement as of the date it is first used after effectiveness. Provided, however, that no statement made in a registration statement or prospectus that is part of the registration statement or made in a document incorporated or deemed incorporated by reference into the registration statement or prospectus that is part of the registration statement will, as to a purchaser with a time of contract of sale prior to such first use, supersede or modify any statement that was made in the registration statement or prospectus that was part of the registration statement or made in any such document immediately prior to such date of first use. (5) That, for the purpose of determining any liability under the Securities Act, each post-effective amendment that contains a form of prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof. (6) That, for the purpose of determining liability of the registrant under the Securities Act to any purchaser in the initial distribution of the securities, the undersigned registrant undertakes that in a primary offering of securities of the undersigned registrant pursuant to this registration statement, regardless of the underwriting method used to sell the securities to the purchaser, if the securities are offered or sold to such purchaser by means of any of the following communications, the undersigned registrant will be a seller to the purchaser and will be considered to offer or sell such securities to such purchaser:
Insofar as indemnification for liabilities arising under the Securities Act The undersigned registrant hereby undertakes to provide to the underwriter at the closing specified in the underwriting agreements certificates in such denominations and registered in such names as required by the underwriter to permit prompt delivery to each purchaser.
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, as amended, the registrant certifies that it has reasonable grounds to believe that it meets all of the requirements for filing on this Amendment No. 8 to Form S-1 and has duly caused this Registration Statement to be signed on its behalf by the undersigned, thereunto duly authorized, in Dallas, Texas on the
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