SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	Dec. 31, 2022
Accounting Policies [Abstract]
Basis of Measurement [Policy Text Block]	Basis of Measurement The preparation of financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect reported amounts of assets, liabilities, revenues and expenses, as well as the disclosure of contingent assets and liabilities in the financial statements. In determining these estimates, management makes subjective and complex judgments that may require assumptions about matters that are inherently uncertain. The estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognized in the period in which the estimate is revised if the revision affects only that period, or in the period of the revision and future periods if the revision affects both current and future periods. Estimates and assumptions that, in the opinion of the Company’s management, are significant include the estimation of oil and natural gas reserves and depletion (Note 2 below), the redemption value of redeemable non-controlling interests (Note 2 below and Note 9), determination of whether long-lived assets are impaired (Note 2 below), valuation of asset retirement obligations (Note 2 below and Note 6), and deferred tax assets/liabilities (Note 2 below and Note 15). The Company bases its estimates and judgments on historical experience and on various other assumptions and information believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be predicted with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained, or if the Company’s operating environment changes. Actual results may differ from the estimates and assumptions used in the preparation of these financial statements.
Going Concern [Policy Text Block]	Going Concern The financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates continuity of operations, realization of assets, and liquidation of liabilities in the normal course of business. As at December 31, 2022 the Company had a working capital deficit of $162,980,101, reflecting a significant increase in outstanding accounts payable and accrued liabilities as well as borrowings, due to the Company’s increased capital expenditures on oil and natural gas properties. As a result, the Company does not currently have the cash resources to meet its current liabilities for the next twelve months. These factors raise substantial doubt about the Company’s ability to continue as a going concern. The Company’s ability to continue as a going concern is dependent on its ability to generate sufficient cash flows from operations, as well as its ability to obtain financing via an asset sale and/or the issuances of debt and/or equity in the short term. While the Company believes it has sufficient forecasted funds to meet foreseeable obligations, there can be no assurance that the Company will be successful in its efforts to raise additional funds in the short term and its ability to generate sufficient operating cash flows. Due to these factors, the Company may be unable to continue as a going concern. The financial statements do not include any adjustments related to the recoverability and classification of recorded asset amounts or the amounts and classification of liabilities that might be necessary should the Company be unable to continue as a going concern, and such adjustments could be material.
Basis of Consolidation [Policy Text Block]	Basis of Consolidation Subsidiaries The financial statements include the accounts of the Company and its consolidated subsidiaries, after the elimination of intercompany transactions and balances. The Company consolidates all entities that it controls either through a majority voting interest or as the primary beneficiary of variable interest entities ("VIEs"). The Company evaluates (1) whether it holds a variable interest in an entity, (2) whether the entity is a VIE, and (3) whether the Company's involvement would make it the primary beneficiary. The assessment of whether the entity is a VIE is generally performed qualitatively, which requires judgment. These judgments include: (a) determining whether the equity investment at risk is sufficient to permit the entity to finance its activities without additional subordinated financial support, (b) evaluating whether the equity holders, as a group, have the characteristics of a controlling financial interest, (c) determining whether two or more parties' equity interests should be aggregated, (d) determining whether the equity investors have proportionate voting rights to their obligations to absorb losses or rights to receive returns from the entity, and (e) if disproportionate voting rights are identified, whether substantially all of the investee's activities are on behalf of an investor that has disproportionately few voting rights. Significant judgements involve the analysis of the risks and rewards that the VIE's operations generate and the nature of the Company's involvement with and interest in the VIE, including the form of the Company's ownership interest, representation in an entity's governance, and ability to participate in making decisions. For entities that are determined to be VIEs, the Company consolidates those entities where it has concluded it is the primary beneficiary. The primary beneficiary is defined as the variable interest holder with (a) the power to direct the activities of a VIE that most significantly impact the entity's economic performance and (b) the obligation to absorb losses or the right to receive benefits from the entity that could potentially be significant to the VIE. In evaluating whether the Company is the primary beneficiary, the Company evaluates its economic interests in the entity held either directly or indirectly by the Company, and its ability to control the VIEs through arrangements such as general partnership interests or contracts. The Company's consolidated VIEs consist of its controlled subsidiary, Origination, as its control over Origination is contractually provided and not granted via the equity interest. Origination, through its subsidiaries, holds the Company's main operations, including external financing. Some of Origination's drilling programs are structured through limited partnerships (the "Development Partnerships"), which are consolidated VIEs of Origination (see Note 9). Under the contractual agreements with the VIEs, the Company has the power to direct activities of the VIEs and can have assets transferred out of the VIEs under its control. Therefore, the Company considers that there is no asset in any of the VIEs that can be used only to settle obligations of the VIE, except for certain assets that are designated as collateral for long term debt (Note 7). If an entity is determined to not be a VIE, the voting interest entity model is applied, where an investor holding the majority voting rights consolidates the entity. Ownership interests in subsidiaries represented by other parties that do not control the entity are presented in the consolidated financial statements as activities and balances attributable to noncontrolling interests. Joint Arrangements A portion of the Company's oil and natural gas business activities involve jointly controlled assets and are conducted under joint operating agreements. These consolidated financial statements reflect only the Company's proportionate share of the joint operation's controlled assets and liabilities it has incurred, its share of any liabilities jointly incurred with other joint interest partners, income from the sale or use of its share of the joint operation's output, together with its share of expenses incurred by the joint operation and any expenses it incurs in relation to its interest and its share of production in such activities.
Segment Reporting [Policy Text Block]	Segment Reporting The Company operates in a single operating and reportable segment. Operating segments are defined as components of a public entity for which separate financial information is regularly reviewed by the chief operating decision maker in deciding how to allocate resources and assess performance. The Company's chief operating decision maker allocates resources and assesses performance based upon financial information at the Company level. The Company's operations are primarily conducted in, and its assets are primarily located in, the United States of America. The Company's revenues are entirely generated in the United States of America.
Functional and Presentation Currency [Policy Text Block]	Functional and Presentation Currency These financial statements are presented in US dollars. The functional currency of the Company and its individual subsidiaries is the US dollar, which represents the primary economic environment in which the entities operate. Foreign currency transactions are those transactions whose terms are denominated in a currency other than the functional currency. Transactions denominated in foreign currencies are translated to the functional currency using the exchange rate prevailing at the date of the transactions. Monetary assets and liabilities denominated in foreign currencies are translated to the functional currency using the exchange rate in effect as at the balance sheet date. Exchange gains and losses resulting for the remeasurement of monetary assets and liabilities are included in general and administrative expenses in the consolidated statements of operations and comprehensive income (loss) in the period in which they arise.
Cash and Cash Equivalents [Policy Text Block]	Cash and Cash Equivalents Cash and cash equivalents include short-term investments with a term to maturity of three months or less when purchased (Note 18).
Restricted Cash [Policy Text Block]	Restricted Cash Cash and cash equivalents that are restricted as to the withdrawal or usage, in accordance with specific arrangements, are presented as restricted cash. The amount of restricted cash as of December 31, 2022 is $3,375,395 (December 31, 2021 - $nil), reflecting the interest reserve account maintained in connection with the asset backed securitization facility (Note 7).
Accounts Receivable, Net [Policy Text Block]	Accounts Receivable, Net The accounts receivable are primarily receivables from crude oil, natural gas, and natural gas liquids customers and joint interest owners. Oil and natural gas sales are normally collected by the Company between 30 and 60 days from deliveries. Joint interest receivables are typically collected within 30 to 90 days of the joint interest bill being issued to the partner. Accounts receivable, net are recorded at amortized cost. Management evaluates all accounts periodically and an allowance is established based on the best facts available. Management considers historical collection data, accounts receivable aging trends, other operational trends and reasonable forecasts to estimate the collectability of receivables. The Company's accounts receivable are subject to normal industry credit risk (Note 18).
Derivatives [Policy Text Block]	Derivatives The Company has entered into certain financial risk management contracts in order to manage the exposure to market risks from fluctuations in commodity prices and interest rates. The Company considers all risk management contracts to be economic hedges, but has not designated its financial risk management contracts as accounting hedges and, therefore, has not applied hedge accounting. As a result, all financial risk management contracts are measured at fair value with changes in fair value recognized in income (Note 17). Transaction costs are recognized in the consolidated statements of operations and comprehensive income (loss) as incurred. In the consolidated balance sheets, the fair values of the derivative instruments are presented as current and non-current assets or liabilities depending on the timing of settlements and the resulting cash flows associated with the instruments. Fair value amounts related to cash flows occurring beyond one year are classified as non-current (Note 18).
Oil and Natural Gas Properties, Net [Policy Text Block]	Oil and Natural Gas Properties, Net Oil and Natural Gas Properties The Company uses the full-cost method of accounting for its oil and natural gas properties. Under this method, all costs associated with the acquisition, exploration and development of oil and natural gas properties and reserves, including unproved and unevaluated property costs, are capitalized as incurred and accumulated in a single cost center representing the Company's activities, which are undertaken exclusively in the United States. Such costs include lease acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties, costs of drilling both productive and non-productive wells, and general and administrative expenses directly related to acquisition, exploration and development activities, but does not include any costs related to production, selling or general corporate administrative activities. Sales of oil and natural gas properties are accounted for as adjustments to net capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between net capitalized costs and proved reserves of oil and gas. All costs related to production activities and maintenance and repairs are expensed as incurred. Significant workovers that increase the properties' reserves are capitalized. In the years ended December 31, 2022 and 2021, there were no property sales that resulted in a significant alteration. Depletion Capitalized costs of oil and natural gas properties are amortized using the unit-of-production method. Under this method, depletion is calculated at the end of each period by multiplying total production for the period by a depletion rate. The depletion rate is determined by dividing the total unamortized cost base plus estimates of future development costs by estimates of proved reserves quantities. Unproved and unevaluated property costs and related carrying costs are excluded from the depletion base until the properties associated with these costs are considered proved or impaired. The Company reviews its unproved and unevaluated properties at the end of each quarter to determine whether the costs incurred should be transferred to the full cost pool and thereby subject to amortization. Upon impairment, which includes leases that have expired or have been deemed uneconomic, the costs of the unproved properties are immediately included in the depletion base. The determination of depletion is significantly impacted by the proved reserves volumes and future development costs. Relative volumes of reserves and production are converted at the energy equivalent conversion ratio of six thousand cubic feet of natural gas to one barrel of oil. Impairment Under the full cost method of accounting, the Company is required to perform a ceiling test each quarter. The test determines a limit, or ceiling, on the net capitalized costs of oil and natural gas properties. The net capitalized costs are limited to the lower of unamortized costs less related deferred income taxes or the cost center ceiling. The cost center ceiling is defined as the sum of: (a) the present value, discounted at 10%, of future net revenues of proved oil and natural gas reserves, reduced by the estimated costs of developing these reserves, plus (b) unproved and unevaluated property costs not being amortized, plus (c) the lower of cost or estimated fair value of unproved and unevaluated properties included in the costs being amortized, if any, less (d) any income tax effects related to the properties involved. Any excess of the Company's net capitalized costs above the cost center ceiling is expensed as a full-cost ceiling impairment. The Company's derivative instruments are not considered in the ceiling test computations as the Company does not designate these instruments as hedges for accounting purposes. The estimated present value of after-tax future net cash flows from proved oil and natural gas reserves is highly dependent on the quantities of proved reserves, the estimation of which requires substantial judgement. The associated commodity prices and the applicable discount rate used in these estimates are in accordance with guidelines established by the United States Securities and Exchange Commission. Under these guidelines, oil and natural gas reserves are estimated using then-current operating and economic conditions, with no provision for price and cost changes in future periods except by contractual arrangements. Future net revenues are calculated using prices that represent the arithmetic averages of the first-day-of-the-month oil and natural gas prices for the previous 12-month period, and a 10% discount factor is used to determine the present value of future net revenues. For the period from January through December 2022, these average oil and natural gas prices were $94.49 per Bbl and $6.25 per MMBtu, respectively. For the period from January through December 2021, these average oil and natural gas prices were $66.55 per Bbl and $3.64 per MMBtu, respectively. In estimating the present value of after-tax future net cash flows from proved oil and natural gas reserves, the average oil prices were further adjusted by property for quality, transportation and marketing fees and regional price differentials, and the average natural gas prices were further adjusted by property for energy content, transportation and marketing fees and regional price differentials. During the years ended December 31, 2022 and 2021, the Company's full-cost ceiling exceeded the net capitalized costs less related deferred income taxes. As a result, the Company recorded no impairment to its net capitalized costs for those periods. As a non-cash item, the full-cost ceiling impairment impacts the accumulated depletion and the net carrying value of the Company’s assets on its consolidated balance sheets, as well as the corresponding shareholders’ deficiency, but it has no impact on the Company’s net cash flows as reported. Changes in oil and natural gas production rates, oil and natural gas prices, reserves estimates, future development costs and other factors will determine the Company’s actual ceiling test computation and impairment analyses in future periods. Other Impairment Estimates Unproved and unevaluated properties are assessed periodically to determine whether they have been impaired, based on the Company's future development plans, the probability of successful development of properties and the length of time that the Company expects to hold the properties, amongst other factors. Upon impairment, the costs of the unproved and unevaluated properties are immediately included in the depletion base. Exploratory dry holes are included in the depletion base immediately upon determination that the well is not productive. During the year ended December 31, 2022 and 2021, no unproved and unevaluated properties were impaired and transferred to be included in the depletion base as part of evaluated properties. Reserves The assessment of reported recoverable quantities of proved reserves includes estimates regarding production volumes, commodity prices, remediation costs, timing and amount of future development costs, and production, transportation and marketing costs for future cash flows. It also requires interpretation of geological and geophysical models in anticipated recoveries. The economical, geological and technical factors used to estimate reserves may change from period to period. Changes in reported reserves can impact the carrying values of the Company's oil and natural gas properties, the calculation of depletion and depreciation, and the provision for asset retirement obligations. The reserve assessment was completed by an external third-party engineering firm for the years ended December 31, 2022 and 2021 and reserves are internally updated for interim periods.
Asset Retirement Obligations [Policy Text Block]	Asset Retirement Obligations The Company recognizes asset retirement obligations ("ARO") arising from regulatory, contractual or other legal requirements to perform certain property and asset reclamation activities at the end of the respective asset life when the fair value of this obligation is determinable. These obligations consist of estimated future costs associated with the plugging and abandonment of natural gas and oil wells, and land restoration in accordance with applicable local, state and federal laws. The Company estimates the expected cash flows associated with the obligation and discounts the amounts using a credit-adjusted risk-free interest rate. This discounted fair value of the ARO liability is recognized in the period in which it is incurred, with the associated asset retirement cost capitalized as part of the carrying cost of the related natural gas and oil asset in property, plant and equipment, net and depleted as the reserves are produced. In the estimation of the initial fair value of an ARO, the Company uses assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation, technical assessments of the assets, estimated amounts and timing of settlements including reserve lives, discount rates, and inflation rates. Given the significance of the unobservable nature of a number of the inputs, this measurement is considered Level 3 on the fair value hierarchy (Note 17). In periods subsequent to the initial measurement of an ARO, period-to-period changes are recognized in the liability resulting from the passage of time and revisions to either the timing or the amount of the original estimate of undiscounted cash flows. To the extent future revisions to these assumptions impact the present value of the existing ARO liability, a corresponding adjustment is made to the related asset. Accretion, reflecting the increases in the ARO liability due to the passage of time is recognized as part of operating expenses within the consolidated statements of operations and comprehensive income (loss) (Note 6).
Leases [Policy Text Block]	Leases The Company assesses whether a contract is or contains a lease, at the inception of a contract. A contract is, or contains, a lease if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. The Company recognizes a right-of-use ("ROU") asset and a corresponding lease liability with respect to lease arrangements in which it is the lessee, except for short-term leases (defined as leases with a lease term of 12 months or less). For such short-term leases, the Company recognizes the lease payments as an operating expense on a straight-line basis over the term of the lease unless another systematic basis is more representative of the time pattern in which economic benefits from the leased asset are consumed. The Company also made the accounting policy election to not separate lease and non-lease components for its real estate leases. The lease liability is initially measured at the present value of the unpaid lease payments at the commencement date, discounted by using the rate implicit in the lease. If this rate cannot be readily determined, the Company uses its incremental borrowing rate. Subsequently, the lease liability is measured using the effective interest method, by increasing the carrying amount to reflect accretion on the lease liability and by reducing the carrying amount to reflect the lease payments made. The ROU asset is initially measured at cost, which comprises the initial amount of the lease liability adjusted for lease payments made at or before the lease commencement date, plus any initial direct costs incurred less any lease incentives received. For operating leases, the Company records the amortization of the ROU assets and the accretion of the lease liabilities as a single lease cost on a straight-line basis over the lease term. The measurement of the lease liabilities and ROU assets requires the use of judgment and estimates which are applied in determining whether an arrangement contains a lease, determining the lease term, appropriate discount rate, and whether there are any indicators of impairment for ROU assets.
Revenue from Contracts with Customers [Policy Text Block]	Revenue from Contracts with Customers The Company enters into contracts with customers to sell its oil, natural gas and natural gas liquids. Revenue from these contracts is recognized when the Company's performance obligations are satisfied, which generally occurs with the transfer of the control to the customer, and when collectability is reasonably assured. The transfer of control usually occurs when the product is physically transferred at the delivery point agreed upon in the contract and legal title to the product passes to the customer (often at terminals, pipelines, or other transportation methods). The Company evaluates creditworthiness on an individual customer basis prior to entering into a sales contract and throughout the contract duration (Note 18). The sales contracts range from short term to long term contracts that are variable-priced and based on actual quantities delivered each period. The transaction price includes variable consideration as product pricing is based on published market prices and adjusted for contract specified differentials such as quality, energy content and transportation. Determining the variable consideration does not require significant judgment and the Company engages third party sources to validate the estimates. The Company does not disclose the value of unsatisfied performance obligations under its contracts with customers as it applies the practical expedient in accordance with ASC 606 – Revenue from Contracts with Customers (“ASC 606”). The expedient applies to variable consideration that is recognized as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. The Company evaluates its arrangements with third parties and partners to determine if the Company acts as the principal or as an agent. In making this evaluation, the Company considers if it obtains control of the product delivered or services provided, which is indicated by the Company having the primary responsibility for the delivery of the product or rendering of the service, having the ability to establish prices or having inventory risk. If the Company acts in the capacity of an agent rather than as a principal in a transaction, then the revenue is recognized on a net-basis. Revenue is recognized net of royalties due to third parties in an amount that reflects the consideration the Company expects to receive in exchange for those products.
Share Based Compensation [Policy Text Block]	Share Based Compensation The Company grants share purchase options, which are classified as equity settled awards. The fair value of each option granted by the Company are estimated using the Black-Scholes option pricing model and are recognized into general and administrative expense over the vesting period of the options. The Company has also issued restricted share units (“RSUs”) and deferred share units (“DSUs”) which are both accounted for as equity classified awards. The Company’s RSUs and DSUs grants are valued using the intrinsic value method, utilizing the closing share price on the day before the grant and are recognized into general and administrative expense over the vesting period for each grant (Note 12). In all cases for these awards, the Company estimates forfeitures and updates this estimate over the vesting period of the awards.
Income Taxes [Policy Text Block]	Income Taxes Income tax expense comprises current and deferred tax. The expense is recognized in net income (loss) except to the extent that it relates to a business combination, or items recognized directly in equity or in other comprehensive income (loss). Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Each reporting period, the Company reviews its deferred tax assets for the possibility they will not be realized. A valuation allowance will be recorded if it is more likely than not that a deferred tax asset will not be realized. The benefits of uncertain tax positions that the company has taken or expects to take in its income tax returns are recognized in the financial statements if management concludes that it is more likely than not that the position will be sustained with the tax authorities. Significant judgment is required in the accounting for income tax contingencies and tax disputes because the outcomes are often difficult to predict. The Company did not have any uncertain tax positions during the periods presented in these financial statements. Interest and penalties are recognized in finance expense and income tax expense, respectively. For the fiscal years ended December 31, 2022 and 2021, the Company did not incur interest and penalties related to income taxes.
Non-Controlling Interests [Policy Text Block]	Non-Controlling Interests Non-controlling interests ("NCI") represent ownership interest in consolidated subsidiaries which are not owned, directly or indirectly, by the Company. The portion of equity not owned by the Company in such entities is reflected as NCI within the equity section of the consolidated balance sheets, and the share of income/(loss) attributable to NCI is shown as a component of net income/(loss) in the consolidated statements of operations and comprehensive income (loss). Changes to the parent company's ownership that do not result in a loss of control are accounted for as equity transactions.
Redeemable Non-controlling Interests [Policy Text Block]	Redeemable Non-controlling Interests Non-controlling interests with redemption features that are not solely within the control of the Company are considered redeemable non-controlling interests. The Company's redeemable non-controlling interests ("Redeemable NCI") reflects the development partnership units that are not held by the Company either directly or indirectly, and which contain certain redemption rights, as described in Note 9. The Redeemable NCI is classified in temporary equity that is reported between liabilities and shareholders’ deficiency on the consolidated balance sheets and is initially recognized at its issuance date fair value. Subsequently, the Redeemable NCI is adjusted each reporting period for the net income (or loss) attributable to the Redeemable NCI interests. Further measurement adjustments are made to adjust the Redeemable NCI to the higher of the redemption value or the carrying value each reporting period. The measurement adjustments to the redemption value are recognized through accumulated deficit and are reflected in the attribution of net income (loss) between the NCI holders, the common shareholders of the Company and the Redeemable NCI holders, such that an increase in the redemption value over the carrying value would increase the net income attributed to the Redeemable NCI. The redemption value is calculated based on future net present values of the oil and gas reserves of the related development partnership, subject to a fixed discount rate.
Adoption of New Accounting Standards [Policy Text Block]	Adoption of New Accounting Standards Accounting Standards Update ("ASU") 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes was issued in December 2019. ASU 2019-12 simplifies the accounting for income taxes by removing certain exceptions and by clarifying and amending existing guidance. The Company adopted ASU 2019-12 effective January 1, 2021. The adoption of ASU 2019-12 did not have a material impact on the Company's operating results, financial position or disclosures. ASU 2020-06, Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity's Own Equity was issued in August 2020. The update simplifies the accounting for certain financial instruments with both liability and equity characteristics and is effective for smaller reporting companies for fiscal years beginning after December 15, 2023, with early adoption permitted. The Company early adopted ASU 2020-06 effective January 1, 2021. The adoption of ASU 2020-06 did not have a material impact on the Company's operating results, financial position or disclosures. ASU 2020-04, Reference Rate Reform (Topic 848), was issued in March 2020 in response to the risk of cessation of the London Interbank Offered Rate (LIBOR). This amendment provides optional expedients and exceptions for applying generally accepted accounting principles to contracts, hedging arrangements, and other transactions that reference LIBOR. ASU 2020-04 was effective upon issuance for all entities and through December 31, 2022. In December 2022, the FASB issued ASU 2022-06 - Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 which is effective on issuance and defers the sunset date of Topic 848 from December 31, 2022, to December 31, 2024, after which entities will no longer be permitted to apply the relief in Topic 848. The adoption of ASU 2022-06 did not have a material impact on the Company's operating results, financial position or disclosures.
Future Accounting Standard Changes [Policy Text Block]	Future Accounting Standard Changes ASU 2021-08 - Business Combinations (Topic 805): Accounting for Contract Assets and Contract Liabilities from Contracts with Customers, was issued in October 2021. The update, which can be adopted retrospectively or prospectively, requires the application of Topic 606 to recognize and measure contract assets and contract liabilities in a business combination. The amendments in this update are effective for public business entities for fiscal years beginning after December 15, 2022. The Company expects to adopt this ASU prospectively for future business combinations, with no impact at the time of adoption. The Company considers the applicability and the impact of all ASUs. ASUs not discussed above were assessed and determined to be either not applicable, the effects of adoption are not expected to be material or are clarifications of ASUs previously disclosed.