Significant Accounting Policies	12 Months Ended
Jul. 31, 2020
Accounting Policies [Abstract]
Significant Accounting Policies	Basis of presentation The accounting and reporting policies of the Company conform to U.S. generally accepted accounting principles (US GAAP). Use of estimates The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results may differ from those estimates. Cash and Cash Equivalents The Company considers all cash accounts, which are not subject to withdrawal restrictions or penalties, and all highly liquid debt instruments purchased with a maturity of three months or less as cash and cash equivalents. The carrying amount of financial instruments included in cash and cash equivalents approximates fair value because of the short maturities for the instruments held. The Company had no cash equivalents as of July 31, 2020 and 2019. Principles of Consolidation The accompanying consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, Kathis Energy LLC, Kathis Energy Fund 1, LLP and Enmex Operations LLC. All financial information has been prepared in conformity with accounting principles generally accepted in the United States of America. All significant intercompany transactions and balances have been eliminated. Revenue Recognition Revenue is recognized when a customer obtains control of promised goods or services and is recognized in an amount that reflects the consideration that an entity expects to receive in exchange for those goods or services. In addition, the standard requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The amount of revenue that is recorded reflects the consideration that the Company expects to receive in exchange for those goods. The Company applies the following five-step model in order to determine this amount: (i) identification of the promised goods in the contract; (ii) determination of whether the promised goods are performance obligations, including whether they are distinct in the context of the contract; (iii) measurement of the transaction price, including the constraint on variable consideration; (iv) allocation of the transaction price to the performance obligations; and (v) recognition of revenue when (or as) the Company satisfies each performance obligation. The Company only applies the five-step model to contracts when it is probable that the entity will collect the consideration it is entitled to in exchange for the goods or services it transfers to the customer. Once a contract is determined to be within the scope of ASC 606 at contract inception, the Company reviews the contract to determine which performance obligations the Company must deliver and which of these performance obligations are distinct. The Company recognizes as revenues the amount of the transaction price that is allocated to the respective performance obligation when the performance obligation is satisfied or as it is satisfied. Generally, the Company’s performance obligations are transferred to customers at a point in time, typically upon delivery. The Company receives a majority of its revenue from oil and gas sales from the J. E Richey lease located in Coleman County, Texas. Revenue is recognized when received. For the year ended July 31, 2020 and 2019, we recognized 100% and 62.4% of revenue, respectively, from crude oil sales on our Richey Lease. Accounts Receivable Revenues that have been recognized but not yet received are recorded as accounts receivable. Losses on receivables will be recognized when it is more likely than not that a receivable will not be collected. An allowance for estimated uncollectible amounts will be recognized to reduce the amount of receivables to its net realizable value. The allowance for uncollectible amounts is evaluated quarterly. Long Lived Assets Property consists of mineral rights purchases as stipulated by underlying agreements and payments made for oil and gas exploration rights. Our company assesses the impairment of long-lived assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable. When we determine that the carrying value of long-lived assets may not be recoverable based upon the existence of one or more indicators of impairment and the carrying value of the asset cannot be recovered from projected undiscounted cash flows, we record an impairment charge. Our company measures any impairment based on a projected discounted cash flow method using a discount rate determined by management to be commensurate with the risk inherent in the current business model. Significant management judgment is required in determining whether an indicator of impairment exists and in projecting cash flows. Mineral Property Acquisition and Exploration Costs Mineral property acquisition and exploration costs are expensed as incurred until such time as economic reserves are quantified. Cost of lease, exploration, carrying and retaining unproven mineral lease properties are expensed as incurred. We have chosen to expense all mineral exploration costs as incurred given that it is still in the exploration stage. Once our company has identified proven and probable reserves in its investigation of its properties and upon development of a plan for operating a mine, it would enter the development stage and capitalize future costs until production is established. When a property reaches the production stage, the related capitalized costs will be amortized over the estimated life of the probable-proven reserves. When our company has capitalized mineral properties, these properties will be periodically assessed for impairment of value and any diminution in value. Oil and Gas Properties The Company follows the successful efforts method of accounting for its oil and gas properties. Under this method of accounting, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense. The costs of development wells are capitalized whether those wells are successful or unsuccessful. Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts. Depletion and amortization of oil and gas properties are computed on a well-by-well basis using the units-of-production method. Although the Company has recognized minimal levels of production and revenue, none of its property have proved reserves. Therefore, the Company’s properties are designated as unproved properties. Unproved property costs are not subject to amortization and consist primarily of leasehold costs related to unproved areas. Unproved property costs are transferred to proved properties if the properties are subsequently determined to be productive and are assigned proved reserves. Proceeds from sales of partial interest in unproved leases are accounted for as a recovery of cost without recognizing any gain until all cost is recovered. Unproved properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks or future plans to develop acreage. Asset Retirement Obligation Accounting Standards Codification (“ASC”) Topic 410, Asset Retirement and Environmental Obligations (“ASC 410”) requires an entity to recognize the fair value of a liability for an asset retirement obligation in the period in which it is incurred. The net estimated costs are discounted to present values using credit-adjusted, risk-free rate over the estimated economic life of the oil and gas properties. Such costs are capitalized as part of the related asset. The asset is depleted on the equivalent unit-of-production method based upon estimates of proved oil and natural gas reserves. The liability is periodically adjusted to reflect (1) new liabilities incurred, (2) liabilities settled during the period, (3) accretion expense and (4) revisions to estimated future cash flow requirements. To date, the Company has very few operating wells. Currently, the Company has one working well. Because there is only one active well on the Ritchie Lease with a 24% working interest, the Company estimates the asset retirement obligation to be trivial and has not recorded an ARO liability. Basic and Diluted Earnings Per Share Net income (loss) per common share is computed pursuant to ASC 260-10-45, Earnings per Share—Overall—Other Presentation Matters. Basic net income (loss) per common share is computed by dividing net income (loss) by the weighted average number of shares of common stock outstanding during the period. Diluted net income (loss) per common share is computed by dividing net income (loss) by the weighted average number of shares of common stock and potentially outstanding shares of common stock during the period. For the year ended July 31, 2020, the Company had 3,031,958 of potentially dilutive shares. The shares consisted of common shares and warrants from convertible debt of 1,687,972 and 843,986, respectively, and an additional 5000,000 warrants. For the year ended July 31, 2019, the Company had 4,768,408 of potentially dilutive shares. The shares consisted of common shares and warrants from convertible debt of 1,602,272 and 801,136, respectively, and an additional 2,365,000 warrants. The diluted loss per share is the same as the basic loss per share for the years ended July 31, 2020 and 2019, as the inclusion of any potential shares would have had an antidilutive effect due to our loss from operations. Recently issued accounting pronouncements In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses, and also issued subsequent amendments to the initial guidance, ASU 2018-19, ASU 2019-04, ASU 2019-05, and ASU 2019-11 (collectively, Topic 326), to introduce a new impairment model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses (CECL). Under Topic 326, an entity is required to estimate CECL on available-for-sale (AFS) debt securities only when the fair value is below the amortized cost of the asset and is no longer based on an impairment being “other-than-temporary”. Topic 326 also requires the impairment calculation on an individual security level and requires an entity use present value of cash flows when estimating the CECL. The credit-related losses are required to be recognized through earnings and non-credit related losses are reported in other comprehensive income. In April 2019, the FASB further clarified the scope of Topic 326 and addressed issues related to accrued interest receivable balances, recoveries, variable interest rates and prepayment. The new guidance will require modified retrospective application to all outstanding instruments, with a cumulative effect adjustment recorded to opening retained earnings as of the beginning of the first period in which the guidance becomes effective. The amendments in this Update for the Company are effective for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. Early adoption is permitted in any interim period after the issuance of this of this Update. The Company is evaluating the impact of the adoption of the new standard on its financial statement and disclosures. In August 2018, the FASB issued ASU 2018-13 to improve the effectiveness of disclosures about fair value measurements required under ASC 820. The ASU modifies the disclosure objective paragraphs of ASC 820 to eliminate (1) “at a minimum” from the phrase “an entity shall disclose at a minimum” and (2) other similar “open ended” disclosure requirements to promote the appropriate exercise of discretion by entities. The disclosure objective added in ASC 820-10-50-1C states: The objective of the disclosure requirements in this Subtopic is to provide users of financial statements with information about assets and liabilities measured at fair value in the statement of financial position or disclosed in the notes to financial statements: a) the valuation techniques and inputs that a reporting entity uses to arrive at its measures of fair value, including judgments and assumptions that the entity makes, b) the uncertainty in the fair value measurements as of the reporting date, and c) how changes in fair value measurements affect an entity’s performance and cash flows. The new ASU is effective for all entities for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted. The Company has implemented all new accounting pronouncements that are in effect. These pronouncements did not have any material impact on the financial statements unless otherwise disclosed, and the Company does not believe that there are any other new accounting pronouncements that have been issued that might have a material impact on its financial position or results of operations.

Significant Accounting Policies

12 Months Ended

Jul. 31, 2020

Basis of presentation

The accounting and reporting policies of the Company conform to U.S. generally accepted accounting principles (US GAAP).

Use of estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results may differ from those estimates.

Cash and Cash Equivalents

The Company considers all cash accounts, which are not subject to withdrawal restrictions or penalties, and all highly liquid debt instruments purchased with a maturity of three months or less as cash and cash equivalents. The carrying amount of financial instruments included in cash and cash equivalents approximates fair value because of the short maturities for the instruments held. The Company had no cash equivalents as of July 31, 2020 and 2019.

Principles of Consolidation

The accompanying consolidated financial statements include the accounts of the Company and its wholly-owned subsidiaries, Kathis Energy LLC, Kathis Energy Fund 1, LLP and Enmex Operations LLC. All financial information has been prepared in conformity with accounting principles generally accepted in the United States of America. All significant intercompany transactions and balances have been eliminated.

Revenue Recognition

Revenue is recognized when a customer obtains control of promised goods or services and is recognized in an amount that reflects the consideration that an entity expects to receive in exchange for those goods or services. In addition, the standard requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The amount of revenue that is recorded reflects the consideration that the Company expects to receive in exchange for those goods. The Company applies the following five-step model in order to determine this amount: (i) identification of the promised goods in the contract; (ii) determination of whether the promised goods are performance obligations, including whether they are distinct in the context of the contract; (iii) measurement of the transaction price, including the constraint on variable consideration; (iv) allocation of the transaction price to the performance obligations; and (v) recognition of revenue when (or as) the Company satisfies each performance obligation.

The Company only applies the five-step model to contracts when it is probable that the entity will collect the consideration it is entitled to in exchange for the goods or services it transfers to the customer. Once a contract is determined to be within the scope of ASC 606 at contract inception, the Company reviews the contract to determine which performance obligations the Company must deliver and which of these performance obligations are distinct. The Company recognizes as revenues the amount of the transaction price that is allocated to the respective performance obligation when the performance obligation is satisfied or as it is satisfied. Generally, the Company’s performance obligations are transferred to customers at a point in time, typically upon delivery.

The Company receives a majority of its revenue from oil and gas sales from the J. E Richey lease located in Coleman County, Texas. Revenue is recognized when received.

For the year ended July 31, 2020 and 2019, we recognized 100% and 62.4% of revenue, respectively, from crude oil sales on our Richey Lease.

Accounts Receivable

Revenues that have been recognized but not yet received are recorded as accounts receivable. Losses on receivables will be recognized when it is more likely than not that a receivable will not be collected. An allowance for estimated uncollectible amounts will be recognized to reduce the amount of receivables to its net realizable value. The allowance for uncollectible amounts is evaluated quarterly.

Long Lived Assets

Property consists of mineral rights purchases as stipulated by underlying agreements and payments made for oil and gas exploration rights. Our company assesses the impairment of long-lived assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable. When we determine that the carrying value of long-lived assets may not be recoverable based upon the existence of one or more indicators of impairment and the carrying value of the asset cannot be recovered from projected undiscounted cash flows, we record an impairment charge. Our company measures any impairment based on a projected discounted cash flow method using a discount rate determined by management to be commensurate with the risk inherent in the current business model. Significant management judgment is required in determining whether an indicator of impairment exists and in projecting cash flows.

Mineral Property Acquisition and Exploration Costs

Mineral property acquisition and exploration costs are expensed as incurred until such time as economic reserves are quantified. Cost of lease, exploration, carrying and retaining unproven mineral lease properties are expensed as incurred. We have chosen to expense all mineral exploration costs as incurred given that it is still in the exploration stage. Once our company has identified proven and probable reserves in its investigation of its properties and upon development of a plan for operating a mine, it would enter the development stage and capitalize future costs until production is established. When a property reaches the production stage, the related capitalized costs will be amortized over the estimated life of the probable-proven reserves. When our company has capitalized mineral properties, these properties will be periodically assessed for impairment of value and any diminution in value.

Oil and Gas Properties

The Company follows the successful efforts method of accounting for its oil and gas properties. Under this method of accounting, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense. The costs of development wells are capitalized whether those wells are successful or unsuccessful. Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts. Depletion and amortization of oil and gas properties are computed on a well-by-well basis using the units-of-production method. Although the Company has recognized minimal levels of production and revenue, none of its property have proved reserves. Therefore, the Company’s properties are designated as unproved properties.

Unproved property costs are not subject to amortization and consist primarily of leasehold costs related to unproved areas. Unproved property costs are transferred to proved properties if the properties are subsequently determined to be productive and are assigned proved reserves. Proceeds from sales of partial interest in unproved leases are accounted for as a recovery of cost without recognizing any gain until all cost is recovered. Unproved properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks or future plans to develop acreage.

Asset Retirement Obligation

Accounting Standards Codification (“ASC”) Topic 410, Asset Retirement and Environmental Obligations (“ASC 410”) requires an entity to recognize the fair value of a liability for an asset retirement obligation in the period in which it is incurred. The net estimated costs are discounted to present values using credit-adjusted, risk-free rate over the estimated economic life of the oil and gas properties. Such costs are capitalized as part of the related asset. The asset is depleted on the equivalent unit-of-production method based upon estimates of proved oil and natural gas reserves. The liability is periodically adjusted to reflect (1) new liabilities incurred, (2) liabilities settled during the period, (3) accretion expense and (4) revisions to estimated future cash flow requirements. To date, the Company has very few operating wells. Currently, the Company has one working well. Because there is only one active well on the Ritchie Lease with a 24% working interest, the Company estimates the asset retirement obligation to be trivial and has not recorded an ARO liability.

Basic and Diluted Earnings Per Share

Net income (loss) per common share is computed pursuant to ASC 260-10-45, Earnings per Share—Overall—Other Presentation Matters. Basic net income (loss) per common share is computed by dividing net income (loss) by the weighted average number of shares of common stock outstanding during the period. Diluted net income (loss) per common share is computed by dividing net income (loss) by the weighted average number of shares of common stock and potentially outstanding shares of common stock during the period.

For the year ended July 31, 2020, the Company had 3,031,958 of potentially dilutive shares. The shares consisted of common shares and warrants from convertible debt of 1,687,972 and 843,986, respectively, and an additional 5000,000 warrants. For the year ended July 31, 2019, the Company had 4,768,408 of potentially dilutive shares. The shares consisted of common shares and warrants from convertible debt of 1,602,272 and 801,136, respectively, and an additional 2,365,000 warrants. The diluted loss per share is the same as the basic loss per share for the years ended July 31, 2020 and 2019, as the inclusion of any potential shares would have had an antidilutive effect due to our loss from operations.

Recently issued accounting pronouncements

In June 2016, the FASB issued ASU 2016-13, Financial Instruments - Credit Losses, and also issued subsequent amendments to the initial guidance, ASU 2018-19, ASU 2019-04, ASU 2019-05, and ASU 2019-11 (collectively, Topic 326), to introduce a new impairment model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses (CECL). Under Topic 326, an entity is required to estimate CECL on available-for-sale (AFS) debt securities only when the fair value is below the amortized cost of the asset and is no longer based on an impairment being “other-than-temporary”. Topic 326 also requires the impairment calculation on an individual security level and requires an entity use present value of cash flows when estimating the CECL. The credit-related losses are required to be recognized through earnings and non-credit related losses are reported in other comprehensive income. In April 2019, the FASB further clarified the scope of Topic 326 and addressed issues related to accrued interest receivable balances, recoveries, variable interest rates and prepayment. The new guidance will require modified retrospective application to all outstanding instruments, with a cumulative effect adjustment recorded to opening retained earnings as of the beginning of the first period in which the guidance becomes effective. The amendments in this Update for the Company are effective for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. Early adoption is permitted in any interim period after the issuance of this of this Update. The Company is evaluating the impact of the adoption of the new standard on its financial statement and disclosures.

In August 2018, the FASB issued ASU 2018-13 to improve the effectiveness of disclosures about fair value measurements required under ASC 820. The ASU modifies the disclosure objective paragraphs of ASC 820 to eliminate (1) “at a minimum” from the phrase “an entity shall disclose at a minimum” and (2) other similar “open ended” disclosure requirements to promote the appropriate exercise of discretion by entities. The disclosure objective added in ASC 820-10-50-1C states: The objective of the disclosure requirements in this Subtopic is to provide users of financial statements with information about assets and liabilities measured at fair value in the statement of financial position or disclosed in the notes to financial statements: a) the valuation techniques and inputs that a reporting entity uses to arrive at its measures of fair value, including judgments and assumptions that the entity makes, b) the uncertainty in the fair value measurements as of the reporting date, and c) how changes in fair value measurements affect an entity’s performance and cash flows. The new ASU is effective for all entities for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. Early adoption is permitted.

The Company has implemented all new accounting pronouncements that are in effect. These pronouncements did not have any material impact on the financial statements unless otherwise disclosed, and the Company does not believe that there are any other new accounting pronouncements that have been issued that might have a material impact on its financial position or results of operations.