Significant Accounting Policies	3 Months Ended
Oct. 31, 2019
Accounting Policies [Abstract]
Significant Accounting Policies	Basis of presentation The Company’s unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”). The accompanying unaudited condensed financial statements reflect all adjustments, consisting of only normal recurring items, which, in the opinion of management, are necessary for a fair statement of the results of operations for the periods shown and are not necessarily indicative of the results to be expected for the full year ending July 31, 2020. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes included in the Company’s Annual Report on Form 10-K for the year ended July 31, 2019. 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 October 31, 2019 and July 31, 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. Reclassifications Certain reclassifications have been made to the prior year financial information to conform to the presentation used in the financial statements for the three months ended October 31, 2019. Specifically, the Company has changed its presentation of revenue from revenue and distributions to only presenting net revenue. There was no effect on net loss or earnings per share. 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 its revenue from oil and gas sales from the J. E Richey lease located in Coleman County, Texas. Revenue is recognized upon delivery. 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. In 2019, the Company on had one working well. Because there is only one active well on the Ritchie Lease, 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. The weighted average number of common shares outstanding and potentially outstanding common shares assumes that we incorporated as of the beginning of the first period presented. As of October 31, 2019 and 2018, the Company had 3,650,545 and 4,823,045 potentially dilutive shares; however, the diluted loss per share is the same as the basic loss per share for the three months ended October 31, 2019 and 2018, as the inclusion of any potential shares would have had an antidilutive effect due to our loss from operations. Recently adopted accounting pronouncements In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). The ASU requires that a lessee recognize the assets and liabilities that arise from operating leases. A lessee should recognize in the statement of financial position a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. For leases with a term of 12 months or less, a lessee is permitted to make an accounting policy election by class of underlying asset not to recognize lease assets and lease liabilities. This new guidance will be effective for annual reporting periods beginning after December 15, 2018, including interim periods within those annual reporting periods, and early adoption is permitted. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The Company adopted this ASU and it did not have an impact on the Company’s consolidated financial statements. In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, to establish ASC Topic 606, (ASC 606). ASU 2014-09 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition and most industry-specific guidance throughout the Industry Topics of the Codification. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The guidance includes a five-step framework that requires an entity to: (i) identify the contract(s) with a customer, (ii) identify the performance obligations in the contract, (iii) determine the transaction price, (iv) allocate the transaction price to the performance obligations in the contract, and (v) recognize revenue when the entity satisfies a performance obligation. In addition, the standard requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. In August 2015, the FASB issued ASU 2015-14, Deferral of the Effective Date, which amended the effective date for nonpublic entities to annual reporting periods beginning after December 15, 2018. In March 2016, the FASB issued an update (ASU 2016-08) to ASC 606, Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which clarifies the guidance on principal versus agent considerations. In April 2016, the FASB issued an update (ASU 2016-10) to ASC 606, Identifying Performance Obligations and Licensing, which provides clarification related to identifying performance obligations and licensing implementation guidance under ASU 2014-09. In May 2016, the FASB issued an update (ASU 2016-12) to ASC 606, Narrow-Scope Improvements and Practical Expedients, which amends guidance on transition, collectability, noncash consideration and the presentation of sales and other similar taxes. In December 2016, the FASB issued an update (ASU 2016-20) to ASC 606, Technical Corrections and Improvements, which outlines technical corrections to certain aspects of the new revenue recognition standard such as provisions for losses on construction type contracts and disclosure of remaining performance obligations, among other aspects. The effective date and transition requirements are the same as those in ASU 2014-09 for all subsequent clarifying guidance discussed herein. The guidance permits two methods of adoption: retrospectively to each prior reporting period presented (full retrospective method), or retrospectively with the cumulative effect of initially applying the guidance recognized at the date of initial application (modified retrospective method). The Company has elected to apply the modified retrospective method. Accordingly, the new revenue standard is applied prospectively in the Company’s financial statements from August 1, 2019 forward and reported financial information for historical comparable periods will not be revised and will continue to be reported under the accounting standards in effect during those historical periods. The impact of ASC 606 is immaterial to the Company.

Significant Accounting Policies

3 Months Ended

Oct. 31, 2019

Basis of presentation

The Company’s unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”). The accompanying unaudited condensed financial statements reflect all adjustments, consisting of only normal recurring items, which, in the opinion of management, are necessary for a fair statement of the results of operations for the periods shown and are not necessarily indicative of the results to be expected for the full year ending July 31, 2020. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes included in the Company’s Annual Report on Form 10-K for the year ended July 31, 2019.

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 October 31, 2019 and July 31, 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.

Reclassifications

Certain reclassifications have been made to the prior year financial information to conform to the presentation used in the financial statements for the three months ended October 31, 2019. Specifically, the Company has changed its presentation of revenue from revenue and distributions to only presenting net revenue. There was no effect on net loss or earnings per share.

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 its revenue from oil and gas sales from the J. E Richey lease located in Coleman County, Texas. Revenue is recognized upon delivery.

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. In 2019, the Company on had one working well. Because there is only one active well on the Ritchie Lease, 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. The weighted average number of common shares outstanding and potentially outstanding common shares assumes that we incorporated as of the beginning of the first period presented.

As of October 31, 2019 and 2018, the Company had 3,650,545 and 4,823,045 potentially dilutive shares; however, the diluted loss per share is the same as the basic loss per share for the three months ended October 31, 2019 and 2018, as the inclusion of any potential shares would have had an antidilutive effect due to our loss from operations.

Recently adopted accounting pronouncements

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). The ASU requires that a lessee recognize the assets and liabilities that arise from operating leases. A lessee should recognize in the statement of financial position a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. For leases with a term of 12 months or less, a lessee is permitted to make an accounting policy election by class of underlying asset not to recognize lease assets and lease liabilities. This new guidance will be effective for annual reporting periods beginning after December 15, 2018, including interim periods within those annual reporting periods, and early adoption is permitted. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The Company adopted this ASU and it did not have an impact on the Company’s consolidated financial statements.

In May 2014, the Financial Accounting Standards Board (FASB) issued ASU 2014-09, Revenue from Contracts with Customers, to establish ASC Topic 606, (ASC 606). ASU 2014-09 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition and most industry-specific guidance throughout the Industry Topics of the Codification. The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The guidance includes a five-step framework that requires an entity to: (i) identify the contract(s) with a customer, (ii) identify the performance obligations in the contract, (iii) determine the transaction price, (iv) allocate the transaction price to the performance obligations in the contract, and (v) recognize revenue when the entity satisfies a performance obligation. In addition, the standard requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers.

In August 2015, the FASB issued ASU 2015-14, Deferral of the Effective Date, which amended the effective date for nonpublic entities to annual reporting periods beginning after December 15, 2018. In March 2016, the FASB issued an update (ASU 2016-08) to ASC 606, Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which clarifies the guidance on principal versus agent considerations. In April 2016, the FASB issued an update (ASU 2016-10) to ASC 606, Identifying Performance Obligations and Licensing, which provides clarification related to identifying performance obligations and licensing implementation guidance under ASU 2014-09. In May 2016, the FASB issued an update (ASU 2016-12) to ASC 606, Narrow-Scope Improvements and Practical Expedients, which amends guidance on transition, collectability, noncash consideration and the presentation of sales and other similar taxes. In December 2016, the FASB issued an update (ASU 2016-20) to ASC 606, Technical Corrections and Improvements, which outlines technical corrections to certain aspects of the new revenue recognition standard such as provisions for losses on construction type contracts and disclosure of remaining performance obligations, among other aspects. The effective date and transition requirements are the same as those in ASU 2014-09 for all subsequent clarifying guidance discussed herein.

The guidance permits two methods of adoption: retrospectively to each prior reporting period presented (full retrospective method), or retrospectively with the cumulative effect of initially applying the guidance recognized at the date of initial application (modified retrospective method). The Company has elected to apply the modified retrospective method. Accordingly, the new revenue standard is applied prospectively in the Company’s financial statements from August 1, 2019 forward and reported financial information for historical comparable periods will not be revised and will continue to be reported under the accounting standards in effect during those historical periods. The impact of ASC 606 is immaterial to the Company.