NOTE 15. SUPPLEMENTAL INFORMATION RELATING TO OIL AND GAS PRODUCING ACTIVITIES (UNAUDITED)

Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development

Amounts reported as costs incurred include both capitalized costs and costs charged to expense during the year for oil and gas property acquisition, exploration and development activities. Costs incurred also include new ARO established in the current year, as well as increases or decreases to the ARO resulting from changes to cost estimates during the year. Exploration costs presented below include the costs of drilling and equipping successful exploration wells, as well as dry hole costs, leasehold impairments, geological and geophysical expenses, and the costs of retaining undeveloped leaseholds. Development costs include the costs of drilling and equipping development wells, and construction of related production facilities.

In 2019, the Company did not make any acquisitions or purchase any working interests.

In 2020, the Company purchased 50% working interest in the Utikuma field in Alberta, Canada for an aggregate purchase price of $678,765. In connection with the acquisition, Company recognized an asset retirement obligation of $906,146.

SCHEDULE OF COSTS INCURRED IN OIL AND GAS PROPERTY ACQUISITION, EXPLORATION AND DEVELOPMENT 

Capitalized costs

Capitalized costs include the cost of properties, equipment and facilities for oil and natural-gas producing activities, excluding any asset retirement obligations. Capitalized costs for proved properties include costs for oil and natural-gas leaseholds where proved reserves have been identified, development wells, and related equipment and facilities, including development wells in progress. Capitalized costs for unproved properties include costs for acquiring oil and gas leaseholds and geological and geophysical expenses where no proved reserves have been identified.

SCHEDULE OF CAPITALIZED COSTS IN OIL AND GAS PROPERTY ACQUISITION, EXPLORATION AND DEVELOPMENT 

Oil and Gas Reserve Information

MKM Engineering (“MKM”), an independent engineering firm, prepared the estimates of the proved reserves, future production, and income attributable to the Chaves County, New Mexico and Creek County, Oklahoma and Canadian property leasehold interests as of December 31, 2020 and the estimates of the proved reserves, future production, and income attributable to the Milam County, Texas, Chaves County, New Mexico and Creek County, Oklahoma leasehold interests as of December 31, 2017. The estimated proved net recoverable reserves presented below include only those quantities that were expected to be commercially recoverable at prices and costs in effect at the balance sheet dates under the then existing regulatory practices and with conventional equipment and operating methods. Proved Developed Reserves represent only those reserves estimated to be recovered through existing wells. Proved Undeveloped Reserves include those reserves that may be recovered from new wells on undrilled acreage or from existing wells on which a relatively major expenditure for recompletion or secondary recovery operations is required. All of the Company’s Proved Reserves are located onshore in the continental United States of America and Canada.

Discounted future cash flow estimates like those shown below are not intended to represent estimates of the fair value of oil and gas properties. Estimates of fair value should also consider unproved reserves, anticipated future oil and gas prices, interest rates, changes in development and production costs and risks associated with future production. Because of these and other considerations, any estimate of fair value is subjective and imprecise.

The following table sets forth estimates of the proved oil and gas reserves (net of royalty interests) for the Company and changes therein, for the periods indicated.

SCHEDULE OF PROVED OIL AND GAS RESERVES 

SCHEDULE OF PROVED DEVELOPED AND UNDEVELOPED RESERVES 

Proved developed and proved undeveloped reserves decreased from December 31, 2019 to December 31, 2020, primarily due the forfeiture of wells in New Mexico, production and revision of prior estimates, partially offset by the acquisition of the Canadian Properties.

The following table sets forth estimates of the proved developed and proved undeveloped oil and gas reserves (net of royalty interests) for the Company and changes therein, for the period indicates.

Standardized Measure of Discounted Future Net Cash Flows

The Standardized Measure related to proved oil and gas reserves is summarized below. Future cash inflows were computed by applying a twelve-month average of the first day of the month prices to estimated future production, less estimated future expenditures (based on year end costs) to be incurred in developing and producing the proved reserves, less estimated future income tax expense. Future income tax expenses are calculated by applying appropriate year-end tax rates to future pretax net cash flows, less the tax basis of properties involved. Future net cash flows are discounted at a rate of 10% annually to derive the standardized measure of discounted future net cash flows. This calculation procedure does not necessarily result in an estimate of the fair market value or the present value of the Company.

Standardized Measure of Oil and Gas

The following table sets forth the changes in standardized measure of discounted future net cash flows relating to proved oil and gas reserves for the periods indicated.

SCHEDULE OF STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS 

Changes in standardized measure of discounted future cash flows

SCHEDULE OF CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE CASH FLOWS