NOTE 4. EVALUATED PROPERTIES

The Company’s current properties can be summarized as follows.

 SCHEDULE OF COMPANY’S CURRENT PROPERTIES

On August 6, 2019, the Company entered into a Purchase and Sale Agreement (“PSA”) for the sale of the same NOACK property with Flowtex Energy LLC. (“FT”). The purchaser agreed to pay $400,000 for the NOACK Assets including a $20,000 deposit that was received on August 15, 2019 and the remaining balance of $380,000 to be received by September 30, 2019. By December 31, 2019, FT had made cumulative payments of $375,000, resulting in a $25,000 account receivable to the Company at March 31, 2021 which is included in other current assets. The $400,000 was recorded as a gain on sale of properties. On July 6, 2021, the remaining $25,000 accounts receivable was settled via the following. The purchaser remitted a cash payment of $8,995, as well as paying (on the Company’s behalf) $16,005 of outstanding property tax invoices previously incurred by the Company.

On May 01 2020, Petrolia Energy Corporation acquired a 50% working interest in approximately 28,000 net working interest acres located in the Utikuma Lake area in Alberta, Canada. The property is an oil-weighted asset currently producing approximately 525 bopd of light oil. The working interest was acquired from Blue Sky Resources Ltd. in an affiliated party transaction as Zel C. Khan, the Company’s former Chief Executive Officer, is related to the ownership of Blue Sky. Blue Sky acquired a 100% working interest in the Canadian Property from Vermilion Energy Inc. via Vermilion’s subsidiary Vermilion Resources. The effective date of the acquisition was May 1, 2020. The total purchase price of the property was $2,000,000 (CAD), with $1,000,000 of that total due initially. The additional $1,000,000 was contingent on the future price of WTI crude. At the time WTI price exceeded $50/bbl, the Company would pay an additional $750,000. In addition, at the time WTI price exceeded $57/bbl the Company would pay an additional $250,000 (for a cumulative contingent total of $1,000,000). Note that WTI crude prices did not exceed those price thresholds until 2021, so the contingent $1,000,000 will not be recorded until 2021. Included in the terms of the agreement, the Company also funded their portion of the Alberta Energy Regulator (“AER”) bond fund requirement ($607,357), necessary for the wells to continue in production after the acquisition. Additional funds ($390,159 USD) remain in the other current asset balance for future payments from BSR, related to the acquisition.

On July 27, 2020, the Company entered into a settlement agreement with their Trustee pursuant to which nine leases totaling approximately 3,800 acres of the 4,880-acre Twin Lakes San Andres Unit were forfeited as a part of the settlement agreement. Consequently, the Company no longer has the right to produce oil, gas, or other hydrocarbons and any other minerals from the mineral estate encumbered by the leases and owned by the Trustee. The company accounted for the forfeiture of the TLSAU properties, in accordance with Reg S-W.T.Rule 4-10(c)(6). Accordingly, an analysis of multi-period reserve reports was performed to determine the percentage of the cumulative US full cost pool’s reserves that were forfeited (56% or 943,820). Then that percentage was multiplied by the period end net property balance of $10,175,456. This resulted in a write down of $5,648,994 ($10,175,456 * 56%) of the US cost pool, which was recorded as part of operating expenses for the year ended December 31, 2020. Note that both TLSAU and SUDS make up the US full cost pool.