Petrolia Energy Corp - Quarter Report: 2020 September (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☒ Quarterly Report Pursuant To Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended September 30, 2020

☐ Transition Report Under Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from __________ to __________

Commission File Number: 000-52690

PETROLIA ENERGY CORPORATION

(Exact name of registrant as specified in its charter)

(832-723-1266)

(Issuer’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act: None.

Indicate by check mark whether the registrant: (1) filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the past 12 months (or for such shorter period that the issuer was required to file such reports); and (2) has been subject to such filing requirements for the past 90 days. Yes ☐ No ☒

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☐ No ☒

Indicate by check mark whether the registrant is large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definition of “large accelerated filer,” accelerated filer” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act:

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

State the number of shares outstanding of each of the issuer’s classes of common equity, as of the latest practicable date: 176,988,322  shares of common stock as of December 13, 2021.

TABLE OF CONTENTS

PART I: Financial Information

Item 1. Consolidated Financial Statements

PETROLIA ENERGY CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS

The accompanying notes are an integral part of these condensed consolidated interim financial statements.

PETROLIA ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE LOSS

(Unaudited)

The accompanying notes are an integral part of these condensed consolidated interim financial statements.

PETROLIA ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ DEFICIT

(Unaudited)

The accompanying notes are an integral part of these condensed consolidated interim financial statements.

PETROLIA ENERGY CORPORATION

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

SUPPLEMENTAL DISCLOSURES

The accompanying notes are an integral part of these condensed consolidated interim financial statements.

PETROLIA ENERGY CORPORATION

NOTES TO CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2020 AND 2019

(Unaudited)

1. ORGANIZATION AND BASIS OF PRESENTATION:

Petrolia Energy Corporation (the “Company”) is in the business of oil and gas exploration, development and production.

Basis of Presentation

The accompanying unaudited condensed consolidated interim financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States of America (“US GAAP”) and the rules of the Securities and Exchange Commission (“SEC”), and should be read in conjunction with the audited financial statements and notes thereto contained in the Company’s latest Annual Report filed with the SEC on Form 10-K. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of the results of operations for the interim periods presented have been reflected herein. The results of operations for such interim periods are not necessarily indicative of operations for a full year. Notes to the consolidated financial statements which would substantially duplicate the disclosure contained in the audited financial statements for the year ended December 31, 2019, as reported in Form 10-K, have been omitted.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Leases

Leases are classified as operating leases or financing leases based on the lease term and fair value associated with the lease. The assessment is done at lease commencement and reassessed only when a modification occurs that is not considered a separate contract.

Lessee arrangements

Where the Company is the lessee, leases classified as operating leases are recorded as lease liabilities based on the present value of minimum lease payments over the lease term, discounted using the lessor’s rate implicit in the lease or the Company’s incremental borrowing rate, if the lessor’s implicit rate is not readily determinable. The lease term includes all periods covered by renewal and termination options where the Company is reasonably certain to exercise the renewal options or not to exercise the termination options. Corresponding right-of-use assets are recognized consisting of the lease liabilities, initial direct costs and any lease incentive payments.

Lease liabilities are drawn down as lease payments are made and right-of-use assets are depreciated over the term of the lease. Operating lease expenses are recognized on a straight-line basis over the term of the lease, consisting of interest accrued on the lease liability and depreciation of the right-of-use asset, adjusted for changes in index-based variable lease payments in the period of change.

Lease payments on short-term operating leases with lease terms twelve months or less are expensed as incurred.

Fair Value of Financial Instruments

Fair value of financial instruments requires disclosure of the fair value information, whether or not recognized in the balance sheet, where it is practicable to estimate that value. As of September 30, 2020, the amounts reported for cash, accrued interest and other expenses, notes payable, convertible notes, and derivative liability approximate the fair value because of their short maturities.

We adopted ASC Topic 820 for financial instruments measured as fair value on a recurring basis. ASC Topic 820 defines fair value, established a framework for measuring fair value in accordance with accounting principles generally accepted in the United States and expands disclosures about fair value measurements.

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (i.e., the “exit price”) in an orderly transaction between market participants at the measurement date. The hierarchy is broken down into three levels based on the observability of inputs as follows:

We measure certain financial instruments at fair value on a recurring basis. Assets and liabilities measured at fair value on a recurring basis are as follows at September 30, 2020 and December 31, 2019.

Recent Accounting Pronouncements

Adopted in the current year

Effective January 1, 2019, the Company adopted Accounting Standards Update (“ASU”) 2016-02, “Leases”, using the modified retrospective method, whereby a cumulative effect adjustment was made as of the date of initial application. The Company elected the practical expedient to use the effective date of adoption as the date of initial application. Accordingly, financial information and disclosures in the comparative period were not restated. The Company also elected to apply the package of practical expedients such that for any expired or existing leases, it did not reassess lease classification, initial direct costs or whether the relevant contracts are or contain leases. The Company did not use hindsight to reassess lease term or for the determination of impairment of right-of-use assets.

Adoption of ASU 2016-02 did not have any impact on the Company as all its leases are short-term operating leases with lease terms twelve months or less.

To be Adopted in Future Years

In June 2016, Financial Account Standards Board (“FASB”) issued ASU 2016-13, “Measurement of Credit Loss on financial Instruments”. ASU 2016-13 replaces the current incurred loss impairment methodology with the expected credit loss impairment model, which requires consideration of a broader range of reasonable and supportable information to estimate expected credit losses over the life of the instrument instead of only when losses are incurred. This standard applies to financial assets measured at amortized cost basis and investments in leases recognized by the lessor. This standard is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. Early adoption is permitted for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. The Company is currently evaluating this standard to determine the impact it will have on its consolidated financial statements.

3. GOING CONCERN

The Company has suffered recurring losses from operations. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. The Company will need to raise funds through either the sale of its securities or through debt funding to accomplish its goals. If additional financing is not available when needed, the Company may not be able to rework existing oil wells. Management believes that actions presently being taken to secure additional funding for the reworking of its existing infrastructure will provide the opportunity for the Company to continue as a going concern. The accompanying financial statements have been prepared assuming the Company will continue as a going concern; no adjustments to the financial statements have been made to account for this uncertainty.

4. EVALUATED PROPERTIES

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

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 September 30, 2019 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 29, 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 ($560,441), necessary for the wells to continue in production after the acquisition. Additional funds ($484,864 USD) remain in the other current asset balance for future payments to BSR, related to the acquisition.

On July 27, 2020 the Company entered into a settlement agreement with Moon Company, Trustee of the O’Brien Mineral Trust, 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 and it was determined that 32% of the cumulative US full cost pool’s reserves were forfeited. This resulted in a write down of $3,225,928 of the US cost pool which was included in operating expenses. Note that both TLSAU and SUDS make up the US full cost pool.

5. NOTES PAYABLE

The following table summarizes the Company’s notes payable:

On January 15, 2019, the Company entered into a loan agreement in the amount of $125,000 with a third party. The note bore interest at an interest rate of 4% per annum and was to mature on January 15, 2020. On September 30, 2019, Jovian Petroleum Corporation reimbursed the $125,000 to the third party. Consequently, the $125,000 debt balances were transferred into the Jovian LOC and are now included in the $346,040 at September 30, 2020 (see Note 6: Related Party Notes Payable)

On April 23, 2020, the Company was granted a $56,680 business loan through the Paycheck Protection Program (PPP) administered through the CARES act. The loan amount was based 2.5 times the Company’s average monthly payroll costs. The Company is in the process of applying for loan forgiveness and expects to be granted the forgiveness. If forgiveness is granted, the loan principal will not have to be repaid. If not, the loan will earn 1% annual interest and will mature in 2 years.

The following is a schedule of future minimum repayments of notes payable as of September 30:

6. RELATED PARTY NOTES PAYABLE

The following table summarizes the Company’s related party notes payable:

During 2019, $120,000 of related party notes and payables were converted to shares. Specifically, Leo Womack for $ 20,000, Joel Oppenheim for $40,000, Jovian for $40,000 and American Resources for $20,000. See Note 10 for further explanation.

The following is a schedule of future minimum repayments of related party notes payable as of September 30, 2020:

7. DERIVATIVE FINANCIAL INSTRUMENTS

On May 18, 2018, as an inducement to enter into an Amended and Restated Loan Agreement, the Company issued, among other instruments, warrants to acquire 320,000 shares of common stock with an exercise price of $0.10 per share in Canadian dollars (see Note 5). The warrants are valued using the Black Scholes Option Pricing Model and the derivative is fair valued at the end of each reporting period. The Company valued the derivative liability at initial recognition as $30,013.

On January 2, 2020, as an inducement to enter into a Loan Agreement, the Company issued warrants to purchase 5,000,000 shares of common stock with an exercise price of $0.10 per share in Canadian dollars (see Note 5) and expire in 36 months. The warrants are valued using the Black Scholes Option Pricing Model and the derivative is fair valued at the end of each reporting period. The Company valued the derivative liability at initial recognition as $144,259.

A summary of the activity of the Company’s derivative liabilities is shown below:

Derivative liability classified warrants were valued using the Black Scholes Option Pricing Model with the range of assumptions outlined below. Expected life was determined based on historical exercise data of the Company.

8. ASSET RETIREMENT OBLIGATIONS

The Company has a number of oil and gas wells in production and will have Asset Retirement Obligations (“AROs”) once the wells are permanently removed from service. The primary obligations involve the removal and disposal of surface equipment, plugging and abandoning the wells and site restoration.

AROs associated with the retirement of tangible long-lived assets are recognized as liabilities with an increase to the carrying amounts of the related long-lived assets in the period incurred. The fair value of AROs is recognized as of the acquisition date of the working interest. The cost of the tangible asset, including the asset retirement cost, is depleted over the life of the asset. AROs are recorded at estimated fair value, measured by reference to the expected future cash outflows required to satisfy the retirement obligations discounted at the Company’s credit-adjusted risk-free interest rate. Accretion expense is recognized over time as the discounted liabilities are accreted to their expected settlement value. If estimated future costs of AROs change, an adjustment is recorded to both the ARO and the long-lived asset. Revisions to estimated AROs can result from changes in retirement cost estimates, revisions to estimated discount rates and changes in the estimated timing of abandonment.

The Company’s ARO is measured using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging costs, remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs. For the Canadian properties, abandonment and reclamation liabilities are prescribed by the province in which the Company operates in. For the purpose of determining the fair value of AROs incurred during the years presented, the Company used the following assumptions:

The following table shows the change in the Company’s ARO liability:

9. EQUITY

Preferred stock

The holders of Series A Preferred Stock are entitled to receive cumulative dividends at a rate of 9% per annum. The Preferred Stock will automatically convert into common stock when the Company’s common stock market price equals or exceeds $0.28 per share for 30 consecutive days. At conversion, the value of each dollar of preferred stock (based on a $10 per share price) will convert into 7.1429 common shares (which results in a $0.14 per common share conversion rate).

In accordance with the terms of the Preferred Stock, cumulative dividends of $134,025 were declared for the nine months ended September 30, 2020.

Common stock

As of year ended December 31, 2019, the Company closed private placements for $0.08 per unit for a total of 1,875,000 units and gross proceeds of $150,000 (the “2019 Units”). Each 2019 Unit was comprised of one common share and two warrants entitling the holder to exercise such warrant for one common share for a period of two years from the date of issuance. The warrants have exercise price of $0.10 per share. See additional description of the detail transactions concerning those warrants in Note 10: Related Party Transactions, below.

On August 8, 2019, director Joel Martin Oppenheim exercised warrants to purchase 150,000 shares of common stock for cash proceeds of $15,000 at an exercise price of $0.10 per share. The shares were issued in January 2020.

On August 14, 2019, director Joel Martin Oppenheim exercised warrants to purchase 10,000 shares of common stock for cash proceeds of $1,000 at an exercise price of $0.10 per share. The shares were issued in January 2020.

On July 23, 2019, Joel Oppenheim, a related party, purchased 1 unit of the debt private placement with gross proceeds of $12,500. At maturity, the holder has the option to either collect the principal or convert the balance into shares/warrants. The conversion would be for 156,250 shares of common stock and warrants to purchase 312,500 shares of common stock at a price of $0.08 per unit. The warrants fair value was determined to be $15,517 via the Black Sholes Option Pricing Model. Consideration for the purchase was provided though a cash payment of $2,500 as well as the forgiving of an outstanding bridge loan of $10,000. The shares were issued in January 2020.

On January 20, 2020, a related party, purchased 1 unit of the debt private placement with gross proceeds of $12,500. At maturity, the holder has the option to either collect the principal or convert the balance into shares/warrants. The conversion would be for 156,250 shares of common stock and warrants to purchase 312,500 shares of common stock at a price of $0.08 per unit. Jovian converted the debt into shares during 2020.

On February 29, 2020, the Company signed a consulting agreement with a third party to provide Management services related to the SUDS field. The compensation related terms included the issuance of 250,000 shares of Common Stock. The shares were not issued and earned until December 15, 2020.

Warrants

On September 24, 2015, the Board of Directors of the Company approved the adoption of the 2015 Stock Incentive Plan (the “Plan”). The Plan provides an opportunity, subject to approval of our Board of Directors, of individual grants and awards, for any employee, officer, director or consultant of the Company. The maximum aggregate number of shares of common stock which may be issued pursuant to awards under the Plan, as amended on November 7, 2017, was 40,000,000 shares. The plan was ratified by the stockholders of the Company on April 14, 2016.

Continuity of the Company’s common stock purchase warrants issued and outstanding is as follows:

As of September 30, 2020, the weighted-average remaining contractual life of warrants outstanding was 1.10 years (December 31, 2019 – 1.04 years).

As of September 30, 2020, the intrinsic value of warrants outstanding is $0.0 (December 31, 2019 - $8,256).

The table below summarizes warrant issuances during the nine months ended September 30, 2020 and year ended December 31, 2019:

The warrants were valued using the Black Scholes Option Pricing Model with the range of assumptions outlined below. Expected life was determined based on historical data of the Company.

10. RELATED PARTY TRANSACTIONS

On August 21, 2019, Jovian, a related party, purchased 4 units of the debt private placement with gross proceeds of $50,000. At maturity, the holder has the option to either collect the principal or convert the balance into shares/warrants. The conversion would be for 625,000 shares of common stock and warrants to purchase 1,250,000 shares of common stock at a price of $0.08 per unit. The warrants fair value was determined to be $62,066 via the Black Sholes Option Pricing Model. Consideration for the purchase was provided though a cash payment and the conversion of the related party’s prior notes payable and accrued payables.

On August 21, 2019, Joel Oppenheim, a related party, purchased 4 units of the debt private placement with gross proceeds of $50,000. At maturity, the holder has the option to either collect the principal or convert the balance into shares/warrants. The conversion would be for 625,000 shares of common stock and warrants to purchase 1,250,000 shares of common stock at a price of $0.08 per unit. The warrants fair value was determined to be $62,066 via the Black Sholes Option Pricing Model. Consideration for the purchase was provided though a cash payment and the conversion of the related party’s prior notes payable and accrued payables.

On August 21, 2019, American Resources Offshore, Inc., a related party, purchased 2 units of the debt private placement with gross proceeds of $25,000. At maturity, the holder has the option to either collect the principal or convert the balance into shares/warrants. The conversion would be for 312,500 shares of common stock and warrants to purchase 625,000 shares of common stock at a price of $0.08 per unit. The warrants fair value was determined to be $31,033 via the Black Sholes Option Pricing Model. Consideration for the purchase was provided though a cash payment and the conversion of the related party’s prior notes payable and accrued payables.

On August 21, 2019, Leo Womack, a related party, purchased 2 units of the debt private placement with gross proceeds of $25,000. At maturity, the holder has the option to either collect the principal or convert the balance into shares/warrants. The conversion would be for 312,500 shares of common stock and warrants to purchase 625,000 shares of common stock at a price of $0.08 per unit. The warrants fair value was determined to be $31,033 via the Black Sholes Option Pricing Model. Consideration for the purchase was provided though a cash payment and the conversion of the related party’s prior notes payable and accrued payables.

On May 29, 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 ($560,441 USD), necessary for the wells to continue in production after the acquisition. Additional funds ($484,864 USD) remain in the other current asset balance for future payments to BSR, related to the acquisition.

On September 1, 2020, the Company entered into an employment agreement with Mark Allen, to serve as President for a period of six months (with monthly extensions). The President was to be paid a salary of $15,000 a month. Also, the President was issued a signing bonus of 2,000,000 shares of common stock. One million (1,000,000) shares were to be issued upon signing and the remaining 1,000,000 shares are to be issued at the completion of a 6 month probationary period. In addition, the President was granted warrants to purchase 1,000,000 shares of common stock exercisable at $0.08 per share equally vesting over 24 months. The warrants expire in 36 months.

11. SEGMENT REPORTING

The Company has a single reportable operating segment, Oil and Gas Exploration and Production, which includes exploration, development, and production of current and potential oil and gas properties. Results of operations from producing activities were as follows:

13. SUBSEQUENT EVENTS

All of the transactions/events mentioned below occurred subsequent to September 30, 2020.

On February 29, 2020, the Company signed a consulting agreement with a third party to provide management services related to the SUDS field. The compensation related terms included the issuance of 250,000 shares of Common Stock. The shares were not issued and earned until December 15, 2020.

On September 1, 2020, the Board of Directors approved a contractual Employment Agreement between the Company and Mark M Allen to appoint him as the new President of the Company. Mr. Allen’s contract term is 6 months, with a cash payment of $90,000 in equal monthly installments of $15,000, including an option to extend. In addition, Mr. Allen is due to receive incentive compensation of 2,000,000 shares of common stock (1,000,000 were issued at signing and the remining shares are yet to be issued). He also is to receive 1,000,000 warrants at $0.08 per share that expire in 36 months and vest over a two-year period. Mr. Allen has been in the oil and gas industry for over 25 years, most recently as Vice President, Oil and Gas Consulting for Wipro Limited, a leading global consulting and information technology services firm. Prior to Wipro Limited, Mr. Allen was Vice President, Exploration and Production Services for SAIC, a Fortune 500 company.

On December 15, 2020, Company President, Mark M Allen, was issued 1,650,000 common shares for exercising warrants at $0.05 per share with cash proceeds of $82,500.

On December 22, 2020, the Company entered into a promissory note with American Resources for $125,000. The Note bears interest at 10% per annum and is due in full at maturity on June 1, 2021. In addition, 500,000 shares of common stock were granted in association with the note.

On January 25, 2021, the Company signed an Executive Salary Payable Agreement with Zel Khan as the Chief Executive Officer. All of Mr. Khan’s previous salary obligation will be satisfied by the issuance of 1,992,272 shares of the Company, within 15 days of the signed agreement.

Paul Deputy was reinstated as Interim Chief Financial Officer, signed a Settlement and Mutual Release Agreement. In exchange for releasing the Company for any current, outstanding payroll and/or service-related liability at January 29, 2021, the Company agreed to pay Mr. Deputy $50,000, to be paid in $2,500 monthly increments, starting April 1, 2021. In addition, on January 29, 2021 Mr. Deputy was issued 250,000 shares of Petrolia common stock.

Joel Oppenheim, former Director, was issued 316,491 shares in January 2021 pursuant to a Director’s Fees Payable Agreement. The agreement stated that the shares were issued in full satisfaction of all outstanding director fees payable.

On March 30, 2021, Mark M Allen converted $30,000 of unpaid contract wages from early 2020 into 333,333 common shares of common stock at a rate of $0.09 per share.

On March 30, 2021, Mark M Allen converted a defaulted secured loan of $270,000 that was due on December 15, 2019. The debt was converted at a rate of $0.05 per share and resulted in the issuance of 5,400,000 shares of common stock and 5,400,000 warrants to purchase common stock. The warrants have a strike price of $0.08 per share and expire in 36 months.

Effective September 1, 2021, the Board accepted Zel Khan’s resignation as Chief Executive Officer (“CEO”). See Form 8-K filing reference in Exhibits section below.

Effective September 1, 2021, Mark M Allen was promoted from President to CEO. See Form 8-K reference in Exhibits section below.

FORWARD LOOKING STATEMENTS

This Report contains statements which, to the extent that they do not recite historical fact, constitute forward-looking statements. These statements can be identified by the fact that they do not relate strictly to historical or current facts and may include the words “may,” “will,” “could,” “should,” “would,” “believe,” “expect,” “anticipate,” “estimate,” “intend,” “plan” or other words or expressions of similar meaning. We have based these forward-looking statements on our current expectations about future events. The forward-looking statements include statements that reflect management’s beliefs, plans, objectives, goals, expectations, anticipations and intentions with respect to our financial condition, results of operations, future performance and business, including statements relating to our business strategy and our current and future development plans.

The potential risks and uncertainties that could cause our actual financial condition, results of operations and future performance to differ materially from those expressed or implied in this report include:

Although we believe that the expectations reflected in the forward-looking statements are reasonable, we cannot guarantee future results, level of activity, performance or achievements. Many factors discussed in this report, some of which are beyond our control, will be important in determining our future performance. Consequently, actual results may differ materially from those that might be anticipated from the forward-looking statements. In light of these and other uncertainties, you should not regard the inclusion of a forward-looking statement in this Report as a representation by us that our plans and objectives will be achieved, and you should not place undue reliance on such forward-looking statements. We undertake no obligation to publicly update any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law.

You should read the matters described in “Risk Factors” and the other cautionary statements made in, and incorporated by reference in, this Report as being applicable to all related forward-looking statements wherever they appear in this Report. We cannot assure you that the forward-looking statements in this Report will prove to be accurate and therefore prospective investors are encouraged not to place undue reliance on forward-looking statements. Other than as required by law, we undertake no obligation to update or revise these forward-looking statements, even though our situation may change in the future.

Please see the “Glossary of Oil and Gas Terms” on page 9 of our Annual Report on Form 10-K for the year ended December 31, 2019, filed with the SEC on May 27, 2021 (the “2019 Annual Report”) for a list of abbreviations and definitions used throughout this Report.

This information should be read in conjunction with the unaudited condensed consolidated interim financial statements and the notes thereto included in this Quarterly Report on Form 10-Q and Part II, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in our 2019 Annual Report.

Certain capitalized terms used below and otherwise defined below, have the meanings given to such terms in the footnotes to our consolidated financial statements included above under “Part I – Financial Information” – “Item 1. Financial Statements”.

Unless the context requires otherwise, references to the “Company,” “we,” “us,” “our,” “Petrolia” and “Petrolia Energy Corp.” refer specifically to Petrolia Energy Corp. and its wholly-owned subsidiaries.

In addition, unless the context otherwise requires and for the purposes of this Report only:

Item 2 Management’s Discussion and Analysis of Financial Condition and Results of Operations

Background

We were incorporated in Colorado on January 16, 2002. In February 2012, we decided it would be in the best interests of our shareholders to no longer pursue our original business plan and, in April 2012, we became active in the exploration and development of oil and gas properties.

Effective September 2, 2016, we formally changed our name to Petrolia Energy Corporation, pursuant to the filing of a Statement of Conversion with the Secretary of State of Colorado and a Certificate of Conversion with the Secretary of State of Texas, authorized by the Plan of Conversion which was approved by our stockholders at our April 14, 2016, annual meeting of stockholders, each of which are described in greater detail in the Definitive Proxy Statement on Schedule 14A, which was filed with the Securities and Exchange Commission on March 23, 2016. In addition to the Certificate of Conversion filing, we filed a Certificate of Correction filing with the Secretary of State of Texas (correcting certain errors in our originally filed Certificate of Formation) on August 24, 2016.

As previously reported, although the stockholders approved the Plan of Conversion at the annual meeting, pursuant to which our corporate jurisdiction was to be changed from the State of Colorado to the State of Texas by means of a process called a “Conversion” and our name was to be changed to “Petrolia Energy Corporation”, those filings were not immediately made and the Conversion did not become legally effective until September 2, 2016. Specifically, on June 15, 2016, the Company filed a Certificate of Conversion with the Texas Secretary of State, affecting the Conversion and the name change, and including a Certificate of Formation as a converted Texas corporation; however, the Statement of Conversion was not filed with the State of Colorado until a later date. As a result, and because FINRA and the Depository Trust Company (DTC) had advised us that they would not recognize the Conversion or name change, or update such related information in the marketplace until we became current in our periodic filings with the Securities and Exchange Commission and they had a chance to review and approve such transactions, we took the position that the Conversion and name change were not legally effective until September 2, 2016.

As a result of the filings described above, and FINRA and the Depository Trust Company (DTC) formally recognizing and reflecting the events described above in the marketplace, the Company has formally converted from a Colorado corporation to a Texas corporation, and has formally changed its name to “Petrolia Energy Corporation”.

Two significant acquisitions were made in 2015 and additional working interests in the same properties were acquired in 2016 and 2017, as described in greater detail in the “Plan of Operation” section below. Additionally, in February 2018, we acquired Bow Energy Ltd. and its assets (“Bow”), provided that in September 2018, we divested Bow, each as described in greater detail in the “Plan of Operation” section below. During 2018, we acquired an aggregate of a 28% working interest in properties consisting of approximately 41,526 acres located in the Luseland, Hearts Hill, and Cuthbert fields, located in Southwest Saskatchewan and Eastern Alberta, Canada, as described in greater detail in the “Plan of Operation” section below.

Plan of Operation

Since 2015, we have established a clearly defined strategy to acquire, enhance and redevelop high-quality, resource in place assets. The Company has been focusing on acquisitions in the Southwest United States and Canada while actively pursuing our strategy to offer low-cost operational solutions in established Oil and Gas regions. We believe our mix of oil-in-place conventional plays, low-risk resource plays and the redevelopment of our late-stage plays is a solid foundation for continued growth and future revenue growth.

Our strategy is to acquire low risk, conventionally producing oil fields. This strategy allows us to incorporate new technology to minimize risk and maximize the recoverability of existing reservoirs. This approach allows us to minimize the environmental impact caused by exploratory development.

Our activities will primarily be dependent upon available financing.

Oil and gas leases are considered real property. Title to properties which we may acquire will be subject to landowner’s royalties, overriding royalties, carried working and other similar interests and contractual arrangements customary in the oil and gas industry, to liens for current taxes not yet due, liens for amounts owing to persons operating wells, and other encumbrances. As is customary in the industry, in the case of undeveloped properties, little investigation of record title will be made at the time of acquisition (other than a preliminary review of local records.

Minerva-Rockdale Field

The Minerva-Rockdale Field, which is located approximately 30 miles Northeast of Austin, Texas, was first discovered in 1921 and is approximately 50 square miles in size. The main producing formation for this field is the Upper Cretaceous Navarro Group of sands and shales. The Navarro is typically subdivided into several producing zones from the uppermost “A” and “B” sands to the lower “C” and “D” sands. The “B” sand is the primary producing zone. These sands are commonly fine grained and poorly sorted and were deposited close to a shoreline during a cycle of marine regression.

In April 2013, the Company entered into a lease pertaining to a 423-acre tract in Milam County, Texas, which is adjacent to the Company’s original 200-acre lease. The Company issued 500,000 shares of its common stock as consideration for a 100% working interest (83.33% net revenue interest) in such lease.

In August 2013, we became an oil and gas operator and took over the operation of 100% of our wells. During the fourth quarter of 2014, the Company hired Jovian Petroleum Corporation (“Jovian”) to survey the operations and well performance at the NOACK field. Their report identified paraffin buildup problems in the well bores and gathering lines as the main production issue for the Company to overcome. In December 2014, the Company signed an operating agreement with Jovian to assume full operational responsibility for the NOACK field under a fixed fee agreement of $10,000 per month for full operating field services. On March 1, 2015, the Company hired Zel C. Khan, our former CEO and director, who is a stockholder and former employee of Jovian. The CEO and President of Jovian is Quinten Beasley, our former director (resigned October 31, 2018).

During the period from our inception to December 31, 2011, we did not drill any oil or gas wells. During the year-ended December 31, 2012, we drilled and completed six (6) oil wells. During 2013, the Company drilled and completed three (3) wells of which one (1) was converted to an injection well. During 2014, the Company drilled seven (7) new wells. In 2015, six (6) of the wells were completed, five (5) wells produced, one (1) did not produce, and one (1) well was not completed. During 2016, the Company had three (3) wells producing, ten (10) wells to workover, with one (1) injection well, one (1) that did not produce, and one (1) well not completed. During 2017, the Company had four (4) wells producing, ten (10) wells to workover, with one (1) injection well, and one (1) well not completed. During 2019, the Company had six (6) wells producing, eight (8) wells to workover, with one (1) injection well, and one (1) well not completed.

Houston Gulf Energy defaulted on a Purchase and Sale Agreement for the NOACK field assets located in Milam County, Texas and the Company took proper measures to foreclose on the NOACK Assets on April 3, 2019 and reclaimed title to the property. The property was subsequently sold to FlowTex Energy L.L.C. for $400,000 with an effective closing date of September 1, 2019. The Sale Agreement includes customary indemnification obligations of the parties. As per the Sale Agreement, a $20,000 deposit was received on August 15, 2019 and a $355,000 payment on August 30, 2019. On July 6, 2021; the remaining $25,000 receivable was settled.

Slick Unit Dutcher Sands (“SUDS”) Field

The SUDS oilfield consists of 2,604 acres located in Creek County, Oklahoma and Petrolia owns a 100% Working Interest (“WI”) with a 76.5% net revenue interest (NRI). The first oil well was completed in 1918 by Standard Oil of Ohio (“Sohio”), which at that time was owned by John D. Rockefeller. By 1959, approximately 14,000,000 barrels of oil had been recovered at an average well depth of 3,100 feet and over 100 wells in production. Our engineering reports and analysis indicate there is still considerable recoverable reserves remaining.

We have recently completed a capital project to rebuild our field tank battery, consisting of two free water knockout units, four oil stock tanks and one fiberglass saltwater tank. Additionally, we received a new 5-year permit for our disposal well and upgraded our flowlines for most of the field.

Twin Lakes San Andres Unit (“TLSAU”) Field

TLSAU is located 45 miles from Roswell, Chaves County, New Mexico and consists of 880 acres with approximately 38 wells.

TLSAU is currently shut-in awaiting capital allocation to complete some regulatory plugging requirements.

Askarii Resources, LLC

Effective February 1, 2016, the Company acquired 100% of the issued and outstanding interests of Askarii Resources LLC (“Askarii”), a private Texas based oil & gas service company for the aggregate value of $50,000.

The Company may engage in the oil field service business in the U.S.

Canadian properties

Luseland, Hearts Hill and Cuthbert fields

On June 29, 2018, the Company acquired a 25% working interest in approximately 41,526 acres located in the Luseland, Hearts Hill, and Cuthbert fields, located in Southwest Saskatchewan and Eastern Alberta, Canada (collectively, the “Canadian Properties” and the “Working Interest”). The Canadian Properties currently encompass 64 sections, with 240 oil and 12 natural gas wells currently producing on the properties. Additionally, there are several idle wells with potential for reactivation and 34 sections of undeveloped land (approximately 21,760 acres). The Canadian Properties and the Working Interest were acquired from Blue Sky (a related party, as described above). Blue Sky had previously acquired an 80% working interest from Georox Resources Inc., who had acquired the Canadian Properties from Cona Resources Ltd.

On September 17, 2018, the Company entered into a Memorandum of Understanding (“MOU”) with Blue Sky to obtain the rights to acquire an additional 3% working interest in the Canadian Properties, increasing our Working Interest to 28%. Total consideration paid from the Company to Blue Sky for the additional 3% Working Interest was $150,000.

Utikuma field

On May 29, 2020, Petrolia Energy Corporation acquired a 50% working interest in approximately 28,000 acres located in the Utikuma Lake area in Alberta, Canada. The property is an oil-weighted asset currently producing approximately 500 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 ($560,441 USD), necessary for the wells to continue in production after the acquisition. Additional funds ($484,864 USD) remain in the other current asset balance for future payments to BSR, related to the acquisition.

Results of Operations

Revenues

Our oil and gas revenue reported for the three months ended September 30, 2020 was $953,524, an increase of $119,203 from the three months ended September 30, 2019. The increase was due to the purchase of the Utikuma field and its related sales during the quarter. Revenues associated with our US properties totaled $0.0 during this period.

Our oil and gas revenue reported for the nine months ended September 30, 2020 was $1,943,866, an decrease of $509,799 from the nine months ended September 30, 2019. The decrease was due to a significant decrease in the CONA production in 2020, compared to the respective period in 2019. Those decreases were offset by the production from the newly purchased Utikuma field. Revenues associated with our U.S. properties totaled $8,005.

Operating Expenses

Operating expenses increased by $3,365,113, to $5,002,836 for the three-month period ended September 30, 2020, compared to $1,637,723 for the three months ended September 30, 2019. The operating expense increase was primarily due to the forfeiture of a number of TLSAU leases of $3,225,928. In addition, there was an increase of $176,607 in lease operating expenses, with an offsetting decrease of $146,897 in general and administrative expense primarily due to reduced board compensation expense.

Operating expenses increased by $3,063,046, to $7,538,474 for the nine-month period ended September 30, 2020, compared to $4,475,428 for the nine months ended September 30, 2019. The operating expense increase was primarily due to the forfeiture of a number of TLSAU leases of $3,225,928. There were also increases in depreciation, depletion and amortization expense of $149,006 related to the acquisition of the two Canadian properties on June 29,2018 and May 29, 2020. ARO accretion also increased by $97,692. These increases were offset by a decrease of $132,115 in lease operating expenses and a $272,930 decrease in general and administrative expense which was primarily due to a decrease in equity related issuances (stock compensation expense) in connection with Mr. James Burns stepping down as the Company’s president, and the associated Separation Agreement.

Other income (expense)

The Company incurred a net other expense balance of $288,813 for the three-month period ended September 30, 2020, compared to a net other income balance of $67,759, for the three-month ended September 30, 2019. The primary cause of the increase was a $101,188 increase in interest expense due to the new loan. Also, an increase in relative expense was due to the $113,905 loan origination fee.

Other expenses increased by $1,097,956 to $900,896 for the nine-month period ending September 30, 2020, compared to $(197,060) for the nine-month period ending September 30, 2019. The primary cause of the increase was a $365,398 increase in interest expense due to the additional note agreements in 2020. There was also an increase of $189,978 in the change in fair value of derivative liabilities related to the $1,000,000 Reinhart note agreement that was signed in 2020. In addition, there were increases in foreign exchange losses and decreases in other income from 2019 related to the gain on sale of the Noack property.

Foreign exchange loss was $0.0 for the nine-month period ended September 30, 2020. It increased by $34,375, compared to a $34,375 foreign exchange gain for the nine months ended September 30, 2019. The decrease resulted from fluctuations in the value of the United States dollar against the Canadian dollar.

Net Income (Loss)

Net loss for the three months ended September 30, 2020 was $4,338,125, compared to a net loss of $871,161 for the three months ended September 30, 2019. The primary reason for the decrease in net income is due to the forfeiture of the TLSAU leases, as well as a decrease in revenue from reduced production, and increased interest expense from new loans and related derivative liabilities.

Net loss for the nine months ended September 30, 2020 was $6,495,504, compared to a net loss of $1,824,703 for the nine months ended September 30, 2019. The primary reason for the increase in loss in 2020 compared to 2019 was due to the forfeiture of the TLSAU leases as well as the Canadian acquisition related expenses and increased interest expense.

Liquidity and Capital Resources

The financial condition of the Company has not changed significantly throughout the period from December 31, 2019 to September 30, 2020.

As of September 30, 2020, we had total current assets of $536,181 and total assets of $10,162,655. Our total current liabilities as of September 30, 2020 were $5,346,358 and our total liabilities as of September 30, 2020 were $10,681,374. We had negative working capital of $4,810,177 as of September 30, 2020.

Our material asset balances are made up of oil and gas properties and related equipment. Our most significant liabilities are notes payable and notes payable related party of $6,787,603 along with accounts payable and accrued liabilities, including amounts due to related parties, mainly consisting of accrued officer salaries of $1,185,270, in addition to asset retirement obligations of $2,811,869 (see “Part I – Item 1. Financial Statements - Note 5. Notes Payable”, above for information regarding outstanding debt obligations).

Net cash used in operating activities was $744,433 and $473,386 for the nine months ended September 30, 2020 and 2019, respectively. The primary cause for the increase was due to the forfeiture of a number of TLSAU leases. In addition, the was an increase related to the Company’s loan funding for the purchase of the Utikuma properties. These funds were previously escrowed as a prepaid assets. In addition, there was a net loss that was offset by the defaulted previous sale of the NOACK property and reduced stock compensation expense.

Net cash from investing activities was $0.0 for the nine months ended September 30, 2020 compared to net cash used of $276,902 for the nine months ended September 30, 2019. The increase was primarily due to the funds used to acquire the Canadian Properties with an offset due to the sale of the NOACK properties.

Net cash provided by financing activities was $770,138 and $1,011,509 for the nine months ended September 30, 2020 and 2019, respectively. The decrease of $404,160 was primarily due to the larger 2019 loan of $750,000 from a third party which was offset by only $615,000 in 2020 loans, from a number of new notes payable by two third-parties and Mark M Allen. (see “Part I – Item 1. Financial Statements - Note 5. Notes Payable”, above for information regarding outstanding debt obligations).

During the quarter ended September 30, 2020, the Company operated at a negative cash flow from operations of approximately $10,000 per month and our auditors have raised a going concern in their audit report as contained herein.

The Company has suffered recurring losses from operations. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. However, we will need to raise additional funds to workover or drill new wells through the sale of our securities, through loans from third parties or from third parties willing to pay our share of drilling and completing the wells.

We do not have any commitments or arrangements from any person to provide us with any additional capital. If additional financing is not available when needed, we may need to cease operations. There can be no assurance that we will be successful in raising the capital needed to drill oil or gas wells nor that any such additional financing will be available to us on acceptable terms or at all. Any wells which we may drill may not be productive of oil or gas. Management believes that actions presently being taken to obtain additional funding provide the opportunity for the Company to continue as a going concern. The accompanying financial statements have been prepared assuming the Company will continue as a going concern; no adjustments to the financial statements have been made to account for this uncertainty.

Off-Balance Sheet Arrangements

As of September 30, 2020, we had no off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, results of operations, liquidity or capital resources or change our financial condition.

Trends Affecting Future Operations

The factors that will most significantly affect our results of operations will be (i) the sale prices of crude oil and natural gas, (ii) the amount of production from oil or gas wells in which we have an interest, and (iii) lease operating expenses. Our revenues will also be significantly impacted by our ability to maintain or increase oil or gas production through exploration and development activities, and the availability of funding to complete such activities.

It is expected that our principal source of cash flow will be from the production and sale of crude oil and natural gas reserves which are depleting assets. Cash flow from the sale of oil and gas production depends upon the quantity of production and the price obtained for the production. An increase in prices will permit us to finance our operations to a greater extent with internally generated funds, may allow us to obtain equity financing more easily or on better terms, and lessens the difficulty of obtaining financing. However, price increases heighten the competition for oil and gas prospects, increase the costs of exploration and development, and, because of potential price declines, increase the risks associated with the purchase of producing properties during times that prices are at higher levels.

A decline in oil and gas prices (i) will reduce the cash flow internally generated by the Company which in turn will reduce the funds available for exploring for and replacing oil and gas reserves, (ii) will increase the difficulty of obtaining equity and debt financing and worsen the terms on which such financing may be obtained, (iii) will reduce the number of oil and gas prospects which have reasonable economic terms, (iv) may cause us to permit leases to expire based upon the value of potential oil and gas reserves in relation to the costs of exploration, (v) may result in marginally productive oil and gas wells being abandoned as non-commercial, and (vi) may increase the difficulty of obtaining financing. However, price declines reduce the competition for oil and gas properties and correspondingly reduce the prices paid for leases and prospects.

Critical Accounting Policies and New Accounting Pronouncements

In December 2001, the SEC requested that all registrants list their most “critical accounting polices” in the Management Discussion and Analysis. The SEC indicated that a “critical accounting policy” is one which is both important to the portrayal of a company’s financial condition and results, and requires management’s most difficult, subjective or complex judgments, often as a result of the need to make estimates about the effect of matters that are inherently uncertain.

Going concern – The accompanying financial statements have been prepared on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. The Company has incurred cumulative net losses of $54,532,874 since its inception and requires capital for its contemplated operational and marketing activities to take place. The Company’s ability to raise additional capital through the future sales of common stock is unknown. The obtainment of additional financing, the successful development of the Company’s contemplated plan of operations, and its transition, ultimately, to the attainment of profitable operations are necessary for the Company to continue operations. The ability to successfully resolve these factors raise substantial doubt about the Company’s ability to continue as a going concern. The consolidated financial statements of the Company do not include any adjustments that may result from the outcome of these aforementioned uncertainties.

Item 3 Quantitative and Qualitative Disclosures about Market Risk

Pursuant to Item 305(e) of Regulation S-K (§ 229.305(e)), the Company is not required to provide the information required by this Item as it is a “smaller reporting company,” as defined by Rule 229.10(f)(1).

Item 4 Controls and Procedures

(a) We maintain a system of controls and procedures designed to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act, is recorded, processed, summarized and reported within time periods specified in the SEC’s rules and forms and to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our Principal Executive and Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

As of September 30, 2020, our Principal Executive and Financial Officer evaluated the effectiveness of the design and operation of our disclosure controls and procedures. Based on that evaluation, our Principal Executive and Financial Officer concluded that our disclosure controls and procedures were not effective.

(b) Changes in Internal Controls. There were no changes in our internal controls over financial reporting during the quarter ended September 30, 2020 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II: OTHER INFORMATION

Item 1 Legal Proceedings

We may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business. We are not currently a party to any material legal proceeding. All legal disputes have been disclosed. In addition, we are not aware of any material legal or governmental proceedings against us, or contemplated to be brought against us.

Item 1A Risk Factors

There have been no material changes from the risk factors previously disclosed in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2019, filed with the Commission on October 15, 2019, under the heading “Risk Factors”, except as set forth below and investors should review the risks provided in the Form 10-K and below, prior to making an investment in the Company. The business, financial condition and operating results of the Company can be affected by a number of factors, whether currently known or unknown, including but not limited to those described in the Form 10-K for the year ended December 31, 2019, under “Risk Factors” and below, any one or more of which could, directly or indirectly, cause the Company’s actual financial condition and operating results to vary materially from past, or from anticipated future, financial condition and operating results. Any of these factors, in whole or in part, could materially and adversely affect the Company’s business, financial condition, operating results and stock price.

We are currently behind in our SEC filing obligations.