VIKING ENERGY GROUP, INC. - Quarter Report: 2019 March (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x QUARTERLY REPORT UNDER SECTION 13 OR 15 (D) OF THE SECURITIES EXCHANGE ACT OF 1934 

FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2019

OR

¨ TRANSITION REPORT UNDER SECTION 13 OR 15 (D) OF THE SECURITIES EXCHANGE ACT OF 1934 

For the transition period from _______ to _______.

Commission file number: 000-29219

15915 Katy Freeway, Suite 450

Houston, TX 77094

(Address of principal executive offices)

(281) 404 4387

(Registrant’s telephone number, including area code)

____________________________________________________________

(Former name, former address and former fiscal year, if changed since last report)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions 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 x

APPLICABLE ONLY TO CORPORATE ISSUERS 

As of May 6, 2019, the registrant had 91,187,081 shares of common stock outstanding.

VIKING ENERGY GROUP, INC.

PART I—FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

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

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

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

For the three months ended March 31, 2019

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

Note 1 Nature of Business and Going Concern 

Viking Energy Group, Inc. (“Viking” or the “Company”) is incorporated under the laws of the State of Nevada. The Company's business plan is to engage in the acquisition, exploration, development and production of oil and natural gas properties, both individually and through collaborative partnerships with other companies in this field of endeavor. Since 2014 the Company has had the following related activities:

These accompanying consolidated 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. However, the Company had a net loss of $11,931,481, and $1,552,883 for the three months ended March 31, 2019 and 2018, respectively. Furthermore, as of March 31, 2019, the Company has a working capital deficiency in excess of $48,000,000. The largest components of current liabilities creating this deficiency are (a) notes payable with a face value aggregating approximately $15,000,000 due in August of 2019 and (b) a promissory note payable to the seller of the certain oil and gas interests purchased on December 28, 2018 in the amount of $23,777,948 with all principal and accrued interest due on the earlier of (i) the date the Company or one of its affiliates completes an acquisition with one or more of the Sellers for a purchase price equal to or greater than $50,000,000 or (ii) January 31, 2020.

Management has evaluated these conditions and has developed a plan which, in part, address these obligations as follows:

These conditions raise substantial doubt regarding the Company’s ability to continue as a going concern. The Company’s ability to continue as a going concern is dependent upon its ability to utilize the resources in place to generate future profitable operations, to develop additional acquisition opportunities, and to obtain the necessary financing to meet its obligations and repay its liabilities arising from business operations when they come due. Management believes the Company will be able to continue to develop new opportunities, and will be able to obtain additional funds through debt and / or equity financings to facilitate its development strategy; however, there is no assurance of additional funding being available. These consolidated financial statements do not include any adjustments to the recorded assets or liabilities that might be necessary should the Company have to curtail operations or be unable to continue in existence.

Note 2 Summary of Significant Accounting Policies 

a) Basis of Presentation 

The accompanying unaudited consolidated financial statements of the Company have been prepared in accordance with generally accepted accounting principles in the United States of America (“GAAP”) and the interim reporting rules of the Securities and Exchange Commission (“SEC”) and should be read in conjunction with the audited financial statements and notes thereto contained in Viking’s latest Annual Report filed with the SEC on Form 10-K. In the opinion of management, all adjustments, consisting of normal recurring adjustments (unless otherwise indicated), necessary for a fair presentation of the financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year.

b) Basis of Consolidation

The financial statements presented herein reflect the consolidated financial results of the Company and its wholly owned subsidiaries: Viking Oil & Gas (Canada) ULC, a Canadian corporation formed to provide a base of operations for properties in Canada; Mid-Con Petroleum, LLC, Mid-Con Drilling, LLC, and Mid-Con Development, LLC, which were all formed to provide a base of operations for properties in the Central United States; and Petrodome Energy, LLC (and its subsidiaries) and Ichor Energy Holdings, LLC, its subsidiary Ichor Energy, LLC (Ichor Energy”), and Ichor Energy’s subsidiaries, Ichor Energy (TX), LLC, and Ichor Energy (LA), LLC, which provide a base of operations to facilitate property acquisitions in Texas, Louisiana and Mississippi. All significant intercompany transactions and balances have been eliminated.

c) Use of Estimates in the Preparation of Financial Statements

The preparation of consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts and timing of revenues and expenses, the reported amounts and classification of assets and liabilities, and disclosure of contingent assets and liabilities. Significant areas requiring the use of management estimates relate to impairment of long-lived assets, stock-based compensation, asset retirement obligations, and the determination of expected tax rates for future income tax recoveries.

The estimates of proved, probable and possible oil and gas reserves are used as significant inputs in determining the depletion of oil and gas properties and the impairment of proved and unproved oil and gas properties. There are numerous uncertainties inherent in the estimation of quantities of proved, probable and possible reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price outlooks. Actual results could differ from the estimates and assumptions utilized.

d) Financial Instruments 

Accounting Standards Codification, “ASC” Topic 820-10, “Fair Value Measurement” requires disclosure of the fair value of financial instruments held by the Company. ASC Topic 820-10, defines fair value, and establishes a three-level valuation hierarchy for disclosures of fair value measurement that enhances disclosure requirements for fair value measurement. The carrying amounts reported in the consolidated balance sheets for other receivable – related party, long-term investment, accrued expenses and other current liabilities, accounts payable, derivative liabilities, amount due to directors, and convertible notes each qualify as financial instruments and are a reasonable estimate of their fair values because of the short period of time between the origination of such instruments and their expected realization and their current market rate of interest. The three levels of valuation hierarchy are defined as follows:

Assets and liabilities measured at fair value as of March 31, 2019 are classified below based on the three fair value hierarchy described above:

Assets and liabilities measured at fair value as of December 31, 2018, are classified below based on the three-level fair value hierarchy described above:

The Company has entered into certain commodity derivative instruments containing swaps and collars, which are effective in mitigating commodity price risk associated with a portion of its future monthly natural gas and crude oil production and related cash flows. The Company does not designate its commodities derivative instruments as hedges and therefore does not apply hedge accounting. Changes in fair value of derivative instruments subsequent to the initial measurement are recorded as change in fair value on derivative liability, in other income (expense). The estimated fair value amounts of the Company’s commodity derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2. Although the Company’s commodity derivative instruments are valued using public indices, as well as the Black-Sholes model, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange.

In a commodities swap agreement, the Company trades the fluctuating market prices of oil or natural gas at specific delivery points over a specified period, for fixed prices. As a producer of oil and natural gas, the Company holds these commodity derivatives to protect the operating revenues and cash flows related to a portion of its future natural gas and crude oil sales from the risk of significant declines in commodity prices, which helps reduce exposure to price risk and improves the likelihood of funding its capital budget. If the price of a commodity rises above what the Company has agreed to receive in the swap agreement, the amount that it agreed to pay the counterparty is expected to be offset by the increased amount it received for its production.

The Company has also entered into collar agreements related to oil and gas production with established floors and ceilings. Upon settlement, if the current market price of the commodity is below the floor, the Company receives the difference. Conversely, if the current market price of the commodity is above the ceiling at settlement, the Company pays the excess over the ceiling price.

Although the Company is exposed to credit risk to the extent of nonperformance by the counterparties to these derivative contracts, the Company does not anticipate such nonperformance and monitors the credit worthiness of its counterparties on an ongoing basis.

The derivative assets were $0 and $681,776 as of March 31, 2019 and December 31, 2018, and the derivative liabilities were $11,595,525 and $2,531,718 as of March 31, 2019 and December 31, 2018 respectively. The change in the fair value of the derivative assets and liabilities for the three months ended March 31, 2019 consisted of a decrease of $681,776 associated with existing commodity derivatives and a decrease of $9,063,807 associated with the new commodity derivative related to the acquisition accomplished on December 28, 2018, and a loss recognized in the consolidated statement of operations in the amount of $9,745,583.

The table below is a summary of the Company’s commodity derivatives as of March 31, 2019:

e) Cash and Cash Equivalents 

Cash and cash equivalents include cash in banks and highly liquid investment securities that have original maturities of three months or less. At March 31, 2019, the Company has cash deposits in excess of FDIC insured limits in the amounts of $3,183,623

Restricted cash in the amount of $3,233,324 as of March 31, 2019 represents the balance of cash in the Ichor Energy LLC subsidiaries, generated through the operations of those subsidiaries and restricted for operations, debt service and development projects within those subsidiaries.

f) Accounts receivable

Accounts receivable consist of oil and gas receivables. The Company evaluates these accounts receivable for collectability and, when necessary, records allowances for expected unrecoverable amounts. The Company has recorded an allowance for doubtful accounts of $217,057 at March 31, 2019 and December 31, 2018 respectively. 

g) Oil and Gas Properties

The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs associated with acquisition, exploration and development of oil and gas reserves, including directly related overhead costs, are capitalized. General and administrative costs related to production and general overhead are expensed as incurred.

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit of production method using estimates of proved reserves. Disposition of oil and gas properties are accounted for as a reduction of capitalized costs, with no gain or loss recognized unless such adjustment would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in operations. Unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is included in loss from operations before income taxes and the adjusted carrying amount of the unproved properties is amortized on the unit-of-production method.

Depreciation, depletion and amortization expense utilizing the unit-of-production method for the Company’s oil and gas properties for the three months ended March 31, 2019 and 2018 were as follows:

h) Limitation on Capitalized Costs

Under the full-cost method of accounting, we are required, at the end of each reporting date, to perform a test to determine the limit on the book value of our oil and natural gas properties (the “Ceiling” test). If the capitalized costs of our oil and natural gas properties, net of accumulated amortization and related deferred income taxes, exceed the Ceiling, this excess or impairment is charged to expense. The expense may not be reversed in future periods, even though higher oil and natural gas prices may subsequently increase the Ceiling. The Ceiling is defined as the sum of:

(a) the present value, discounted at 10 percent, and assuming continuation of existing economic conditions, of 1) estimated future gross revenues from proved reserves, which is computed using oil and natural gas prices determined as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month hedging arrangements pursuant to SAB 103, less 2) estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves, plus

(b) the cost of properties not being amortized; plus

(c) the lower of cost or estimated fair value of unproven properties included in the costs being amortized, net of

(d) the related tax effects related to the difference between the book and tax basis of our oil and natural gas properties.

i) Oil and Gas Reserves

Reserve engineering is a subjective process that is dependent upon the quality of available data and the interpretation thereof, including evaluations and extrapolations of well flow rates and reservoir pressure. Estimates by different engineers often vary sometimes significantly. In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates. Because proved reserves are required to be estimated using recent prices of the evaluation, estimated reserve quantities can be significantly impacted by changes in product prices.

j) Loss per Share

Basic net loss per share is computed by dividing the net loss by the weighted-average number of common shares outstanding during the period. Diluted net loss per share is computed by dividing the net loss by the weighted-average number of common shares and, adjusted by any effects of warrants and options outstanding, if dilutive, that may add to the number of common shares during the period. At March 31, 2019 and 2018 there were approximately 92,274,782 and 31,503,126 common stock equivalents respectively, that were anti-dilutive.

k) Revenue Recognition 

Sales of crude oil, natural gas, and natural gas liquids (NGLs) are included in revenue when production is sold to a customer in fulfillment of performance obligations under the terms of agreed contracts. Performance obligations primarily comprise delivery of oil, gas, or NGLs at a delivery point, as negotiated within each contract. Each barrel of oil, million BTU (MMBtu) of natural gas, or other unit of measure is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are satisfied at a point in time once control of the product has been transferred to the customer. The Company considers a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the hydrocarbons, the transfer of significant risks and rewards, the Company’s right to payment, and transfer of legal title. In each case, the time between delivery and when payments are due is not significant.

The following table disaggregates the Company’s revenue by source for the three months ended March 31, 2019 and 2018:

l) Income Taxes

The Company accounts for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the consolidated financial statements. Under this method, the Company determines deferred tax assets and liabilities on the basis of the differences between the consolidated financial statements and the tax basis of assets and liabilities by using estimated tax rates for the year in which the differences are expected to reverse.

The Company recognizes deferred tax assets and liabilities to the extent that we believe that these assets and/or liabilities are more likely than not to be realized. In making such a determination, we consider all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax planning strategies, and results of recent operations. If we determine that the Company would be able to realize our deferred tax assets in the future in excess of their net recorded amount, we would make an adjustment to the deferred tax asset valuation allowance, which would reduce the provision for income taxes.

In assessing the realizability of its deferred tax assets, management evaluated whether it is more likely than not that some portion, or all of its deferred tax assets, will be realized. The realization of its deferred tax assets relates directly to the Company’s ability to generate taxable income. The valuation allowance is then adjusted accordingly.

The Company has estimated net operating losses in excess of $12,000,000 at March 31, 2019. The potential benefit of these net operating losses has not been recognized in these financial statements because the Company cannot be assured it is more likely than not that it will utilize the net operating losses carried forward in future years. The net operating loss carryforwards will expire between 2027 through 2037.

m) Stock-Based Compensation

The Company may issue stock options to employees and stock options or warrants to non-employees in non-capital raising transactions for services and for financing costs. The cost of stock options and warrants issued to employees and non-employees is measured on the grant date based on the fair value. The fair value is determined using the Black-Scholes option pricing model. The resulting amount is charged to expense on the straight-line basis over the period in which the Company expects to receive the benefit, which is generally the vesting period.

The fair value of stock options and warrants is determined at the date of grant using the Black-Scholes option pricing model. The Black-Scholes option model requires management to make various estimates and assumptions, including expected term, expected volatility, risk-free rate, and dividend yield. The expected term represents the period of time that stock-based compensation awards granted are expected to be outstanding and is estimated based on considerations including the vesting period, contractual term and anticipated employee exercise patterns. Expected volatility is based on the historical volatility of the Company’s stock. The risk-free rate is based on the U.S. Treasury yield curve in relation to the contractual life of stock-based compensation instrument. The dividend yield assumption is based on historical patterns and future expectations for the Company dividends.

The following table represents stock warrant activity as of and for the three months ended March 31, 2019:

n) Impairment of long-lived assets 

In accordance with ASC 360, "Accounting for the Impairment or Disposal of Long-Lived Assets", the Company is required to review its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable through the estimated undiscounted cash flows expected to result from the use and eventual disposition of the assets. Whenever any such impairment exists, an impairment loss will be recognized for the amount by which the carrying value exceeds the fair value.

Assets are grouped and evaluated at the lowest level for their identifiable cash flows that are largely independent of the cash flows of other groups of assets. The Company considers historical performance and future estimated results in its evaluation of potential impairment and then compares the carrying amount of the asset to the future estimated cash flows expected to result from the use of the asset. If the carrying amount of the asset exceeds estimated expected undiscounted future cash flows, the Company measures the amount of impairment by comparing the carrying amount of the asset to its fair value. The estimation of fair value is generally determined by using the asset's expected future discounted cash flows or market value. The Company estimates fair value of the assets based on certain assumptions such as budgets, internal projections, and other available information as considered necessary. There is no impairment of long-lived assets during the three months ended March 31, 2019 and 2018.

o) Derivative Liability

We review the terms of convertible debt issues to determine whether there are embedded derivative instruments, including embedded conversion options, which are required to be bifurcated and accounted for separately as derivative financial instruments. In circumstances where the host instrument contains more than one embedded derivative instrument, including the conversion option, that is required to be bifurcated, the bifurcated derivative instruments are accounted for as a single, compound derivative instrument

Bifurcated embedded derivatives are initially recorded at fair value and are then revalued at each reporting date with changes in the fair value reported as non-operating income or expense. When the equity or convertible debt instruments contain embedded derivative instruments that are to be bifurcated and accounted for as liabilities, the total proceeds received are first allocated to the fair value of all the bifurcated derivative instruments. The remaining proceeds, if any, are then allocated to the host instruments themselves, usually resulting in those instruments being recorded at a discount from their face value. The discount from the face value of the convertible debt, together with the stated interest on the instrument, is amortized over the life of the instrument through periodic charges to interest expense. 

The Company has evaluated the terms and conditions of its convertible notes. The conversion feature did not meet the definition of “indexed to a company’s own stock” due to the down round protection feature. Therefore, the conversion feature requires bifurcation and liability classification. Additionally, the default put requires bifurcation because it is indexed to risks that are not associated with credit or interest risk. As a result, the compound embedded derivative comprises of (i) the embedded conversion feature and (i) the default put. Rather than bifurcating and recording the compound embedded derivative as a derivative liability, the Company elected to initially and subsequently measure the convertible note in its entirety at fair value, with changes in fair value recognized in earnings. On January 1, 2018, the Company adopted ASU 2017-11, Derivatives and Hedging (Topic 815), and increased beginning retained earnings in the amount of $807,762.

p) Accounting for Asset Retirement Obligations

Asset retirement obligations (“ARO”) primarily represent the estimated present value of the amount the Company will incur to plug, abandon and remediate its producing properties at the projected end of their productive lives, in accordance with applicable federal, state and local laws. The Company determined its ARO by calculating the present value of estimated cash flows related to the obligation. The retirement obligation is recorded as a liability at its estimated present value as of the obligation’s inception, with an offsetting increase to proved properties.

The following table describes the changes in the Company’s asset retirement obligations for the three months ended March 31, 2019: 

q) Undistributed Revenues and Royalties

The Company records a liability for cash collected from oil and gas sales that have not been distributed. The amounts get distributed in accordance with the working interests of the respective owners.

r) Recent Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update No. 2016-02 “Leases” (ASU 2016-02) and subsequently issued supplemental adoption guidance and clarification (collectively, Topic 842). Topic 842 amends a number of aspects of lease accounting, including requiring lessees to recognize right-of-use assets and lease liabilities for operating leases with a lease term greater than one year. Topic 842 supersedes Topic 840 “Leases.” On January 1, 2019, the Company adopted Topic 842 using the modified retrospective approach. Results for reporting periods beginning after January 1, 2019 are presented under Topic 842, while prior period amounts are not adjusted and continue to be reported in accordance with our historical accounting under Topic 840. We elected the package of practical expedients permitted under the transition guidance within Topic 842, which allowed us to carry forward the historical lease classification, retain the initial direct costs for any leases that existed prior to the adoption of the standard and not reassess whether any contracts entered into prior to the adoption are leases. We also elected to account for lease and non-lease components in our lease agreements as a single lease component in determining lease assets and liabilities. In addition, we elected not to recognize the right-of-use assets and liabilities for leases with lease terms of one year or less. Upon adoption of Topic 842, we recorded $367,365 of right-of-use assets and operating lease liabilities as of January 1, 2019. The adoption did not have a material impact on our Consolidated Statements of Operations or Consolidated Statements of Cash Flows

In July 2017, the Financial Accounting Standards Board (“FASB”) issued ASU 2017-11, “Earnings Per Share (Topic 260); Distinguishing Liabilities from Equity (Topic 480); Derivatives and Hedging (Topic 815): (Part 1) Accounting for Certain Financial Instruments with Down Round Features, (Part II) Replacement of the Indefinite Deferral for Mandatorily Redeemable Financial Instruments of Certain Non-public Entities and Certain Mandatorily Redeemable Non-controlling Interests with a Scope Exception” (“ASU 2017-11”). Part I relates to the accounting for certain financial instruments with down round features in Subtopic 815-40, which is considered in determining whether an equity-linked financial instrument qualifies for a scope exception from derivative accounting. Down round features are features of certain equity-linked instruments (or embedded features) that result in the strike price being reduced based on the pricing of future equity offerings. An entity still is required to determine whether instruments would be classified as equity in determining whether they qualify for that scope exception. If they do qualify, freestanding instruments with down round features are no longer classified as liabilities. ASU 2017-11 is effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period. Early adoption is permitted, including in an interim period. We adopted Topic 815 as of January 1, 2018. The effect was to no longer recognize certain freestanding instruments with down round features as a liability, through an increase in beginning retained earnings of $807,762

s) Subsequent events

The Company has evaluated all subsequent events from March 31, 2019, through the date of filing this report, and determined there are no additional items to disclose other than those described in Note 9.

Note 3. Business Acquisition 

Proforma unaudited condensed selected financial data for the three months ended March 31, 2018 as though the Ichor Energy Acquisition had taken place at January 1, 2018 are as follows:

Note 4. Oil and Gas Properties 

The following table summarizes the Company’s oil and gas activities by classification and geographical cost center for the three months ended March 31, 2019:

Note 5. Related Party Transactions

The Company’s CEO and Director, James Doris has previously incurred expenses on behalf of, and made advances to the Company in order to provide the Company with funds to carry on its operations. As of March 31, 2019, the total amount due to Mr. Doris for unreimbursed expenses is $6,183, and is included in accounts payable. Additionally, Mr. Doris has made several loans through promissory notes to the Company, all accruing interest at 12%, and payable on demand. As of March 31, 2019, the total amount due to Mr. Doris for these loans is $395,555 Accrued interest of $69,912 is included in accrued expenses and other current liabilities at March 31, 2019.

The Company’s CFO, Frank W. Barker, Jr., renders professional services to the Company through FWB Consulting, Inc., an affiliate of Mr. Barker’s. As of March 31, 2019, the total amount due to FWB Consulting, Inc. is $114,468, and is included in accounts payable.

Note 6. Capital Stock and Additional Paid-in Capital 

(a) Preferred Stock

The Company is authorized to issue 5,000,000 shares of Preferred Stock, par value $0.001 per share (the “Preferred Stock”), of which 50,000 have been designated as Series C Preferred Stock (the “Series C Preferred Stock”). Each share of Series C Preferred Stock entitles the holder thereof to 10,000 votes on all matters submitted to the vote of the stockholders of the Company. Each share of Series C Preferred Stock is convertible, at the option of the holder, at any time after the date of issuance of such share, at the office of the Corporation or any transfer agent for such stock, into one share of fully paid and non-assessable common stock (the “Conversion Rate”).

(b) Common Stock

On November 5, 2018, the Company amended its Articles of Incorporation to increase the number of shares of common stock the Company is authorized to issue from 100,000,000 to 500,000,000.

During the three months ended March 31, 2019, the Company issued the shares of its common stock as follows:

During the three months ended March 31, 2018, the Company issued the shares of its common stock as follows:

Note 7. Long Term Debt

Long term debt consisted of the following at March 31, 2019 and December 31, 2018:

Note 8. Commitments and contingencies 

In April 2018, the Company’s subsidiary, Petrodome Energy, LLC entered into a 66-month lease for 4,147 square feet of office space for the Company’s corporate office in Houston, Texas. The annual base rent commenced at $22.00 per square foot, and escalates at $0.50 per foot each year through expiration of the lease term. A right-of-use asset and operating lease liability has been recorded with the adoption of Topic 842, pertaining to this office lease. As this lease does not provide an implicit interest rate, we used a portfolio approach to determine a collateralized incremental borrowing rate of 10% based on the information available at the date of adoption of Topic 842 to determine the lease liability. Operating lease expense is recognized on a straight-line basis over the lease term. Operating lease expense was $24,096 for the three months ended March 31, 2019.

From time to time the Company may be a party to litigation involving commercial claims against the Company. Management believes that the ultimate resolution of these matters will not have a material effect on the Company’s financial position or results of operations.

The staff (the “Staff”) of the SEC’s Division of Enforcement has notified the Company, that the Staff has made a preliminary determination to recommend that the SEC file an enforcement action against the Company, as well as against its CEO and it CFO, for alleged violations of Section 17(a) of the Securities Act of 1933 and Section 10(b) of the Securities Exchange Act of 1934 and Rule 10b-5 thereunder during the period from early 2014 through late 2016. The Staff’s notice is not a formal allegation or a finding of wrongdoing by the Company, and the Company is in dialogue with the Staff regarding its preliminary determination. The Company believes it has adequate defenses, and intends to vigorously defend any enforcement action that may be initiated by the SEC.

Note 9. Subsequent Events

On April 5, 2019, the Company borrowed $145,000 from James A. Doris, the Company’s CEO, under a 12% unsecured promissory note payable on demand.

On May 1, 2019, the Company’s subsidiary, Mid-Con Development, LLC sold to an independent third party all of its interests in the oil and gas assets Mid-Con Development, LLC owned in Ellis and Rooks Counties, Kansas, consisting of working interests in approximately 41 oil leases comprising several thousand acres. The sale price was $4,100,000, $3,800,000 of which was applied toward the reserve-based loan (“RBL”) previously provided by CrossFirst Bank to Mid-Con and certain of Viking’s other subsidiaries. The principal balance of the RBL was reduced from approximately $11,400,000 to approximately $7,600,000 as a result of the payment. The balance of the sale proceeds was used for transaction costs and working capital purposes.

On May 10, 2019, Petrodome Louisiana Pipeline LLC ("Petrodome LA"), a subsidiary of Petrodome Energy, LLC, acquired from Legacy Resources Co., L.P. ("Legacy") a majority working interest in 6 gas wells (including 2 producing gas wells), 1 producing oil well and 1 salt water disposal well in Cameron Parish, Louisiana. The purchase price was $2,800,000, before adjustments, and the effective date of the transaction was March 1, 2019. The purchase price after adjustments, paid by Petrodome LA to Legacy on closing was $2,706,143, all of which was funded via a drawdown against the RBL. The principal balance of the RBL was increased to approximately $10,334,143, including a separate advance of $28,000 covering closing costs. CrossFirst Bank has a first mortgage against the assets acquired by Petrodome LA.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

You should read the following discussion and analysis in conjunction with the financial statements and notes thereto appearing elsewhere in this Quarterly Report on Form 10-Q. In preparing the management’s discussion and analysis, the registrant presumes that you have read or have access to the discussion and analysis for the preceding fiscal year.

SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

This document includes “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 or the Reform Act. All statements other than statements of historical fact are “forward-looking statements” for purposes of federal and state securities laws, including, but not limited to, any projections of earning, revenue or other financial items; any statements of the plans, strategies and objectives of management for future operations; any statements concerning proposed new services or developments; any statements regarding future economic conditions of performance; and statements of belief; and any statements of assumptions underlying any of the foregoing. Such forward-looking statements involve known and unknown risks, uncertainties and other factors which may cause the actual results, performance or achievements of the Company to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Such factors include, among others, the following: our ability to raise capital and the terms thereof; ability to gain an adequate player base to generate the expected revenue; competition with established gaming websites; adverse changes in government regulations or polices; and other factors referenced in this Form 10-Q.

The use in this Form 10-Q of such words as “believes”, “plans”, “anticipates”, “expects”, “intends”, and similar expressions are intended to identify forward-looking statements, but are not the exclusive means of identifying such statements. These forward-looking statements present the Company’s estimates and assumptions only as of the date of this Report. Except for the Company’s ongoing obligation to disclose material information as required by the federal securities laws, the Company does not intend, and undertakes no obligation, to update any forward-looking statements.

Although the Company believes that the expectations reflected in any of the forward-looking statements are reasonable, actual results could differ materially from those projected or assumed or any of the Company’s forward-looking statements. The Company’s future financial condition and results of operations, as well as any forward-looking statements, are subject to change and inherent risks and uncertainties.

PLAN OF OPERATIONS

Overview

The Company's business plan is to engage in the acquisition, exploration, development and production of oil and natural gas properties, both individually and through collaborative partnerships with other companies in this field of endeavor. Viking has relationships with industry experts and formulated an acquisition strategy, with emphasis on acquiring under-valued, producing properties from distressed vendors or those deemed as non-core assets by larger sector participants. The Company does not focus on speculative exploration programs, but rather targets properties with current production and untapped reserves. The Company’s growth strategy includes the following key initiatives:

The following overview provides a background for the current strategy being implemented by management.

Acquisitions – Canada

Acquisitions – Kansas

These Kansas properties are operated by third party contractors. The Company’s plans relative to these properties includes the development of the production potential of existing wells and capitalizing on the drilling opportunities that exist within the acreage covered by these working interests. In 2018, the Company began drilling new wells in various Kansas locations.

Acquisitions – Texas, Louisiana and Mississippi

As a part of this acquisition, the Company retained an operational office in Houston, Texas that includes several senior level professionals with over 100 years of combined oil and gas experience which provides the Company the capability of operating many of its own wells internally. This expertise has since been utilized to evaluate additional oil and gas acquisitions, evaluate the profitable management of all of the Company’s oil and gas assets, and evaluate and develop new drilling prospects.

Acquisitions – Texas and Louisiana

This acquisition of these assets is consistent with the location of our Petrodome assets and are effectively managed from our Houston office.

Going Concern Qualification

These accompanying consolidated 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. However, the Company had a net loss of $11,931,481, and $1,552,883 for the three months ended March 31, 2019 and 2018, respectively. Furthermore, as of March 31, 2019, the Company has a working capital deficiency in excess of $48,000,000. The largest components of current liabilities creating this deficiency are (a) notes payable with a face value aggregating approximately $15,000,000 due in August of 2019 and (b) a promissory note payable to the seller of the certain oil and gas interests purchased on December 28, 2018 in the amount of $23,777,948 with all principal and accrued interest due on the earlier of (i) the date the Company or one of its affiliates completes an acquisition with one or more of the Sellers for a purchase price equal to or greater than $50,000,000 or (ii) January 31, 2020.

Management has evaluated these conditions and has developed a plan which, in part, address these obligations as follows:

These conditions raise substantial doubt regarding the Company’s ability to continue as a going concern. The Company’s ability to continue as a going concern is dependent upon its ability to utilize the resources in place to generate future profitable operations, to develop additional acquisition opportunities, and to obtain the necessary financing to meet its obligations and repay its liabilities arising from business operations when they come due. Management believes the Company will be able to continue to develop new opportunities, and will be able to obtain additional funds through debt and / or equity financings to facilitate its development strategy; however, there is no assurance of additional funding being available. These consolidated financial statements do not include any adjustments to the recorded assets or liabilities that might be necessary should the Company have to curtail operations or be unable to continue in existence.

RESULTS OF CONTINUING OPERATIONS

The following discussion of the financial condition and results of operation of the Company for the three months ended March 31, 2019 and 2018, should be read in conjunction with the audited consolidated financial statements and the notes thereto in the Company’s Annual Report on Form 10-K for the year ended December 31, 2018, filed with the SEC on April 1, 2019.

Liquidity and Capital Resources

As of March 31, 2019, and December 31, 2018, the Company had $4,245,050 and $4,009,892 in cash holdings, respectively.

Three months ended March 31, 2019, compared to the three months ended March 31, 2018

Revenue

The Company had gross revenues of $9,346,592 for the three months ended March 31, 2019, as compared to $2,161,947 for the three months ended March 31, 2018, reflecting an increase in excess of 330% or $7,184,645. This substantial increase in revenue is primarily a result of the increased production from the certain oil and gas assets acquired at the end of 2018, but also is reflective of new drilling and enhancements to existing wells.

Expenses

The Company’s operating expenses increased by approximately 133%, or $3,505,158 to $6,125,555 for the three-month period ended March 31, 2019, from $2,620,397 in the corresponding prior period. Lease operating costs increased by approximately 158%, or $1,591,126, to 2,599,394 from $1,008,268 as compared to the three months ended March 31, 2018. DD&A expense, a non-cash expense, increased by $1,881,005, to $2,370,688 from $489,686 for the corresponding period in 2018. General and administrative expenses only reflected an increase of approximately 15%, to $1,033,345 or $132,820, when compared to $900,525 in the corresponding prior period.

Income (loss) from Operations

The Company, through the increased production coming from its latest acquisition, and controlling the cost of operations and administration, has generated an income from operations for the three months ended March 31, 2019 of $3,221,037, when compared to a loss from operations of $458,450 for the three months ended March 31, 2018.

Other Income (Expense)

The Company had other income (expense) of $(15,152,518) for the three months ended March 31, 2019, as compared to $(1,366,222) for the three months ended March 31, 2018. This significant difference is primarily a result of increased interest expense and amortization of debt discount due to increased debt associated with acquisitions, and loss on commodity derivatives.

Net Income (Loss)

The Company incurred a net (loss) of $(11,931,481) during the three-month period ended March 31, 2019, compared with a net loss of $(1,552,883) for the three-month period ended March 31, 2018. The increase in net loss was mainly due to the items referred to in the analysis of operating expenses and other income (expense).

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

We prepare our financial statements in conformity with GAAP, which requires management to make certain estimates and assumptions and apply judgments. We base our estimates and judgments on historical experience, current trends and other factors that management believes to be important at the time the financial statements are prepared and actual results could differ from our estimates and such differences could be material. Due to the need to make estimates about the effect of matters that are inherently uncertain, materially different amounts could be reported under different conditions or using different assumptions. On a regular basis, we review our critical accounting policies and how they are applied in the preparation of our financial statements, as well as the sufficiency of the disclosures pertaining to our accounting policies in the footnotes accompanying our financial statements. Described below are the most significant policies we apply in preparing our consolidated financial statements, some of which are subject to alternative treatments under GAAP. We also describe the most significant estimates and assumptions we make in applying these policies. See “Note 2 - Summary of Significant Accounting Policies” to our consolidated financial statements.

Oil and Gas Property Accounting

The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs of acquisition, exploration and development of oil and natural gas properties (including such costs as leasehold acquisition costs, geological expenditures, dry hole costs, tangible and intangible development costs and direct internal costs) are capitalized as the cost of oil and natural gas properties when incurred.

The full cost method requires the Company to calculate quarterly, by cost center, a “ceiling,” or limitation on the amount of properties that can be capitalized on the balance sheet. To the extent capitalized costs of oil and natural gas properties, less accumulated depletion and related deferred taxes exceed the sum of the discounted future net revenues of proved oil and natural gas reserves, the lower of cost or estimated fair value of unproved not properties subject to amortization, the cost of properties not being amortized, and the related tax amounts, such excess capitalized costs are charged to expense.

Proved Reserves

Estimates of our proved reserves included in this report are prepared in accordance with U.S. SEC guidelines for reporting corporate reserves and future net revenue. The accuracy of a reserve estimate is a function of:

Our proved reserve information included in this report was predominately based on estimates. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.

In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the unweighted arithmetic average of the prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate.

The estimates of proved reserves materially impact depreciation, depletion, amortization and accretion (“DD&A”) expense. If the estimates of proved reserves decline, the rate at which we record DD&A expense will increase, reducing future net income. Such a decline may result from lower market prices, which may make it uneconomic to drill for and produce from higher-cost fields.

Asset Retirement Obligation

Asset retirement obligations (“ARO”) primarily represent the estimated present value of the amount we will incur to plug, abandon and remediate our producing properties at the projected end of their productive lives, in accordance with applicable federal, state and local laws. We determined our ARO by calculating the present value of estimated cash flows related to the obligation. The retirement obligation is recorded as a liability at its estimated present value as of the obligation’s inception, with an offsetting increase to proved properties. Periodic accretion of discount of the estimated liability is recorded as accretion expense in the accompanying consolidated statements of operations.

ARO liability is determined using significant assumptions, including current estimates of plugging and abandonment costs, annual inflation of these costs, the productive lives of wells and a risk-adjusted interest rate. Changes in any of these assumptions can result in significant revisions to the estimated ARO.

Commodity derivatives

The Company does not designate its commodities derivative instruments as hedges and therefore does not apply hedge accounting. Changes in fair value of derivative instruments subsequent to the initial measurement are recorded as change in fair value on derivative liability, in other income (expense). The estimated fair value amounts of the Company’s commodity derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2. Although the Company’s commodity derivative instruments are valued using public indices, as well as the Black-Sholes model, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not required to provide the information under this item.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

The Company does not currently maintain controls and procedures that are designed to ensure that information required to be disclosed by the Company in the reports it files or submits under the Exchange Act are recorded, processed, summarized, and reported within the time periods specified by the Commission’s rules and forms. Disclosure controls and procedures would include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Company in the reports it files or submits under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of management, including the Company’s Chief Executive Officer, the effectiveness of the Company’s disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of March 31, 2019, have been evaluated, and, based upon this evaluation, the Company’s Chief Executive Officer has concluded that these controls and procedures are not effective in providing reasonable assurance of compliance.

Changes in Internal Control over Financial Reporting

Management and directors will continue to monitor and evaluate the effectiveness of the Company's internal controls and procedures and the Company's internal controls over financial reporting on an ongoing basis and are committed to taking further action and implementing additional enhancements or improvements, as necessary and as funds allow. There were no changes in Internal Control Over Financial Reporting during the quarter ended March 31, 2019.

PART II—OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, the Company may be involved in litigation relating to claims arising out of commercial operations in the normal course of business. As of March 31, 2019, there were no pending or threatened lawsuits that could reasonably be expected to have a material effect on the results of operations.

The staff (the “Staff”) of the SEC’s Division of Enforcement has notified the Company that the Staff has made a preliminary determination to recommend that the SEC file an enforcement action against the Company, as well as against its CEO and it CFO, for alleged violations of Section 17(a) of the Securities Act of 1933 and Section 10(b) of the Securities Exchange Act of 1934 and Rule 10b-5 thereunder during the period from early 2014 through late 2016. The Staff’s notice is not a formal allegation or a finding of wrongdoing by the Company, and the Company is in dialogue with the Staff regarding its preliminary determination. The Company believes it has adequate defenses and intends to vigorously defend any enforcement action that may be initiated by the SEC.

ITEM 1A. RISK FACTORS

As a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not required to provide the information under this item.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.

During the quarter ended March 31, 2019, the Company issued 198,056 common shares for services.

The shares described above were issued pursuant to exemptions from registration requirements relying on Section 4(a)(2) of the Securities Act of 1933 and/or Rule 506 of Regulation D promulgated thereunder as there was no general solicitation, and the transactions did not involve a public offering.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

None.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS