FOOTHILLS EXPLORATION, INC. - Quarter Report: 2018 March (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2018

OR

[  ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from __________ to _________

Commission file number 333-190836

FOOTHILLS EXPLORATION, INC.

(Exact name of registrant as specified in its charter)

(720) 449-7478

(Registrant’s telephone number, including area code)

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

Securities registered pursuant to Section 12(g) of the Act:

Indicate by checkmark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes [  ] No [X]

Indicate by checkmark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act. Yes [  ] No [X]

Indicate by checkmark whether the registrant has (1) 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 Website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§229.405 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 checkmark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting 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. [X]

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

As of July 20, 2018, there were 15,050,627 shares of common stock outstanding.

TABLE OF CONTENTS

PART I – FINANCIAL INFORMATION

Item 1. Interim Consolidated Financial Statements

FOOTHILLS EXPLORATION, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

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

FOOTHILLS EXPLORATION, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

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

FOOTHILLS EXPLORATION, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

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

FOOTHILLS EXPLORATION, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1 – Organization

Business

Foothills Exploration, Inc., (“Company”, “Foothills Exploration”, or “Foothills”) was incorporated in the state of Delaware on May 13, 2010, under the name “Key Link Assets Corp.” for the purpose of acquiring a portfolio of heavily discounted real estate properties in the Chicago metropolitan area. The Company changed its focus and planned to acquire small and medium sized grocery stores in non-urban locales that are not directly served by large national supermarket chains.

On May 2, 2016, Foothills Petroleum Inc., a Nevada corporation (“FPI”), acquired over 14.1 million pre-split (56.4 million post-split) shares of the Company’s common stock constituting approximately 96% of our then issued and outstanding shares (“FPI Acquired Shares”). As of May 16, 2016, we effected a 4:1 forward split of our shares of common stock.

On May 27, 2016, the Company entered into a Share Exchange Agreement with shareholders of FPI.

Prior to the Share Exchange, the Company had minimal assets and recognized no revenues from operations and was accordingly classified as a shell company. In light of closing the Share Exchange transaction with the shareholders of FPI, the Company became actively engaged in oil and gas operations and is no longer a shell company.

The consolidated balance sheets include the accounts of the Company, and its wholly-owned direct and indirect subsidiaries, Foothills Exploration, Inc. (“FTXP”), Foothills Petroleum, Inc. (“FPI”), Foothills Exploration, LLC (“FEL”), Foothills Petroleum Operating, Inc. (“FPOI”), Foothills Exploration Operating, Inc. (“FEOI”), Tiger Energy Partners International, LLC (“TEPI”), Tiger Energy Operating, LLC (“TEO”), and Tiger Energy Mineral Leasing, LLC (“TEML”).

The Company’s oil and gas operations are conducted by its wholly owned indirect subsidiaries. FEL is a qualified oil and gas operator in the states of Wyoming and Colorado, and TEO is a qualified oil and gas operator in the state of Utah.

The Company’s operating entities have historically employed, and will continue in the future to employ, on an as-needed basis, the services of drilling contractors, other drilling related vendors, field service companies and professional petroleum engineers, geologists, and landmen as required in connection with future drilling and production operations.

Note 2 – Going Concern

The accompanying consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate continuation of the Company as a going concern. The Company has incurred recurring losses from inception through March 31, 2018, has a working capital deficit at March 31, 2018, of $14,798,342, and has limited sources of revenue. These conditions have raised substantial doubt as to the Company’s ability to continue as a going concern for one year from the issuance of the financial statements. These financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

To address these matters, the Company is actively meeting with investors for possible equity investments, including business combinations; investigating other possible sources to refinance our existing debt; and in continuing discussions with various individuals and groups that could be willing to provide capital to fund operations and growth of the Company.

Note 3 – Summary of Significant Accounting Policies

Principles of Consolidation

The financial statements include the accounts of Foothills Exploration, Inc., and all of its direct and indirect wholly-owned subsidiaries including Foothill Petroleum, Inc., Foothills Petroleum Operating, Inc., Foothills Exploration Operating, Inc., Foothills Exploration LLC, Tiger Energy Partners International, LLC, Tiger Energy Operating, LLC and Tiger Energy Mineral Leasing, LLC. Intercompany balances and transactions have been eliminated in consolidation.

Basis of Presentation and Functional Currency

Pursuant to the rules and regulations of the Securities and Exchange Commission for Form 10-Q, the unaudited condensed consolidated financial statements, footnote disclosures and other information normally included in consolidated financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted. The condensed consolidated financial statements contained in this report are unaudited but, in the opinion of management, reflect all adjustments, consisting of only normal recurring adjustments, necessary for a fair presentation of the consolidated financial statements. All significant inter-company accounts and transactions have been eliminated in consolidation. The results of operations for any interim period are not necessarily indicative of results for the full year. The condensed consolidated balance sheet at December 31, 2017 has been derived from the audited consolidated financial statements at that date but does not include all of the information and footnotes required by accounting principles generally accepted in the United States of America for complete financial statements.

These consolidated financial statements and related notes are presented in accordance with accounting principles generally accepted in the United States of America and are expressed in United States dollars (USD).

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date(s) of the financial statements and the reported amounts of revenues and expenses during the reporting period(s). Management bases its estimates on historical experience and on various assumptions that are believed to be reasonable in relation to the financial statements taken as a whole under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Management regularly evaluates the key factors and assumptions used to develop the estimates utilizing currently available information, changes in facts and circumstances, historical experience and reasonable assumptions. After such evaluations, if deemed appropriate, those estimates are adjusted accordingly. Actual results could differ from those estimates. Significant estimates include those related to assumptions used in impairment testing of long term assets, accruals for potential liabilities and valuing equity instruments issued for services. Actual results could differ from those estimates.

Reclassifications

Certain reclassifications have been made to amounts in prior year to conform to the current year presentation. All reclassifications have been applied consistently to the periods presented and had no effects on previously reported results of operations.

Cash and Cash Equivalents

Cash and cash equivalents include all highly liquid debt instruments with maturity of three months or less.

Restricted Cash

Cash and cash equivalents that are restricted as to withdrawal or use under the terms of certain contractual agreements are recorded in restricted cash in the non-current assets section of our consolidated balance sheet. At March 31, 2018 and December 31, 2017, the Company had restricted cash of $240,000. This amount is being held in escrow for the benefit of the State of Utah for certain properties located in Utah, covered under a certain Modification to Stipulated Order between the Utah Division of Oil, Gas and Mining and TEPI dated August 1, 2014 (Case No. SI/TA-102). These funds held in escrow, will be released to the Company once the Company finishes its reclamation of the various wells in question.

Accounts receivable and allowance for doubtful accounts

Accounts receivable are stated at the historical carrying amount net of an allowance for uncollectible accounts. The carrying amount of the Company’s accounts receivable approximates fair value because of the short-term nature of the instruments. The Company routinely assesses the collectability of all material trade and other receivables.

Trade accounts receivable comprise receivables from joint interest owners which are recorded when the Company incurs expenses on behalf of the non-operator interest owners of the properties the Company operates.

The Company’s oil and gas revenues receivable comprise receivables from purchasers of the Company’s production of oil and gas and other hydrocarbons and from operators of properties in which the Company has a non-operated interest, as well as from joint interest owners of properties the Company operates. As of March 31, 2018, the Company accrued $396,384 of net revenue receivable from EOG Resources, the operator of two wells in which the Company has a working interest, which the Company has been informed that EOG will apply to unpaid invoices of the Company’s share of costs to drill two wells until EOG has recovered those costs. During the three months ended March 31, 2018, those costs were $1,706,625. See Note 4 – Property and Equipment.

The Company’s reported balance of accounts receivable, net of allowance for doubtful accounts, represents management’s estimate of the amount that ultimately will be realized in cash or used in the future to offset an operator’s joint interest billings.

The Company reviews the adequacy of the allowance for doubtful accounts on an ongoing basis, using historical payment trends, the age of the receivables and knowledge of the individual customers or joint interest owners. When the analysis indicates, management increases or decreases the allowance accordingly. However, if the financial condition of our customers were to deteriorate, additional allowances might be required.

Oil and Gas Properties

The Company follows the full cost method of accounting for its investments in oil and gas properties. Under the full cost method, all costs associated with the exploration of properties are capitalized into appropriate cost centers within the full cost pool. Internal costs that are capitalized are limited to those costs that can be directly identified with acquisition, exploration, and development activities undertaken and do not include any costs related to production, general corporate overhead, or similar activities. Cost centers are established on a country-by-country basis.

Capitalized costs within the cost centers are amortized on the unit-of-production basis using proved oil and gas reserves. The cost of investments in unevaluated properties and major development projects are excluded from capitalized costs to be amortized until it is determined whether or not proved reserves can be assigned to the properties. Until such a determination is made, the properties are assessed annually to ascertain whether impairment has occurred. The costs of drilling exploratory dry holes are included in the amortization base immediately upon determination that the well is dry.

For each cost center, capitalized costs are subject to an annual ceiling test, in which the costs shall not exceed the cost center ceiling. The cost center ceiling is equal to: (i) the present value of estimated future net revenues computed by applying current prices of oil and gas reserves (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; plus (ii) the cost of properties not being amortized; plus (iii) the lower of cost or estimated fair value of unproved properties included in the costs being amortized; and less (iv) income tax effects related to differences between the book and tax basis of the properties. If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the cost center ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs.

Support Facilities and Equipment

Our support facilities and equipment are generally located in proximity to certain of our principal fields. Depreciation of these support facilities is calculated on a units-of-production basis.

Maintenance and repair costs that do not extend the useful lives of property and equipment are charged to expense as incurred.

Proved Reserves

Estimates of the Company’s proved reserves included in this report are prepared in accordance with US GAAP and guidelines from the United States Securities and Exchange Commission (“SEC”). The Company’s engineering estimates of proved oil and natural gas reserves directly impact financial accounting estimates, including depreciation, depletion, and amortization expense and impairment. Proved oil and natural gas reserves are the estimated quantities of oil and natural gas reserves that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under period-end economic and operating conditions. The process of estimating quantities of proved reserves is very complex, requiring significant subjective decisions in the evaluation of all geological, engineering and economic data for each reservoir. The accuracy of a reserves estimate is a function of: (i) the quality and quantity of available data; (ii) the interpretation of that data; (iii) the accuracy of various mandated economic assumptions, and (iv) the judgment of the persons preparing the estimate. The data for a given reservoir may change substantially over time as a result of numerous factors, including additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Changes in oil and natural gas prices, operating costs, and expected performance from a given reservoir also will result in revisions to the amount of the Company’s estimated proved reserves. The Company engages independent reserve engineers to estimate its proved reserves.

Fixed Assets

The Company capitalizes expenditures related to property and equipment not directly associated with our production of oil and gas, subject to a minimum rule, that have a useful life greater than one year for: (1) assets purchased; (2) existing assets that are replaced, improved or the useful lives have been extended; or (3) all land, regardless of cost, acquisitions of new assets, additions, replacements and improvements (other than land) costing less than the minimum rule in addition to maintenance and repair costs, including any planned major maintenance activities, are expensed as incurred.

Depreciation is calculated using the straight-line method over the estimated useful lives of the assets.

Office equipment – 3 years

Vehicle(s) – 5 years

Land – not depreciated

Asset Retirement Obligations

The Company follows the provisions of the Accounting Standards Codification ASC 410 - Asset Retirement and Environmental Obligations. The fair value of an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. The Company’s asset retirement obligations relate to the abandonment of oil and gas producing facilities and facilities that support the production of oil and gas. The amounts recognized are based upon numerous estimates and assumptions, including future retirement costs, future inflation rates and the credit-adjusted risk-free interest rate. After recording these amounts, the ARO will be accreted to its future estimated value using the same assumed cost of funds, and the capitalized costs are depreciated on a unit-of-production basis. Both the accretion and the depreciation will be included in depreciation, depletion and amortization expense on our consolidated statements of operations.

Fair Value of Financial Instruments

For certain of the Company’s financial instruments, including cash and equivalents, restricted cash, accounts receivable, accounts payable, accrued liabilities and short-term debt, the carrying amounts approximate their fair values due to their short maturities. ASC Topic 820, “Fair Value Measurements and Disclosures,” requires disclosure of the fair value of financial instruments held by the Company. ASC Topic 825, “Financial Instruments,” defines fair value, and establishes a three-level valuation hierarchy for disclosures of fair value measurement that enhances disclosure requirements for fair value measures. The carrying amounts reported in the consolidated balance sheets for receivables and current liabilities 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:

The Company analyzes all financial instruments with features of both liabilities and equity under ASC 480, “Distinguishing Liabilities from Equity,” and ASC 815. The carrying amounts of the Company’s financial assets and liabilities, including cash, prepaid expenses, accounts payable, accrued expenses, and other current liabilities, approximate their fair values because of the short maturity of these instruments. The fair value of notes payable and convertible notes approximates their fair values since the current interest rates and terms on these obligations are the same as prevailing market rates.

Certain of the Company’s debt and equity instruments include embedded derivatives that require bifurcation from the host contract under the provisions of ASC 815-40, Derivatives and Hedging. The estimated fair value of the derivative warrant instruments was calculated using a Black Scholes valuation model.

The following table sets forth by level within the fair value hierarchy our financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2018 and December 31, 2017:

The Company did not identify any other assets and liabilities that are required to be presented on the consolidated balance sheet at fair value.

Revenue Recognition

The Company recognizes revenue in accordance with the requirements of ASC 606, which directs that it should recognize revenue when a customer obtains control of promised goods or services for an amount that reflects the consideration the entity expects to receive in exchange for those goods or services. All of our revenue is attributable to sales of oil, gas, and other hydrocarbons which are sold daily, with sales aggregated on a monthly basis. In the case of revenue received for a non-operated working interest, we are paid by the operator, which is a joint interest partner and not the purchaser of the product. In the case of revenue received for an operated working interest, we are paid by the marketer to whom we sell the commodities directly pursuant to contractual arrangements.

Debt Issuance Costs, Debt Discount and Detachable Debt-Related Warrants

Costs incurred to issue debt are deferred and recorded as a reduction to the debt balance in our consolidated balance sheets. We amortize debt issuance costs over the expected term of the related debt using the effective interest method. Debt discounts relate to the relative fair value of warrants issued in conjunction with the debt and are also recorded as a reduction to the debt balance and accreted over the expected term of the debt to interest expense using the effective interest method.

Net Earnings (Loss) Per Common Share

The Company computes earnings per share under ASC 260-10, “Earnings Per Share.” The Company’s earnings (loss) per share are computed by dividing net income by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per share reflects the potential dilution of securities, if any, that could share in the earnings (loss) of the Company and are calculated by dividing net income by the diluted weighted average number of common shares. The diluted weighted average number of common shares is computed using the treasury stock method for common stock that may be issued for outstanding stock options, warrants, and convertible debt.

Stock-Based Compensation

All share-based payments, including grants of stock to employees, directors and consultants, are recognized in the consolidated financial statements based upon their estimated fair values.

The Company accounts for stock, stock options, and stock warrants issued for services and compensation by employees under the fair value method. For non-employees, the fair market value of the Company’s stock is measured on the date of stock issuance or the date an option/warrant is granted as appropriate under ASC 718 “Compensation – Stock Compensation”. The Company determined the fair market value of the warrants/options issued under the Black-Scholes Pricing Model. Under the provisions ASC 718, share-based compensation cost is measured at the grant date, based on the fair value of the award, and is recognized as an expense over the employee’s requisite service period (generally the vesting period of the equity grant).

The Company’s accounting policy for equity instruments issued to consultants and vendors in exchange for goods and services follows ASC Topic 505. As such, the value of the applicable stock-based compensation is periodically re-measured and income or expense is recognized during their vesting terms. The measurement date for the fair value of the equity instruments issued is determined at the earlier of (i) the date at which a commitment for performance by the consultant or vendor is reached or (ii) the date at which the consultant or vendor’s performance is complete. In the case of equity instruments issued to consultants, the fair value of the equity instrument is primarily recognized over the term of the consulting agreement. In accordance with FASB guidance, an asset acquired in exchange for the issuance of fully vested, non-forfeitable equity instruments should not be presented or classified as an offset to equity on the grantor’s balance sheet once the equity instrument is granted for accounting purposes.

Recent Accounting Pronouncements

In November 2015, the FASB issued Accounting Standards Update No. 2015-17, Balance Sheet Classification of Deferred Taxes (“ASU 2015-17”). ASU 2015-17 requires companies to classify all deferred tax assets and liabilities as noncurrent on the balance sheet instead of separating deferred taxes into current and noncurrent amounts. The guidance is effective for financial statements issued for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Early adoption is permitted. The guidance may be adopted on either a prospective or retrospective basis. The adoption of ASU 2015-17 did not have a material impact on its consolidated financial statements.

In February 2016, the FASB issued Accounting Standards Update No. 2016-02, Leases (Topic 842) (“ASU 2016-02”). ASU 2016-02 addresses the financial reporting of leasing transactions. Under current guidance for lessees, leases are only included on the balance sheet if certain criteria classifying the agreement as a capital lease are met. This update will require the recognition of a right-of-use asset and a corresponding lease liability, discounted to the present value, for all leases that extend beyond 12 months. For operating leases, the asset and liability will be expensed over the lease term on a straight-line basis, with all cash flows included in the operating section of the statement of cash flows. For finance leases, interest on the lease liability will be recognized separately from the amortization of the right-of-use asset in the statement of operations and the repayment of the principal portion of the lease liability will be classified as a financing activity while the interest component will be included in the operating section of the statement of cash flows. This guidance is effective for annual and interim reporting periods beginning after December 15, 2018. Early adoption is permitted. The Company has not yet completed the analysis of how adopting this guidance will affect its consolidated financial statements.

In March 2016, the FASB issued Accounting Standards Update No. 2016-09, Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”). ASU 2016-09 simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Some of the areas of simplification apply only to nonpublic entities. For public business entities, the amendments in ASU 2016-09 are effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods. The adoption of ASU 2016-09 did not have a material impact on its consolidated financial statements.

In November 2016, the FASB issued ASC Update No. 2016-18 (Topic 230) Statement of Cash Flows – Restricted Cash (a consensus of the FASB Emerging Issues Task Force). The amendments in this update require that restricted cash and restricted cash equivalents be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. Current GAAP does not include specific guidance on the cash flow classification and presentation of changes in restricted cash. The updated guidance is effective for interim and annual periods beginning after December 15, 2017 and is required to be applied using a retrospective transition method to each period presented. The Company implemented this guidance effective January 1, 2018. Implementing this guidance did not have a material impact on the Company’s statement of cash flows, as the restricted cash balance did not change during three month ended March 31, 2018.

In January 2017, the FASB issued Accounting Standards Update No. 2017-01, Clarifying the Definition of a Business (“ASU 2017-01”). The standard clarifies the definition of a business by adding guidance to assist entities in evaluating whether transactions should be accounted for as acquisitions of assets or businesses. ASU 2017-01 is effective for fiscal years beginning after December 15, 2017, and interim periods within those fiscal years. Under ASU 2017-01, to be considered a business, the assets in the transaction need to include an input and a substantive process that together significantly contribute to the ability to create outputs. Prior to the adoption of the new guidance, an acquisition or disposition would be considered a business if there were inputs, as well as processes that when applied to those inputs had the ability to create outputs. Early adoption is permitted for certain transactions. Adoption of ASU 2017-01 will not have a material impact on the Company’s consolidated financial statements.

In January 2017, the FASB issued Accounting Standards Update No. 2017-04, Simplifying the Test for Goodwill Impairment (“ASU 2017-04”). ASU 2017-04 simplifies the accounting for goodwill impairment by removing Step 2 of the goodwill impairment test, which requires a hypothetical purchase price allocation and may require the services of valuation experts. ASU 2017-04 is effective for annual or interim goodwill impairment tests in fiscal years beginning after December 15, 2019 and should be applied on a prospective basis. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. The Company does not carry any Goodwill on its Consolidated Balance Sheets and does not anticipate the adoption of ASU 2017-04 will have a material impact on its consolidated financial statements.

In July 2017, the FASB issued Accounting Standards Update No. 2017-11, Accounting for Certain Financial Instruments with Down Round Features (“ASU 2017-11”). When determining whether certain financial instruments should be classified as liabilities or equity instruments, a down round feature no longer precludes equity classification when assessing whether the instrument is indexed to an entity’s own stock. ASU 2017-11 is effective for annual or interim periods within those fiscal years beginning after December 15, 2018 and should be applied on a retrospective basis. Early adoption is permitted for all entities, including adoption in an interim period. The Company adopted ASU 2017-11 on its consolidated financial statements.

Other recent accounting pronouncements issued by the FASB, including its Emerging Issues Task Force, the American Institute of Certified Public Accountants, and the Securities and Exchange Commission did not or are not believed by management to have a material impact on the Company’s present or future consolidated financial statements.

Note 4 – Property and Equipment

Oil and Gas Properties

The Company’s oil and gas properties at March 31, 2018 and December 31, 2017 are located in the United States of America.

The carrying values of the Company’s oil and gas properties, net of depletion, depreciation, amortization, and impairment at March 31, 2018 and December 31, 2017 are set forth below in the following table:

Support Facilities and Equipment

The Company’s support facilities and equipment serve its oil and gas production activities. The following table summarizes these properties and equipment, together with their estimated useful lives:

The Company recognized depreciation expense of $185 and $0 during the three months ended March 31, 2018 and 2017, respectively.

Office Furniture, Equipment, and Other

As of March 31, 2018 and December 31, 2017, office furniture, equipment, and other consisted of the following:

During the three months ended March 31, 2018 and 2017, we recorded depreciation expense of $1,846 and $18,369, respectively.

Note 5 – Asset Retirement Obligation

The following table provides a reconciliation of the changes in the estimated present value of asset retirement obligations for the three months ended March 31, 2018 and December 31, 2017.

Accretion expense for the three months ended March 31, 2018 and 2017 was $2,917 and $2,917, respectively.

Note 6 – Notes Payable

A summary of the outstanding amounts of our Notes payable as of March 31, 2018 and December 31, 2017 is as follows:

At March 31, 2018, the principal amounts due under our debt agreements were all classified as current on our Consolidated Balance Sheets.

During the three months ended March 31, 2018 and 2017, respectively, we incurred $87,485 and $22,438 of interest expense, including amortization of discount of $2,264 and $0 and shares issued for extension of $46,700 and $0, respectively.

Note 7 – Notes Payable - Related Party

During the three months ended March 31, 2018 and 2017, respectively, we incurred $157,119 and $85,182 of interest expense, including amortization of discount of $57,134 and $57,134 and shares issued for extension of $58,375 and $0, respectively.

Note 8 – Convertible Note Payable

During the three months ended March 31, 2018 and 2017, respectively, we incurred $95,021 and $0 of interest expense, including amortization of discount of $88,511 and $0, respectively.

Note 9 – Common Stock

During the three months ended March 31, 2018, the Company did not issue common stock.

As of March 31, 2018, the Company had 14,900,627 shares of common stock issued and outstanding.

Warrants

On May 27, 2016, the Company granted to Wilshire Energy Partners, LLC, warrants (“Wilshire Warrants”) to purchase (i) 100,000 common shares at a strike price of $1.25 per share, (ii) 200,000 common shares at a strike price of $2.00 per share and (iii) 400,000 common shares at a strike price of $3.00 per share. The Wilshire Warrants commence to be exercisable on the earlier of (i) 12-month anniversary of the closing of a going public transaction or (ii) June 30, 2017 and expire on June 1, 2021.

On May 27, 2016, the Company granted to an unrelated party warrants to purchase (i) 125,000 common shares at a strike price of $1.25 per share, (ii) 100,000 common shares at a strike price of $2.00 per share and (iii) 100,000 common shares at a strike price of $3.00 per share. The warrants commence to be exercisable on the earlier of (i) 12-month anniversary of the closing of a going public transaction or (ii) June 30, 2017 and expire on June 1, 2021.

The fair value of above warrants was determined to be $2,144 on May 27, 2016, using the Black-Scholes option-pricing model based on the following assumptions: (i) volatility rate of 120%, (ii) discount rate of 0%, (iii) zero expected dividend yield, and (iv) expected life of 5 years.

On November 7, 2017, the Company issued 50,000 warrants to purchase 50,000 shares of common stock of the Company at a strike price of $1.00 per share expiring on May 7, 2019 in connection with a senior convertible promissory note in the principal amount of $50,000. If the Company fails to pay the principal and accrued unpaid interest due and payable to Lender on or before the due date of the convertible note, then the Lender shall be provided the right to convert at either $0.665 per share or upon the same terms offered in FirstFire Global Opportunities Fund, LLC Note’s conversion options. The relative fair value of warrant was determined to be $3,381 on November 7, 2017, using the Black-Scholes option-pricing model based on the following assumptions: (i) volatility rate of 77%, (ii) discount rate of 0%, (iii) zero expected dividend yield, and (iv) expected life of 1.5 years.

On November 17, 2017, the Company issued an unaffiliated investor warrants to purchase 267,500 shares of the Company’s common stock at an exercise price of $1.00 per share and expires in 18 months, in connection with a senior convertible promissory note in the principal amount of $267,500. The aggregate relative fair value of warrant was determined to be $10,750 on November 17, 2017, using the Black-Scholes option-pricing model based on the following assumptions: (i) volatility rate of 78%, (ii) discount rate of 0%, (iii) zero expected dividend yield, and (iv) expected life of 1.5 year.

The following table summarizes all stock warrant activity for the three months ended March 31, 2018:

Options

On May 19, 2016, the Company granted to each of its then three directors options to purchase (i) 50,000 common shares at a strike price of $2 per share, vesting when the Company achieves and maintains a total average daily production level of 100 barrels of oil equivalent per day (“BOE/D”) for at least 30 days, (ii) 50,000 common shares at a strike price of $3 per share, vesting when the Company achieves and maintains a total average daily production level of 200 BOE/D for at least 60 days, and (iii) 50,000 common shares at a strike price of $4 per share, vesting when the Company achieves and maintains a total average daily production level of 500 BOE/D for at least 90 days.

On February 27, 2017, the Company granted to Mr. Christopher Jarvis, currently an officer and director, options to purchase 400,000 common shares at a strike price of $1.99 per share, vesting quarterly over two years commencing with the first quarter following the 90-day probationary period.

The fair value of 400,000 options was determined to be $616,055 on February 27, 2017, using the Black-Scholes option-pricing model based on the following assumptions: (i) volatility rate of 129%, (ii) discount rate of 0%, (iii) zero expected dividend yield, and (iv) expected life of 5 years.

On February 27, 2017, the Company granted to Mr. Kevin Sylla, currently our Executive Chairman of the Board, options to purchase 1,200,000 common shares at a strike price of $1.99 per share, vesting quarterly over the term of three years.

The fair value of 1,200,000 options was determined to be $1,986,902 on February 27, 2017, using the Black-Scholes option-pricing model based on the following assumptions: (i) volatility rate of 129%, (ii) discount rate of 0%, (iii) zero expected dividend yield, and (iv) expected life of 7 years.

During the three months ended March 31, 2018 and 2017, we recorded $239,259 and $68,861 option expense. As of March 31, 2018, the unamortized option expense was $1,547,559.

The following table summarizes all stock option activity for the three months ended March 31, 2018:

Note 10– Other Related Party Transactions

Wilshire Energy Partners, LLC

Wilshire Energy Partners, LLC, is controlled by Kevin J. Sylla, our Executive Chairman and Chief Executive Officer of FPI, and has been determined to be a Related Party. During the three months ended March 31, 2018 and 2017, Wilshire advanced the Company $55,210 and $0 for operating purposes, respectively.

Note 11 – Commitments and Contingencies

Contractual Obligations

Operating Leases

Effective May 1, 2017, the Company entered into a 39-month lease, expiring July 31, 2020, for its Denver, Colorado, corporate office at a total rental of approximately $10,051 per month. During the three months ended March 31, 2018, the Company paid $0 for its Denver office space, redeemed unused allowance for tenant improvements which was contractually allowed to offset monthly rental payments of $17,180 and recorded $17,180 as other income.

On October 5, 2016, the Company launched its Exploration Division and opened a new office in Houston, Texas, to support the division’s staff, at a monthly rental amount of $2,298. On March 27, 2018, the Company closed that office. During the three months ended March 31, 2018 and 2017, the Company accrued $6,366 and $3,600 in rent expense and paid $0 and $2,400 for its Houston office space.

The Company leases a copier at monthly rental of $135 through September 23, 2020, for its Denver, Colorado, office. During the three months ended March 31, 2018, the Company accrued $405 and paid $0 in rental for the copier.

Information regarding all the Company’s contractual lease obligations, at March 31, 2018, is set forth in the following table.

Legal proceedings

The Company has determined that judgments rendered in the first quarter of 2018 in connection with all but four of the following legal proceedings against the Company are Type 1 subsequent events that provide additional evidence with respect to conditions that existed at the date of the balance sheet. Therefore, the financial statements reflect the effects of prejudgment judgments awards to plaintiffs as through March 31, 2018, noted below in accordance with Auditing Standard 2801.03.

Utah Wells

Graco Fishing & Rental Tools, Inc. vs. Tiger Energy Operating LLC (Case No. 160800005 8^th Judicial District Court, Duchesne County, State of Utah)

Plaintiff in this case sought collection of unpaid debt incurred by TEO for services rendered in connection with its workover of wells in Duchesne County, Utah. On June 1, 2016, a default judgment of $159,965 was obtained against TEO by Plaintiff. Graco filed a writ of execution against the A Rust 2, Dye-Hall 2-21 A1, Wilkins 1-24 A5 and Rust 3-22A-4 wells located in Duchesne County executing on properties not owned by us. A Motion to Set Aside the sheriff’s sale of these properties was filed with the court based on the fact that TEO was not the owner of these properties. A hearing for this matter was held on May 1, 2017, in Duchesne County, Utah, at which time a Company representative was present to comply with the court’s order to produce documents. Prior to the hearing, TEO made an initial settlement offer, which was eventually rejected by Graco. A writ of execution was issued to seize the property subject of litigation on March 8, 2018.

Graco had scheduled certain foreclosure sales of TEO’s interests in various oil and gas wells to take place on May 3, 2018 (the “Sales”). On April 27, 2018, the parties reached a settlement and release agreement whereby TEO agreed to make five (5) payments totaling $163,964.59 to Graco. The first payment due on May 9, 2018, has already been made to the judgment holder. The second payment of $32,792.92 is due on July 9, 2018; the third payment of $32,792.92 is due on September 9, 2018; the fourth payment of $32,792.92 is due on November 9, 2018; and fifth and final payment of $32,792.92 is due on January 9, 2019. If any of the above payments are not made when due, Grace will have the right to immediately execute the Sales. Graco will maintain and apply liens and notices of its judgment until the total payment has been paid in full by TEO. TEO shall be provided with a 10-day period within which to cure any default under the settlement agreement, other than making the first payment described above. TEO made its second payment of $32,793 on July 19, 2018, within the 10-day cure period provided in the settlement agreement.

Conquest Well Servicing, LLC vs. Foothills Exploration Operating, Inc. (Case No. 179800421 8^th Judicial District Court in and for Uintah County, State of Utah)

Plaintiff filed this action on September 11, 2017, for collection of unpaid services and materials in the amount of $49,689 in connection with a workover of wells in Uintah County, Utah. A Settlement Agreement and Stipulation to Entry of Judgment was agreed to by the parties and filed with the court on October 10, 2017. Judgment in the amount of $54,937.10 including $5,248.10 in pre-judgement interest was filed on December 18, 2017. An order requesting company asset inquiry was issued on February 20, 2018. As of July 26, 2018, no further action has been taken. As of March 31, 2018, we recorded $6,621.59 of prejudgment interest expense.

Peak Well Service, LLC v. Tiger Energy Operating, LLC (Case No. 2:16-CV-00957-EJF United States District Court for the District of Utah Court)

Peak Well Service, LLC (“Peak”), filed mechanics and materialman’s liens against the Wilkins, Rust 2 Well, Dye Hall 2, Rust 3, and Josie 1 wells operated by TEO for unpaid accounts in connection with work on these wells. A settlement was reached between TEO and Peak pursuant to a confidential settlement agreement. Pursuant to the settlement agreement, lien releases on each of these well liens were filed on February 8, 2017. This settlement is a final resolution of this creditor claim.

BIA Administrative Appeal – Tiger Energy Partners International, LLC

This Administrative appeal concerns the ownership and validity of Northern Ute (the “Tribe”) Tribal leases acquired by Tiger Energy Partners International, LLC (TEPI) in a transaction with Mountain Oil and Gas and its affiliated companies. Pursuant to the Global Settlement Agreement (GSA) negotiated between the Tribe and TEPI, the Company proposes to resolve any issues regarding the ownership of the subject leases and other lands thus acquired. The status of the appeal by TEPI remained unchanged at December 31, 2017, awaiting decision by the Regional Director of the BIA on the merits of the appeal. The decision of the Regional Director is stayed by the parties having entered into the GSA. The Tribe and Tiger remain in discussion regarding approval of the Global Settlement Agreement by the Regional Director.

Labokay Well – Parish of Calcasieu, State of Louisiana

R.W. Delaney Construction Company vs. Foothills Petroleum Operating, Inc. (Cause No. 2017-CV-0330 – County Court of Adams County, Mississippi)

This case was filed on September 18, 2017 and concerns the collection of amounts incurred by FPOI for services performed by plaintiff in the amount of $72,495 in connection with drilling the Labokay test well in Calcasieu Parish, Louisiana.

A judgment was entered on January 22, 2018, in the County Court of Adams County, Mississippi in the principal amount of $72,495.00, plus pre-judgement interest in the amount of $12,763, plus attorney’s fees in the amount of $18,124, plus costs in the amount of $196, for a total amount of $103,578, plus post-judgment interest at the rate of 8% per annum. On May 9, 2018, District Court for the City and County of Denver, Colorado, granted plaintiff with an order granting their petition to domesticate this foreign judgment with the Denver District Court, which now has the same effect and is subject to the same procedures, defenses, and proceedings for reopening, vacating, or staying as a judgment from the Denver District Court, and may be enforced or satisfied in like manner.

Performance Drilling Company, LLC vs. Foothills Petroleum Operating, Inc. (Case No. 2017-3916 DIV G 14^th Judicial District Court in Parish of Calcasieu, State of Louisiana)

This case was filed on September 25, 2017, for payment of services performed by plaintiff in the amount of $205,251 for unpaid accounts in connection with its drilling of the Labokay test well. On January 16, 2018, a default judgment was entered against FPOI, in the amount of $205,251.24; together with accrued interest of $29,861 from March 18, 2017, through December 31, 2017; plus, additional interest from January 1, 2018, at the rate of one and one-half percent (1.5%) per month until paid (a per diem rate of $103.69); plus, an additional sum for reasonable attorney’s fees of $2,500, and all costs of the court proceedings. As of March 31, 2018, we recorded $39,097.74 of prejudgment interest expense.

Monster Rentals, LLC dba Deepwell Equipment Rentals vs. Foothills Petroleum Operating, Inc. (Case No. 2017-11013 DIV E – 15^th Judicial District Court in Parish of Acadia, State of Louisiana)

This case was filed on October 24, 2017 and concerns the collection of amounts incurred by FPOI for services performed by plaintiff in the amount of $53,943.53 in connection with the Labokay test well in Calcasieu Parish, Louisiana.

Canal Petroleum Products, Inc. vs. Foothills Petroleum Operating, Inc. (Case No. 2017-6574; DIV. C – 15^TH Judicial District Court, Lafayette Parish, Louisiana)

This case was filed on November 14, 2017 and concerns the collection of amounts incurred by FPOI for services performed by plaintiff in the amount of $35,981 for unpaid accounts in connection with its drilling of the Labokay test well.

On January 25, 2018, a default judgment was entered against FPOI in the amount of $35,981 inclusive of interest as of September 6, 2017; plus, finance charges to accrue after September 6, 2017, of one and one-half percent per month (18% per annum) until paid on the unpaid principal amount of $32,956; plus, legal fees of $8,239 together with related court costs.

As of March 31, 2018, we recorded $6,485 of prejudgment interest expense.

Smith International, Inc. vs. Foothills Petroleum Operating, Inc. (Case No. 2017-004617; DIV. E – 14^th Judicial District Court, Calcasieu Parish, Louisiana)

This case was filed on November 7, 2017 and concerns the collection of amounts incurred by FPOI for services performed by plaintiff in the amount of $30,244 in connection with its drilling of the Labokay test well.

On March 23, 2018, the court issued a preliminary judgement in favor of plaintiff in the amount of $30,244, plus interest in the contractual amount of 18% per annum from the date the payment was originally due until the judgment date, plus legal interest from the judgment date until amounts are paid, plus reasonable attorneys’ fees. As of March 31, 2018, we recorded $3,474.28 of prejudgment interest expense.

M-I, L.L.C. d/b/a MI-SWACO vs. Foothills Petroleum Operating, Inc. (Case No. 2017-004616; DIV. G – 14^th Judicial District Court, Calcasieu Parish, Louisiana)

This case was filed on November 7, 2017 and concerns the collection of amounts incurred by FPOI for services performed by plaintiff in the amount of $51,275 in connection with the Labokay test well.

On March 23, 2018, the court issued a preliminary judgment in favor of plaintiff in the amount of $51,275, plus interest in the contractual amount of 1.5% per month from the date the payment was originally due until the judgement date, plus legal interest from the judgment date until amounts are paid, plus reasonable attorney’s fees expended in the prosecution and collection of debt. As of March 31, 2017, we recorded $3,845 of prejudgment interest expense.

Schlumberger Technology Corporation vs. Foothills Petroleum Operating, Inc. (Case No. 2017-004618; DIV. E – 14^th Judicial District Court, Calcasieu Parish, Louisiana)

This case was filed on November 7, 2017 and concerns the collection of amounts incurred by FPOI for services performed by plaintiff in the amount of $28,904 for unpaid accounts in connection with its drilling of the Labokay test well in Calcasieu Parish, Louisiana.

On March 23, 2018, the court issued a preliminary judgment in favor of plaintiff in the amount of $28,904, plus interest in the contractual amount of 1.5% per month from the date the payment was originally due until the judgment date, plus legal interest from the judgment date until amounts are paid, plus reasonable attorney’s fees expended in the prosecution and collection of debt.

As of March 31, 2018, and December 31, 2017, the balance of contingent liabilities was $327,891 and $305,935, respectively. During the three months ended March 31, 2018 and 2017, we recorded $21,956 and $0 in contingent liabilities.

Note 12 – Subsequent Events

Completion of two non-operated exploratory wells

In Q2 2018, the two non-operated exploratory wells in which the Company has a 21.62% working interest and 17.1% net revenue interest were completed, and the costs shown as “construction in progress” will be reclassified to oil and gas properties subject to amortization in the second quarter of 2018. See Note 4 – Property and Equipment.

Extension of Debt Maturity

13.5% unsecured note payable due September 8, 2017

The Company and Profit Well are in ongoing discussions to extend the term of this Note and the Company believes it will either extend, rework or repay the obligation to the satisfaction of Profit Well. On July 29, 2018, as partial consideration for the deferral, the Company agreed to issue Profit Well 100,000 shares of its restricted common stock.

8% convertible note payable due August 16, 2018

In June 2018, the Company made a principal payment in the amount of $100,000. Furthermore, the Company agreed to pay the remaining balance of $229,025 on or before thirty-five (35) days from June 5^th, 2018. The Note may be converted if the Note Balance is not paid on or before thirty-five (35) days from June 5^th 2018. FirstFire agreed that the Note is not in default. As consideration for agreeing to provide the Company with this extension of time to pay, the Company issued the investor 150,000 shares of restricted common stock, valued at $18,000.

Extension of Debt Maturity – Related Party

13.25% unsecured note payable due May 5, 2017

The Company and Berwin are in ongoing discussions to extend the term of this Note and the Company believes it will either extend, rework or repay the obligation to the satisfaction of Berwin. On July 29, 2018, as partial consideration for the deferral, the Company agreed to issue Berwin 100,000 shares of its restricted common stock.

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

This report contains forward-looking statements. All statements other than statements of historical facts included in this Quarterly Report on Form 10-Q, including without limitation, statements in this Management’s Discussion and Analysis of Financial Condition and Results of Operations regarding our financial position, estimated working capital, business strategy, the plans and objectives of our management for future operations and those statements preceded by, followed by or that otherwise include the words “believe,” “expects,” “anticipates,” “intends,” “estimates,” “projects,” “target,” “goal,” “plans,” “objective,” “should” or similar expressions or variations on such expressions are forward-looking statements. We can give no assurances that the assumptions upon which the forward-looking statements are based will prove to be correct. Because forward-looking statements are subject to risks and uncertainties, actual results may differ materially from those expressed or implied by the forward-looking statements. There are a number of risks, uncertainties and other important factors that could cause our actual results to differ materially from the forward-looking statements, including, but not limited to, our inability to obtain adequate financing, insufficient cash flows and resulting illiquidity, our inability to expand our business, government regulations, lack of diversification, volatility in the price of oil and/or natural gas, increased competition, results of arbitration and litigation, stock volatility and illiquidity, our failure to implement our business plans or strategies and general economic conditions. A description of some of the risks and uncertainties that could cause our actual results to differ materially from those described by the forward-looking statements in this Quarterly Report on Form 10-Q appears in the section captioned “Risk Factors” in our 2017 Amendment No. 1 to our Annual Report on Form 10-K/A.

Except as otherwise required by the federal securities laws, we disclaim any obligations or undertaking to publicly release any updates or revisions to any forward-looking statement contained in this Quarterly Report on Form 10-Q to reflect any change in our expectations with regard thereto or any change in events, conditions or circumstances on which any such statement is based.

History

Foothills Exploration, Inc. (the “Company”) was incorporated in the state of Delaware on May 13, 2010, under the name “Key Link Assets Corp.” for the purpose of acquiring a portfolio of heavily discounted real estate properties in the Chicago metropolitan area. The Company changed its focus and planned to acquire small and medium sized grocery stores in non-urban locales that are not directly served by large national supermarket chains.

On May 2, 2016, Foothills Petroleum Inc., a Nevada corporation (“FPI”) acquired approximately 14.1 million pre-split (56.4 million post-split) shares of the Company’s common stock constituting approximately 96% of our then issued and outstanding shares (“FPI Acquired Shares”). As of May 16, 2016, we effected a 4:1 forward split of our shares of common stock.

On May 27, 2016, the Company entered into a Share Exchange Agreement with shareholders of FPI whereby we acquired all of the outstanding shares of FPI in exchange for 4,500,000 shares of our common stock and also issued 1,503,759 shares of our common stock on automatic conversion of debt (please see discussion below under Overview) for an aggregate of 6,003,759 shares of our common stock (the “Share Exchange”). As a result of the Share Exchange, FPI became our wholly owned subsidiary and the FPI Acquired Shares were returned to treasury and deemed cancelled. For accounting purposes, this transaction is being accounted for as a reverse acquisition and has been treated as a recapitalization of the Company with FPI considered the accounting acquirer, and the financial statements of the accounting acquirer became the financial statements of the registrant. The completion of the Share Exchange resulted in a change of control. The FPI Shareholders obtained approximately 96% of voting control on the date of Share Exchange. FPI was the acquirer for financial reporting purposes and the Company was the acquired company. The consolidated financial statements after the acquisition include the balance sheets of both companies at historical cost, the historical results of FPI and the results of the Company from the acquisition date. All share and per share information in the accompanying consolidated financial statements and footnotes have been retroactively restated to reflect the recapitalization.

Prior to the Share Exchange, we had minimal assets and recognized no revenues from operations and were accordingly classified as a shell company. On June 24, 2016, we filed an Amendment No. 1 to our Current Report on Form 8-K originally filed on June 10, 2016, indicating that we were no longer a shell company as defined by Rule12b-2 of the Exchange Act. In light of the closing of the Share Exchange, the Company became actively engaged in oil and gas operations.

On August 4, 2016, the Financial Industry Regulatory Association (“FINRA”) approved our name change from Key Link Assets Corp. to Foothills Exploration, Inc., and a change of trading symbol from KYLK to FTXP.

On October 5, 2016, the Company launched its Exploration Division and opened a new office in Houston to support the division’s staff. That division consisted of geologists and petroleum engineers engaged in the exploration and development of hydrocarbons who were tasked with building a portfolio of high impact exploration projects in the Gulf Coast region. On March 27, 2018, we closed that office.

On December 12, 2016, the Company entered into a participation agreement with Magna Operating, LLC, a privately held Houston-based independent exploration and production company (“Magna Operating”), in relation to the Labokay prospect, covering approximately 240 acres in Calcasieu Parish, Louisiana. As consideration for an assignment of interest in and to the leases and the prospect, Foothills Petroleum Operating, Inc., a Nevada corporation and indirect wholly-owned subsidiary of the Company (“FPOI”), tendered to Magna Operating the purchase price in the amount of $144,000. This amount covered FPOI’s share of the land, lease, and administrative costs that Magna Operating incurred in generating and assembling the Labokay prospect as of November 15, 2016. As further consideration for an assignment of working interest in and to the leases, FPOI agreed to participate in the cost, risk, and expense of drilling the Labokay test well. The well was plugged and abandoned in February 2017. The Company has no immediate plans to engage in further exploration and development activities in the U.S. Gulf Coast region.

On December 30, 2016, the Company acquired various oil and gas assets (the “Uinta Agreement”). These assets included certain oil and gas wells throughout the Uinta Basin in Utah on acreage with over 30 proved undeveloped drilling locations, additional non-operated interest in other leases, and access to approximately 5,600 acres in the Uinta Basin with proved and probable reserves and existing infrastructure in place. Through the acquisition, Foothills also obtained six shut-in wells in the Natural Buttes Field, Utah. The transaction provided Foothills with the rights to an agreement to acquire up to 5,600+ acres and up to 16 shut-in oil and gas wells with proved and proved undeveloped reserves on Tribal lands in the Uinta Basin. This acquisition delivered to the Company an additional 40% working interest in the Ladysmith Prospect covering 3,060 acres in the Greater Green River Basin, Wyoming, bringing the Company’s total working interest in the prospect from 35% (pre-acquisition) up to 75%.

Pursuant to the Uinta Agreement the Company acquired 13,166,667 shares, constituting 55.6% of the outstanding shares of Grey Hawk Exploration, Inc. (“Grey Hawk”), a British Columbia, Canada company. Grey Hawk owns a non-operated working interest in two non-producing wells in the southern portion of the Natural Buttes Field.

On December 30, 2016, the Company acquired the remaining 25% membership interest in TEPI from Green Stone Capital Partners Limited, a Cayman Islands limited liability company, in exchange for assumption of Greenstone’s proportionate share of TEPI obligations and liabilities.

Effective August 28, 2017, the Company acquired a 21.6% working interest, with a 17.1% net revenue interest, in two (2) exploratory, horizontal wells in Uintah County, Utah, from an undisclosed party. These wells were drilled through an existing wellbore into an unproved reservoir. Both wells are operated by EOG Resources, Inc. (NYSE: EOG) (“EOG”). At March 31, 2018, total well costs for our working interest share in both wells amounted to $3,205,724.   These wells align with the Company’s overall growth strategy for the basin and provide us with the ability to gain insight from a world-class operator. The Stagecoach 111-20H and Stagecoach 117-20H horizontal wells both commenced producing natural gas liquids, and residue gas in commercial quantities in December 2017, despite the wells having not yet been completed. These two successful horizontal wells are expected to generate production and net cash flow for the Company subject to the Company’s payment to EOG of the Company’s share of costs incurred in the drilling and completion of the wells.

Our principal office is located at 633 17th Street, Suite 1700, Denver, Colorado 80202. Our telephone number is (720) 449-7478. Our website address is www.foothillspetro.com.

Overview and Going Concern

The Company is an exploration stage company engaged in the acquisition and development of oil and natural gas properties. The Company is focused on acquiring producing and developmental properties in the U.S. Rocky Mountain region. The Company seeks to acquire non-core, dislocated, underdeveloped, and underexplored oil and gas assets and maximize those assets to create shareholder value.

Going Concern

The accompanying consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America, which contemplate continuation of the Company as a going concern. The Company has incurred recurring losses from inception through March 31, 2018, has a working capital deficit at March 31, 2018, of $14,798,342, and has limited sources of revenue. These conditions have raised substantial doubt as to the Company’s ability to continue as a going concern for one year from the issuance of the financial statements. These financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

To address these matters, the Company is actively meeting with investors for possible equity investments, including business combinations; investigating other possible sources to refinance our existing debt; and in continuing discussions with various individuals and groups that could be willing to provide capital to fund operations and growth of the Company.

Wyoming Properties

The principal Wyoming assets that we own currently consist of non-producing, prospective mineral leases in the Ladysmith and Paw Paw projects. Our Wyoming properties are located in Fremont and Big Horn Counties, Wyoming.

Ladysmith Project

We own a 75% working interest in the Ladysmith Anticline prospect that is located in Fremont County, Wyoming. Total acreage position is 3,061 gross acres located between the Great Divide/Greater Green River Basin and the Wind River Basin. The primary target zones are the variable Phosphoria and Tensleep sandstone with secondary considerations in the Madison limestone and Flathead sandstone. The prospect generation was based on licensed 2-D seismic comprising two seismic lines covering the Chevron/Echo – Greater Green River Basin.

Paw Paw Project

The Paw Paw project is a 3-D seismic defined prospect, which covers 4,467 net acres and is a direct analog to the highly productive Tensleep Formation “Enigma” Field (EUR 3.7 million barrels of oil) located only two miles to the south. We own 100% working interest in 2,560 net acres of this project before Payout and this working interest is reduced to 75% after Payout. The Tensleep Formation has a history of prolific area production with two nearby analogous reservoirs. The Paw Paw project has potential from primary and secondary recovery of up to 2 million barrels of oil. On December 11, 2016, the Company completed drilling operations on the Paw Paw Federal #1 test well. The Big Horn County Wyoming test well reached total depth in the Madison Formation and the Company successfully logged and acquired valid data to further evaluate the project’s potential.

The Paw Paw Federal #1 test well reached total depth of 4,500 feet in the Madison Formation after drilling an anticipated stratigraphic section and thrust fault. Oil shows were found in the Muddy, Phosphoria, and Madison formations. The Phosphoria is a regionally productive formation and could end up being the secondary zone in sidetrack operations should that type of operation be deemed commercially economic.

As used herein, the term “Payout” shall be deemed to occur at 7:00 a.m. on the first day in which Foothills recovers out of its share of production from the Paw Paw Federal #1 (“Test Well”), after deduction of all royalties, existing overriding royalties, production or severance taxes, and any other burdens or taxes measured by or payable out of production, a sum equal to the aggregate of the following:

Utah Properties

The Utah properties are located in Uintah and Duchesne Counties, comprising operated and non-operated working interests as well as rights and interests in a project for future development.

The Company operates through TEO six oil and gas wells situated on 280 gross acres (224 net) in the Duck Creek area of the Altamont Bluebell field located in Uintah County, Utah, in which the Company has a 100% working interest with an 80% net revenue interest.

The Company owns all rights and interests pertaining to the Global Settlement Agreement (“GSA”) for the Uintah and Ouray Reservation among Mountain Oil & Gas, Inc (‘MOG”) and entities associated with MOG and the Ute Indian Tribe of the Uintah and Ouray Reservation, dated December 22, 2014. The Company also owns all rights and interests acquired in the Purchase and Sale Agreements between TEPI and Mountain Oil & Gas, Inc. dated April 16, 2012, and December 18, 2012. The Company expects to move forward with this transaction in 2018 via a revised Global Settlement Agreement with the parties to said agreement.

The Company owns a very small (under 1%) non-operated working interest in certain leases located in Duchesne County, Utah. The Company recognized approximately $4,532 in net revenues during 2017 from this non-operated working interest.

On August 28, 2017, the Company acquired a 21.6% non-operated working interest with a 17.1% net revenue interest in two horizontal wells in the Uintah Basin (“Basin”). First sales from the two wells were made in December 2017, and the well was expected to be completed in Q2 2018.

Results of Operations

Three months ended March 31, 2018 compared to three months ended March 31, 2017

Revenue

The following table summarizes our revenues from commodity sales during the three months ended March 31, 2018 and 2017.

Operating Expenses

Operating expenses for the three months ended March 31, 2018 and 2017, are set forth in the table below.

Operating expenses expressed in BOE for the three months ended March 31, 2018 and 2017 are set forth in the table below:

Interest Expense

Interest expense for the three months ended March 31, 2018 and 2017, was $339,625 and $110,518, respectively. The increase in interest expense is primarily attributed to additional compensation related to notes payable extension during the three months ended March 31, 2018.

Gain on Change in Derivative Value

Gain on change in derivative value for the three months ended March 31, 2018 and 2017, was $45,025 and $0, respectively. The change in derivative value is primarily attributed to an additional convertible note entered into during November 2017.

Other Income

Other income for the three months ended March 31, 2018 and 2017, was $17,180 and $0, respectively. The increase in other income is primarily attributed to a credit provided by the lessor of our Denver office for an unused allowance for tenant improvements which was contractually allowed to offset monthly rental payments for the three months ended March 31, 2018.

Net Loss

As a result of the foregoing, our net loss for the three months ended March 31, 2018, was $861,845 ($0.06) per basic and diluted common share). Our net loss for the three months ended March 31, 2017, was $2,159,499 ($0.15) per basic and diluted common share).

Liquidity and Capital Resources

Overview

As of March 31, 2018, the Company had a working capital deficit of $14,798,342. As of December 31, 2017, the Company had a working capital deficit of $13,024,813. The increase of $2,013,529, in the working capital deficit was attributable as follows:

Cash, Cash equivalents, restricted cash and Accounts Receivable

As of March 31, 2018, the Company had cash of $0, compared to $555 at December 31, 2017.

As of March 31, 2018, the Company has restricted cash of $240,000, compared to $240,000 at December 31, 2017.

As of March 31, 2018, the Company had accounts receivable of $396,628, compared to $32,671 at December 31, 2017. This increase in accounts receivable is due primarily to production of two horizontal wells.

Liabilities

As of March 31, 2018, the outstanding balance of principal and accrued interest on debt was $9,305,587 a net increase of $86,641 from the outstanding balance of $9,218,947 as of December 31, 2017. This net increase was due to accrued interest on notes payable.