UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended September 30, 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 1-32955

HOUSTON AMERICAN ENERGY CORP.

(Exact name of registrant as specified in its charter)

Delaware	76-0675953
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)

801 Travis Street, Suite 1425, Houston, Texas 77002

(Address of principal executive offices)(Zip Code)

(713) 222-6966

(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, a smaller reporting company or an emerging growth company. See definition of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and an “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	[  ]	Accelerated filer	[  ]	Non-accelerated filer	[  ]
Smaller reporting company	[X]	Emerging growth company	[  ]

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]

As of November 5, 2018, we had 62,222,777 shares of $0.001 par value common stock outstanding.

HOUSTON AMERICAN ENERGY CORP.

FORM 10-Q

INDEX

		Page No.
PART I.	FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Consolidated Balance Sheets as of September 30, 2018 and December 31, 2017 (Unaudited)	3
	Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2018 and 2017 (Unaudited)	4
	Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2018 and 2017 (Unaudited)	5
	Notes to Consolidated Financial Statements (Unaudited)	6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	13
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	17
Item 4.	Controls and Procedures	18
PART II	OTHER INFORMATION
Item 6.	Exhibits	18

2

PART I - FINANCIAL INFORMATION

ITEM 1 Financial Statements

HOUSTON AMERICAN ENERGY CORP.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2018			December 31, 2017
ASSETS
CURRENT ASSETS
Cash	$	785,346		$	392,062
Accounts receivable – oil and gas sales		351,625			347,548
Prepaid expenses and other current assets		27,203			3,750
TOTAL CURRENT ASSETS		1,164,174			743,360
PROPERTY AND EQUIPMENT
Oil and gas properties, full cost method
Costs subject to amortization		60,014,246			60,139,526
Costs not being amortized		2,454,650			2,309,341
Office equipment		90,004			90,004
Total		62,558,900			62,538,871
Accumulated depletion, depreciation, amortization, and impairment		(55,992,976	)		(55,725,080	)
PROPERTY AND EQUIPMENT, NET		6,565,924			6,813,791
Other assets		3,167			3,167
TOTAL ASSETS	$	7,733,265		$	7,560,318
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Accounts payable	$	49,675		$	127,036
Accrued expenses		2,420			24,621
TOTAL CURRENT LIABILITIES		52,095			151,657
LONG-TERM LIABILITIES
Reserve for plugging and abandonment costs		37,980			35,658
Deferred rent obligation		45,285			49,245
TOTAL LONG-TERM LIABILITIES		83,265			84,903
TOTAL LIABILITIES		135,360			236,560
COMMITMENTS AND CONTINGENCIES
SHAREHOLDERS’ EQUITY
Preferred stock, par value $0.001; 10,000,000 shares authorized
Series A Convertible Redeemable Preferred Stock, par value $0.001; 2,000 shares authorized; 1,085 and 1,175 shares issued and outstanding, respectively; liquidation preference of $1,085,000		1			1
Series B Convertible Redeemable Preferred Stock, par value $0.001; 1,000 shares authorized; 835 and 895 shares issued and outstanding, respectively; liquidation preference of $835,000		1			1
Common stock, par value $0.001; 150,000,000 shares authorized 62,209,073 and 59,260,101 shares issued and outstanding, respectively		62,209			59,260
Additional paid-in capital		73,069,501			72,482,303
Accumulated deficit		(65,533,807	)		(65,217,807	)
TOTAL SHAREHOLDERS’ EQUITY		7,597,905			7,323,758
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	7,733,265		$	7,560,318

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

3

HOUSTON AMERICAN ENERGY CORP.

CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2018 AND 2017

(Unaudited)

	Nine Months Ended September 30,						Three Months Ended September 30,
	2018			2017			2018			2017
OIL AND GAS REVENUE	$	1,881,683		$	215,649		$	552,946		$	111,741
EXPENSES OF OPERATIONS
Lease operating expense and severance tax		764,035			95,260			278,460			55,245
General and administrative expense		1,165,854			1,627,433			301,495			622,994
Depreciation and depletion		267,896			86,486			89,924			55,280
Total operating expenses		2,197,785			1,809,179			669,879			733,519
Loss from operations		(316,102	)		(1,593,530	)		(116,933	)		(621,778	)
OTHER INCOME (EXPENSE)
Other income		102			10,184			102			3
Interest expense		—			(171,605	)		—			(164,503	)
Total other income (expense), net		102			(161,421	)		102			(164,500	)
Net loss before taxes		(316,000	)		(1,754,951	)		(116,831	)		(786,278	)
Income tax expense (benefit)		—			—			—			—
Net loss		(316,000	)		(1,754,951	)		(116,831	)		(786,278	)
Dividends to Series A and B preferred stockholders		(181,350	)		(80,570	)		(56,250	)		(63,288	)
Net loss attributable to common shareholders	$	(497,350	)	$	(1,835,521	)	$	(173,081	)	$	(849,566	)
Basic and diluted loss per common share	$	(0.01	)	$	(0.04	)	$	(0.00	)	$	(0.02	)
Based and diluted weighted average number of common shares outstanding		60,079,314			52,306,289			61,220,932			54,330,541

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

4

HOUSTON AMERICAN ENERGY CORP.

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2018 AND 2017

(Unaudited)

	For the Nine Months Ended September 30,
	2018			2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss	$	(316,000	)	$	(1,754,951	)
Adjustments to reconcile net loss to net cash used in operations:
Depreciation and depletion		267,896			86,486
Stock-based compensation		82,947			196,869
Accretion of asset retirement obligation		2,322			2,758
Amortization of debt discount		—			158,734
Changes in operating assets and liabilities:
Increase in accounts receivable		(4,078	)		(24,199	)
Increase in prepaid expenses and other current assets		(23,453	)		(11,250	)
Increase in accounts payable and accrued expenses		335			64,326
Increase/(decrease) in deferred rent obligation		(3,960	)		40,100
Net cash provided by (used in) operating activities		6,010			(1,241,127	)
CASH FLOWS FROM INVESTING ACTIVITIES
Payments for the acquisition and development of oil and gas properties		(119,926	)		(3,878,984	)
Net cash used in investing activities		(119,926	)		(3,878,984	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of notes payable, net of debt discount		—			570,000
Payments on notes payable		—			(600,000	)
Proceeds from the issuance of Series A Preferred Stock		—			1,200,000
Proceeds from the issuance of Series B Preferred Stock		—			909,600
Proceeds from the issuance of common stock, net of offering costs		688,550			3,049,515
Payment of preferred stock dividends		(181,350	)		(80,570	)
Net cash provided by financing activities		507,200			5,048,545
Increase (decrease) in cash		393,284			(71,566	)
Cash, beginning of period		392,062			481,172
Cash, end of period	$	785,346		$	409,606
SUPPLEMENTAL CASH FLOW INFORMATION
Interest paid	$	—		$	12,871
Taxes paid	$	—		$	—
SUPPLEMENTAL NON-CASH INVESTING AND FINANCING ACTIVITIES
Change in accrued oil and gas development costs	$	99,897		$	423,522
Conversion of convertible preferred stock to common stock	$	617		$	—
Debt discount from issuance of warrants as debt inducement	$	—		$	128,734
Increase in reserve for plugging and abandonment costs	$	—		$	6,000
Cashless exercise of stock options	$	114		$	—
Retirement of treasury shares	$	—		$	174,125

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

5

HOUSTON AMERICAN ENERGY CORP.

Notes to Consolidated Financial Statements

(Unaudited)

NOTE 1 – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

The accompanying unaudited consolidated financial statements of Houston American Energy Corp., a Delaware corporation (the “Company”), have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q. They do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America for a complete financial presentation. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, considered necessary for a fair presentation, have been included in the accompanying unaudited consolidated financial statements. Operating results for the periods presented are not necessarily indicative of the results that may be expected for the full year. These unaudited consolidated financial statements should be read in conjunction with the Company’s audited consolidated financial statements and footnotes, which are included as part of the Company’s Annual Report on Form 10-K for the year ended December 31, 2017.

Consolidation

The accompanying consolidated financial statements include all accounts of the Company and its subsidiaries (HAEC Louisiana E&P, Inc., HAEC Oklahoma E&P, Inc., and HAEC Caddo Lake E&P, Inc.). All significant inter-company balances and transactions have been eliminated in consolidation.

Accounting Principles and Use of Estimates

The consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America. In preparing financial statements, management makes informed judgments and estimates that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period. On an ongoing basis, management reviews its estimates, including those related to such potential matters as litigation, environmental liabilities, income taxes and the related valuation allowance, determination of proved reserves of oil and gas and asset retirement obligations. Changes in facts and circumstances may result in revised estimates and actual results may differ from these estimates.

Reclassifications

Certain amounts for prior periods have been reclassified to conform to the current presentation.

Concentration of Credit Risk

Financial instruments that potentially subject the Company to a concentration of credit risk include cash, cash equivalents and any marketable securities (if any). The Company had cash deposits of $155,174 in excess of the FDIC’s current insured limit on interest bearing accounts of $250,000 as of September 30, 2018. The Company also had cash deposits of $45,638 in Colombian banks at September 30, 2018 that are not insured by the FDIC. The Company has not experienced any losses on its deposits of cash and cash equivalents.

Revenue Recognition

ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)”, supersedes the revenue recognition requirements and industry-specific guidance under Revenue Recognition (Topic 605). Topic 606 requires an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration the entity expects to be entitled to in exchange for those goods or services. The Company adopted Topic 606 on January 1, 2018, using the modified retrospective method applied to contracts that were not completed as of January 1, 2018. Under the modified retrospective method, prior period financial positions and results will not be adjusted. The cumulative effect adjustment recognized in the opening balances included no significant changes as a result of this adoption. While the Company does not expect 2018 net earnings to be materially impacted by revenue recognition timing changes, Topic 606 requires certain changes to the presentation of revenues and related expenses beginning January 1, 2018. Refer to Note 2 – Revenue from Contracts with Customers for additional information.

6

The Company’s revenue is comprised entirely of revenue from exploration and production activities. The Company’s oil is sold primarily to marketers, gatherers, and refiners. Natural gas is sold primarily to interstate and intrastate natural-gas pipelines, direct end-users, industrial users, local distribution companies, and natural-gas marketers. NGLs are sold primarily to direct end-users, refiners, and marketers. Payment is generally received from the customer in the month following delivery.

Contracts with customers have varying terms, including spot sales or month-to-month contracts, contracts with a finite term, and life-of-field contracts where all production from a well or group of wells is sold to one or more customers. The Company recognizes sales revenues for oil, natural gas, and NGLs based on the amount of each product sold to a customer when control transfers to the customer. Generally, control transfers at the time of delivery to the customer at a pipeline interconnect, the tailgate of a processing facility, or as a tanker lifting is completed. Revenue is measured based on the contract price, which may be index-based or fixed, and may include adjustments for market differentials and downstream costs incurred by the customer, including gathering, transportation, and fuel costs.

Revenues are recognized for the sale of the Company’s net share of production volumes.

Loss per Share

Basic loss per share is computed by dividing net loss available to common shareholders by the weighted average common shares outstanding for the period. Diluted earnings per share reflects the potential dilution that could occur if securities or other contracts to issue common shares were exercised or converted in common shares that then shared in the earnings of the Company. In periods in which the Company reports a net loss, dilutive securities are excluded from the calculation of diluted net loss per share amounts as the effect would be anti-dilutive.

For the nine months ended September 30, 2018 and 2017, the following convertible preferred stock and warrants and options to purchase shares of common stock were excluded from the computation of diluted net loss per share, as the inclusion of such shares would be anti-dilutive:

	Nine Months Ended September 30,
	2018		2017
Series A Convertible Preferred Stock		5,425,000		6,000,000
Series B Convertible Preferred Stock		2,320,556		2,527,778
Stock warrants		50,000		3,651,680
Stock options		4,978,832		6,012,165
Total		12,774,388		18,191,623

Recently Issued Accounting Pronouncements

In February 2016, the FASB issued ASU 2016-02, a new lease standard requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. The Company has evaluated the adoption of the standard and, due to there being only one operating lease currently in place, there will be minimal impact of the standard on its consolidated financial statements.

In August 2018, the FASB issued ASU 2018-13, “Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement”. The amendments in this update are to improve the effectiveness of disclosures in the notes to the financial statements by facilitating clear communication of the information required by GAAP that is most important to users of each entity’s financial statements. The amendments in this Update apply to all entities that are required, under existing GAAP, to make disclosures about recurring or nonrecurring fair value measurements. The amendments in this update are effective for all entities for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years. The Company does not expect that this guidance will have a material impact on its consolidated financial statements.

In July 2018, the FASB issued ASU 2018-11, “Leases (Topic 842): Target Improvements”. The amendments in this Update also clarify which Topic (Topic 842 or Topic 606) applies for the combined component. Specifically, if the non-lease component or components associated with the lease component are the predominant component of the combined component, an entity should account for the combined component in accordance with Topic 606. Otherwise, the entity should account for the combined component as an operating lease in accordance with Topic 842. An entity that elects the lessor practical expedient also should provide certain disclosures. The Company is currently evaluating the adoption of this guidance and does not expect that this guidance will have a material impact on its consolidated financial statements. The Company has not adopted this Standard and will do so when specified by the FASB.

7

In July 2018, the FASB issued ASU 2018-10, “Codification Improvements to Topic 842, Leases”. The amendments in this Update affect narrow aspects of the guidance issued in the amendments in Update 2016-02 as described in the table below. The amendments in this Update related to transition do not include amendments from proposed Accounting Standards Update, Leases (Topic 842): Targeted Improvements, specific to a new and optional transition method to adopt the new lease requirements in Update 2016-02. That additional transition method will be issued as part of a forthcoming and separate Update that will result in additional amendments to transition paragraphs included in this Update to conform with the additional transition method. The Company is currently evaluating the adoption of this guidance and does not expect that this guidance will have a material impact on its consolidated financial statements. The Company has not adopted this Standard and will do so when specified by the FASB.

In June 2018, the FASB issued ASU 2018-07, “Compensation—Stock Compensation (Topic 718): Improvements to Nonemployee Share-Based Payment Accounting”. The amendments in this update are to maintain or improve the usefulness of the information provided to the users of financial statements while reducing cost and complexity in financial reporting. The areas for simplification in this Update involve several aspects of the accounting for nonemployee share-based payment transactions resulting from expanding the scope of Topic 718, to include share-based payment transactions for acquiring goods and services from nonemployees. Some of the areas for simplification apply only to nonpublic entities. The amendments in this update are effective for all entities for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. The Company does not expect that this guidance will have a material impact on its consolidated financial statements.

The Company does not expect the adoption of any recently issued accounting pronouncements to have a significant impact on its financial position, results of operations, or cash flows.

Subsequent Events

The Company has evaluated all transactions from September 30, 2018 through the financial statement issuance date for subsequent event disclosure consideration.

NOTE 2 – REVENUE FROM CONTRACTS WITH CUSTOMERS

Change in Accounting Policy

The Company adopted ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)”, on January 1, 2018, using the modified retrospective method applied to contracts that were not completed as of January 1, 2018. Refer to Note 1 – Basis of Presentation and Significant Accounting Policies for additional information.

Exploration and Production.

There were no significant changes to the timing or valuation of revenue recognized for sales of production from exploration and production activities.

Disaggregation of Revenue from Contracts with Customers

The following table disaggregates revenue by significant product type for the three and nine month periods ended September 30, 2018:

	Three Months Ended September 30, 2018		Nine Months Ended September 30, 2018
Oil sales	$	297,967	$	1,145,643
Natural gas sales		102,756		583,817
Natural gas liquids sales		152,223		152,223
Total revenue from customers	$	552,946	$	1,881,683

There were no significant contract liabilities or transaction price allocations to any remaining performance obligations as of December 31, 2017 or September 30, 2018.

8

NOTE 3 – OIL AND GAS PROPERTIES

During the nine months ended September 30, 2018, the Company invested $20,029, net, for the acquisition and development of oil and gas properties, consisting of (1) cost of acquisition of U.S. properties $135,329, attributable to acreage acquired in Yoakum County, Texas, and (2) preparation and evaluation costs in Colombia of $9,980; offset by a credit of $125,280 attributable to cash advances previously reflected as development costs on the Company’s Reeves County acreage. Of the amount invested, the Company capitalized $145,309 to oil and gas properties not subject to amortization and reduced costs capitalized to oil and gas properties subject to amortization by $125,280.

Geographical Information

The Company currently has operations in two geographical areas, the United States and Colombia. Revenues for the nine months ended September 30, 2018 and long lived assets (net of depletion, amortization, and impairments) as of September 30, 2018 attributable to each geographical area are presented below:

	Nine Months Ended September 30, 2018		As of September 30, 2018
	Revenues		Long Lived Assets, Net
United States	$	1,881,683	$	4,246,604
Colombia		—		2,319,320
Total	$	1,881,683	$	6,565,924

NOTE 4 – STOCK-BASED COMPENSATION EXPENSE

In 2008, the Company’s Board of Directors adopted the Houston American Energy Corp. 2008 Equity Incentive Plan (the “2008 Plan”). The terms of the 2008 Plan, as amended in 2012 and 2013, allow for the issuance of up to 6,000,000 shares of the Company’s common stock pursuant to the grant of stock options and restricted stock. Persons eligible to participate in the Plans are key employees, consultants and directors of the Company.

In March 2017, the Company’s Board of Directors adopted, and the shareholders ultimately approved, the Houston American Energy Corp. 2017 Equity Incentive Plan (the “2017 Plan” and, together with the 2008 Plan, the “Plans”). The terms of the 2017 Plan, allow for the issuance of up to 5,000,000 shares of the Company’s common stock pursuant to the grant of stock options and restricted stock. Persons eligible to participate in the Plans are key employees, consultants and directors of the Company.

The Company periodically grants options to employees, directors and consultants under the Plans and is required to make estimates of the fair value of the related instruments and recognize expense over the period benefited, usually the vesting period.

Stock Option Activity

In February 2018, options to purchase an aggregate of 1,000,000 shares were granted to an executive officer. The options have a ten-year life, vest 1/3 on each of the first three anniversaries of the grant date and are exercisable at $0.2922 per share, the fair market value on the date of grant. The executive officer was terminated in June 2018 and the options were forfeited unvested on termination of employment. The options were valued on the date of grant at $166,940 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 2.68%; (2) expected life in years of 5.79; (3) expected stock volatility of 105.4%; and (4) expected dividend yield of 0%. The Company determined the options qualify as ‘plain vanilla’ under the provisions of SAB 107 and the simplified method was used to estimate the expected option life.

In March 2018, options to purchase an aggregate of 500,000 shares were granted to a non-officer employee. The options have a ten-year life, vest 1/3 on each of the first three anniversaries of the grant date and are exercisable at $0.30 per share, the fair market value on the date of grant. The options were valued on the date of grant at $89,808 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 2.72%; (2) expected life in years of 5.81; (3) expected stock volatility of 105.0%; and (4) expected dividend yield of 0%. The Company determined the options qualify as ‘plain vanilla’ under the provisions of SAB 107 and the simplified method was used to estimate the expected option life.

9

In April 2018, options to purchase 8,333 shares were granted to a newly appointed non-employee director. The options have a ten-year life, vest 20% on the date of grant and 80% nine months from the date of grant and an exercise price of $0.267 per share, the fair market value on the date of grant. The options were valued on the date of grant at $1,770 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 2.69%; (2) expected life in years of 5.8; (3) expected stock volatility of 105%; and (4) expected dividend yield of 0%. The Company determined the options qualify as ‘plain vanilla’ under the provisions of SAB 107 and the simplified method was used to estimate the expected option life.

In June 2018, options to purchase an aggregate of 150,000 shares were granted to three non-employee directors. The options have a ten-year life, vest 20% on the date of grant and 80% nine months from the date of grant and exercise prices of $0.2425 per share, the fair market value on the date of grant. The options were valued on the date of grant at $27,422 using the Black-Scholes option-pricing model with the following parameters: (1) risk-free interest rate of 2.79%; (2) expected life in years of 5.88; (3) expected stock volatility of 103.9%; and (4) expected dividend yield of 0%. The Company determined the options qualify as ‘plain vanilla’ under the provisions of SAB 107 and the simplified method was used to estimate the expected option life.

In June 2018, stock options to purchase 250,000 shares of common stock were exercised, in a cashless exercise, resulting in the issuance of 114,379 shares of common stock.

A summary of stock option activity and related information for the nine months ended September 30, 2018 is presented below:

	Options			Weighted-Average Exercise Price		Aggregate Intrinsic Value
Outstanding at January 1, 2018		6,012,165		$	1.86
Granted		1,658,333			0.29
Exercised		(250,000	)		0.22
Forfeited		(2,441,666	)		3.79
Outstanding at September 30, 2018		4,978,832		$	0.88	$	6,646
Exercisable at September 30, 2018		4,923,499		$	0.95	$	6,646

During the three and nine months ended September 30, 2018, the Company recognized $14,049 and $81,177, respectively, of stock-based compensation expense attributable to the amortization of unrecognized stock-based compensation from its outstanding stock options. As of September 30, 2018, total unrecognized stock-based compensation expense related to non-vested stock options was $84,514. The unrecognized expense is expected to be recognized over a weighted average period of 0.99 years and the weighted average remaining contractual term of the outstanding options and exercisable options at September 30, 2018 is 5.57 years and 4.82 years, respectively.

Shares are no longer available for issuance under the 2008 Plan. Shares available for issuance under the 2017 Plan, as of September 30, 2018, totaled 4,500,000.

Share-Based Compensation Expense

The following table reflects share-based compensation recorded by the Company for the three and nine months ended September 30, 2018 and 2017:

	Nine Months Ended September 30,				Three Months Ended September 30,
	2018		2017		2018		2017
Share-based compensation expense included in general and administrative expense	$	82,947	$	196,869	$	14,217	$	61,025
Earnings per share effect of share-based compensation expense – basic and diluted	$	0.00	$	0.00	$	0.00	$	0.00

NOTE 5 – CAPITAL STOCK

Series A Convertible Redeemable Preferred Stock

During the nine months ended September 30, 2018, (i) 90 shares of Series A Convertible Redeemable Preferred Stock were converted, under the terms of the preferred stock, into 450,000 shares of common stock and (ii) the Company paid dividends on Series A Convertible Redeemable Preferred Stock in the amount of $100,350. At September 30, 2018, there were 1,085 shares of Series A Convertible Redeemable Preferred Stock issued and outstanding.

10

Series B Convertible Redeemable Preferred Stock

During the nine months ended September 30, 2018, (i) 60 shares of Series B Convertible Redeemable Preferred Stock were converted, under the terms of the preferred stock, into 166,667 shares of common stock, and (ii) the Company paid dividends on Series B Convertible Redeemable Preferred Stock in the amount of $81,000. At September 30, 2018, there were 835 shares of Series B Convertible Redeemable Preferred Stock issued and outstanding.

Common Stock

During the nine months ended September 30, 2018, the Company issued an aggregate of 2,610,083 shares of common stock, consisting of (i) 2,217,926 shares sold under the Company’s At-the-Market Issuance Sales Agreement (the “2017 ATM Offering”) with WestPark Capital, Inc. (“WestPark Capital”); (ii) 277,778 shares issued on conversion of convertible preferred stock, and (iii) 114,379 shares issued on the exercise of stock options. Proceeds from the sale of shares sold under the 2017 ATM Offering, net of commissions and expenses, totaled $688,550. The shares issued on the exercise of stock option were issued in a cashless exercise and resulted in no proceeds to the Company.

Warrants

A summary of warrant activity and related information for the nine months ended September 30, 2018 is presented below:

	Warrants			Weighted-Average Exercise Price		Aggregate Intrinsic Value
Outstanding at January 1, 2018		3,651,680		$	0.44
Issued		—			—
Exercised		—			—
Expired		(3,601,680	)		0.44
Outstanding at September 30, 2018		50,000		$	0.55	$	—
Exercisable at September 30, 2018		25,000		$	0.55	$	—

During the three and nine months ended September 30, 2018, the Company recognized $168 and $1,770, respectively, of stock-based compensation expense attributable to the amortization of warrants. As of September 30, 2018, total unrecognized stock-based compensation expense related to non-vested stock warrants was $12,668. The unrecognized expense is expected to be recognized over a weighted average period of 1.94 years and the weighted average remaining contractual term of the outstanding warrants and exercisable warrants at September 30, 2018 is 1.94 years and 1.94 years, respectively.

NOTE 6 - COMMITMENTS AND CONTINGENCIES

Lease Commitment

The Company leases office facilities under an operating lease agreement that expires October 31, 2022. As of September 30, 2018, the lease agreement requires future payments as follows:

Year	Amount
2018		31,791
2019		128,348
2020		130,717
2021		133,087
2022		112,551
Total	$	536,494

For the three and nine months ended September 30, 2018, the total base rental expense was $30,298 and $98,678, respectively. For the three and nine months ended September 30, 2017, the total base rental expense was $40,100 and $89,544, respectively. The Company does not have any capital leases or other operating lease commitments.

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NOTE 7 – SUBSEQUENT EVENTS

2017 At-the-Market Offering

Subsequent to September 30, 2018, through the date hereof, the Company sold an aggregate of 13,614 shares in the ATM Offering and received proceeds, net of commissions and expenses, of $3,698.

2018 At-the-Market Offering

In October 2018, the Company entered into an At-the-Market Issuance Sales Agreement (the “Sales Agreement”) with WestPark Capital pursuant to which the Company may sell, at its option, up to an aggregate of $1.9 million in shares of its common stock through WestPark Capital, as sales agent. Sales of shares under the Sales Agreement (the “2018 ATM Offering”) will be made, in accordance with one or more placement notices delivered by the Company to WestPark Capital, which notices shall set parameters under which shares may be sold. The 2018 ATM Offering was made pursuant to a shelf registration statement by methods deemed to be “at the market,” as defined in Rule 415 promulgated under the Securities Act of 1933. The Company will pay WestPark a commission in cash equal to 3% of the gross proceeds from the sale of shares in the 2018 ATM Offering. Additionally, the Company reimbursed WestPark Capital for $18,000 of expenses incurred in connection with the 2018 ATM Offering.

Recovery of Escrow Account

In 2010, the Company, and its operator in Colombia, Hupecol, sold its interests in two entities in Colombia. Pursuant to the terms of those sales, a portion of the sales price was escrowed to secure certain representations of the selling parties. The Company’s share of amounts escrowed was recorded as escrow receivables.

In 2016, the Company recorded an allowance in the amount of $262,016 relating to the undisbursed balance of escrow receivables.

In October 2018, the Company received payments totaling $89,230 representing recoveries of escrowed funds relating to the previously written-off escrow receivables. As a result of the receipt of such funds, the Company will record a non-recurring gain in the amount of $89,230 during the quarter ending December 31, 2018.

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

Forward-Looking Information

This Form 10-Q quarterly report of Houston American Energy Corp. (the “Company”) for the nine months ended September 30, 2018, contains certain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, which are intended to be covered by the safe harbors created thereby. To the extent that there are statements that are not recitations of historical fact, such statements constitute forward-looking statements that, by definition, involve risks and uncertainties. In any forward-looking statement, where we express an expectation or belief as to future results or events, such expectation or belief is expressed in good faith and believed to have a reasonable basis, but there can be no assurance that the statement of expectation or belief will be achieved or accomplished.

The actual results or events may differ materially from those anticipated and as reflected in forward-looking statements included herein. Factors that may cause actual results or events to differ from those anticipated in the forward-looking statements included herein include the Risk Factors described in Item 1A herein and in our Form 10-K for the year ended December 31, 2017.

Readers are cautioned not to place undue reliance on the forward-looking statements contained herein, which speak only as of the date hereof. We believe the information contained in this Form 10-Q to be accurate as of the date hereof. Changes may occur after that date, and we will not update that information except as required by law in the normal course of our public disclosure practices.

Additionally, the following discussion regarding our financial condition and results of operations should be read in conjunction with the financial statements and related notes contained in Item 1 of Part 1 of this Form 10-Q, as well as the Risk Factors in Item 1A and the financial statements in Item 7 of Part II of our Form 10-K for the fiscal year ended December 31, 2017.

Critical Accounting Policies

The discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. We believe certain critical accounting policies affect the more significant judgments and estimates used in the preparation of our financial statements. A description of our critical accounting policies is set forth in our Form 10-K for the year ended December 31, 2017. As of, and for the nine months ended, September 30, 2018, there have been no material changes or updates to our critical accounting policies.

Unevaluated Oil and Gas Properties

Unevaluated oil and gas properties not subject to amortization, include the following at September 30, 2018:

	September 30, 2018
Acquisition costs	$	276,648
Development and evaluation costs		2,178,002
Total	$	2,454,650

Of the carrying value of unevaluated oil and gas prospects above, $2,319,320 was attributable to properties in the South American country of Colombia and $135,330 was attributable to properties in the United States. We are maintaining our interest in these properties.

Recent Developments

Leasing Activity

During the nine months ended September 30, 2018, we acquired, for $135,330, a 12.5% working interest (subject to a proportionate 10% back-in after payout) in an approximately 650-acre lease block in Yoakum County, Texas.

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Drilling Activity

During the nine months ended September 30, 2018, we drilled no wells. At September 30, 2018, no drilling operations were ongoing.

During the nine months ended September 30, 2018, we invested $20,029, net, for the acquisition and development of oil and gas properties, consisting of (1) cost of acquisition of U.S. properties $135,329, attributable to acreage acquired in Yoakum County, Texas, and (2) preparation and evaluation costs in Colombia of $9,980; offset by a credit of $125,280 attributable to cash advances previously reflected as development costs on the Company’s Reeves County acreage. Of the amount invested, the Company capitalized $145,309 to oil and gas properties not subject to amortization and reduced costs capitalized to oil and gas properties subject to amortization by $125,280.

In Reeves County, a new operator took control of operations in June 2018, following the acquisition of the interests of our former operator, Founders Oil & Gas. We are awaiting the development and presentation by the new operator of plans to continue the development of our Reeves County acreage. Our future drilling activities on our Reeves County acreage, including timing, number of wells drilled, anticipated cost and related matters, are subject to our review and acceptance of development plans expected to be provided by the new operator, our ability to finance our share of costs, market conditions and other factors, many of which are beyond our control.

In Yoakum County, we are awaiting proposals from the operator with respect to the drilling of the initial wells on our acreage.

In Colombia, our operator is continuing to carry on discussions with federal and local officials in order to overcome opposition to their efforts to secure necessary permits to commence drilling operations on our Serrania concession. Until a satisfactory resolution is reached allowing the issuance of necessary permits, substituting equivalent prospects or otherwise compensating for the value of, and investments in, our Serrania concession, our operator is continuing to defer further efforts to commence drilling on the Serrania concession.

Our operator has also deferred commencement of work on the Los Picachos and Macaya concessions until satisfactory resolution of the permitting issues on the Serrania concession.

Financing Activity

During the nine months ended September 30, 2018, we issued an aggregate of 2,217,926 shares sold under our 2017 At-the-Market Issuance Sales Agreement (the “2017 ATM Offering”) with WestPark Capital, Inc. (“WestPark Capital”) for proceeds, net of commissions and expenses, totaled $688,550.

Subsequent to September 30, 2018, through the date hereof, the Company sold an aggregate of 13,614 shares in the 2017 ATM Offering and received proceeds, net of commissions and expenses, of $3,698.

In October 2018, we entered into an At-the-Market Issuance Sales Agreement (the “Sales Agreement”) with WestPark Capital pursuant to which we may sell, at our option, up to an aggregate of $1.9 million in shares of our common stock through WestPark Capital, as sales agent. Sales of shares under the Sales Agreement (the “2018 ATM Offering”) will be made, in accordance with one or more placement notices delivered to WestPark Capital, which notices shall set parameters under which shares may be sold. The 2018 ATM Offering was made pursuant to a shelf registration statement by methods deemed to be “at the market,” as defined in Rule 415 promulgated under the Securities Act of 1933. We will pay WestPark a commission in cash equal to 3% of the gross proceeds from the sale of shares in the 2018 ATM Offering. Additionally, we reimbursed WestPark Capital for $18,000 of expenses incurred in connection with the 2018 ATM Offering.

Employment Arrangements

During the quarter ended June 30, 2018, our board determined to terminate the services of John Boylan as Chairman, CEO and President. A member of our board is serving as interim CEO and President, and our board has commenced a search for a replacement CEO and President.

Recovery of Escrow Account

In 2010, we, and our operator in Colombia, Hupecol, sold our interests in two entities in Colombia. Pursuant to the terms of those sales, a portion of the sales price was escrowed to secure certain representations of the selling parties. Our share of amounts escrowed was recorded as escrow receivables.

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In 2016, we recorded an allowance in the amount of $262,016 relating to the undisbursed balance of escrow receivables.

In October 2018, we received payments totaling $89,230 representing recoveries of escrowed funds relating to the previously written-off escrow receivables. As a result of the receipt of such funds, we will record a non-recurring gain in the amount of $89,230 during the quarter ending December 31, 2018.

Results of Operations

Oil and Gas Revenues. Total oil and gas revenues increased by 395% to $552,946 in the three months ended September 30, 2018 compared to $111,741 in the three months ended September 30, 2017. Oil and gas revenues increased 772% to $1,881,683 in the nine months ended September 30, 2018 compared to $215,649 in the nine months ended September 30, 2017.

The following table sets forth the gross and net producing wells, net oil and gas production volumes and average hydrocarbon sales prices for the quarter and nine months ended September 30, 2018 and 2017:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2018		2017		2018		2017
Gross producing wells		9		11		9		12
Net producing wells		0.95		0.99		0.95		1.0
Net oil production (bbl)		5,426		2,310		19,375		3,888
Net gas production (mcf)		80,000		3,450		201,083		11,479
Average sales price – oil (per barrel)	$	54.92	$	43.45	$	59.13	$	45.69
Average sales price – natural gas (per mcf)	$	3.19	$	3.29	$	3.66	$	3.31

The increase in production reflects production from our two initial Reeves County wells which commenced commercial production during the fourth quarter of 2017.

The increase in average sales prices reflected generally rising global energy prices during the periods.

Oil and gas sales revenues by region were as follows:

	Colombia		U.S.		Total
2018 First Nine Months
Oil sales	$	—	$	1,145,643	$	1,145,643
Gas sales		—		736,040		736,040
2017 First Nine Months
Oil sales	$	—	$	177,678	$	177,678
Gas sales		—		37,971		37,971

Lease Operating Expenses. Lease operating expenses increased by 404% to $278,460 during the three months ended September 30, 2018 from $55,245 during the three months ended September 30, 2017. During the nine months ended September 30, 2018, lease operating expenses increased by 702% to $764,035 from $95,260 during the nine months ended September 30, 2017. The change in total lease operating expenses was attributable to the commencement of production from our two initial Reeves County wells.

Following is a summary comparison of lease operating expenses, by region, for the periods.

		Colombia		U.S.		Total
Quarter ended September 30,	- 2018	$	—	$	278,460	$	278,460
	- 2017	$	—	$	55,245	$	55,245
Nine Months ended September 30,	- 2018	$	—	$	764,035	$	764,035
	- 2017	$	—	$	95,260	$	95,260

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Future lease operating expenses in Reeves County are expected to be effected by the pending completion of an adjacent salt water disposal well which, if and when completed, is expected to reduce our cost of transportation of water. We expect the disposal well to be on line in the fourth quarter of 2018. However, there is no assurance as to when, if ever, the salt water disposal well will be on line or as to the actual savings, if any, that will be realized when the disposal well becomes operational.

General and Administrative Expenses. General and administrative expense decreased by 52% to $301,495 during the three months ended September 30, 2018 from $622,994 during the three months ended September 30, 2017, and decreased 28% to $1,165,854 during the nine months ended September 30, 2018 from $1,627,433 during the nine months ended September 30, 2017. The change in general and administrative expense was primarily attributable to a reduction in legal fees compared to 2017 when we were significantly more active in acquisition and financing activities and a reduction in compensation expense following termination of our chief executive officer.

Stock-Based Compensation Expense. Stock-based compensation expense decreased by 77% to $14,217 during the three months ended September 30, 2018, from $61,025 during the three months ended September 30, 2017, and decreased 58% to $82,947 during the nine months ended September 30, 2018, from $196,869 during the nine months ended September 30, 2017. The change in stock-based compensation expenses was primarily attributable to earlier high value awards being fully amortized and expiration of options granted to terminated employees.

Depreciation and Depletion Expense. Depreciation and depletion expense was $89,924 and $55,280 for the three months ended September 30, 2018 and 2017, respectively, and $267,896 and $86,486 for the nine months ended September 30, 2018 and 2017, respectively. The increase was due to an increased depletion base and higher production rates, both attributable to commencement of operations of our Reeves County wells.

Financial Condition

Liquidity and Capital Resources. At September 30, 2018, we had a cash balance of $785,346 and working capital of $1,112,079, compared to a cash balance of $396,062 and working capital of $591,703 at December 31, 2017.

Operating activities provided cash of $6,010 during the nine months ended September 30, 2018, compared to $1,241,127 used during the nine months ended September 30, 2017. The change in operating cash flow was primarily attributable to a $1,438,951 decrease in net loss for the 2018 nine-month period, compared to the 2017 nine-month period, which improvement was attributable to the commencement of operations of our Reeves County wells.

Investing activities used cash of $119,926 during the nine months ended September 30, 2018, compared to $3,878,984 used during the nine months ended September 30, 2017. The decrease in funds used by investing activities during 2018 reflects lower investments in acreage acquisitions (including $135,329 for Yoakum County acreage in 2018, compared to $1,041,596 in Reeves County acreage in 2017) and lower investments in drilling operations during 2018 ($13,389 in 2018, compared to $3,433,511 in 2017), offset by a credit of $125,280 attributable to cash advances previously reflected as development costs on the Company’s Reeves County acreage.

Financing activities provided cash of $507,200 during the nine months ended September 30, 2018, compared to $5,048,545 provided during the nine months ended September 30, 2017. During 2018, cash provided by financing activities consisted of sales of common stock in the 2017 ATM Offering ($688,550), partially offset by dividend distributions on outstanding preferred stock ($181,350). During 2017, cash provided by financing activities consisted of $5,729,115 from the sale of common stock in the 2017 ATM Offering ($3,049,515), Series A Preferred Stock ($1,200,000), Series B Preferred Stock and Series B Warrants ($909,600), and Bridge Loan Notes and Bridge Loan Warrants ($570,000), partially offset by the payment of dividends on preferred stock ($80,570) and repayment of Bridge Loan Notes ($600,000).

Long-Term Liabilities. At September 30, 2018, we had long-term liabilities of $83,265, compared to $84,903 at December 31, 2017. Long-term liabilities consisted of deferred rent obligation and a reserve for plugging costs.

Capital and Exploration Expenditures and Commitments. Our principal capital and exploration expenditures relate to ongoing efforts to acquire, drill and complete prospects, in particular our Reeves County and Yoakum County acreage. Our principal capital and exploration expenditures during the balance of 2018 and early 2019 are expected to relate to drilling additional wells on our Reeves County acreage, drilling an initial well on our Yoakum County acreage and possibly opportunistic acquisitions of additional acreage in the Permian Basin. The actual timing and number of wells drilled during 2018 and early 2019 will be principally controlled by the operators of our Reeves County and Yoakum County acreage, based on a number of factors, including but not limited to availability of financing, performance of existing wells on the Reeves County acreage, energy prices and industry condition and outlook, costs of drilling and completion services and equipment and other factors beyond our control or that of our operators.

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During the nine months ended September 30, 2018, we invested $20,029, net, for the acquisition and development of oil and gas properties, consisting of (1) cost of acquisition of U.S. properties $135,329, attributable to acreage acquired in Yoakum County, Texas, and (2) preparation and evaluation costs in Colombia of $9,980; offset by a credit of $125,280 attributable to cash advances previously reflected as development costs on the Company’s Reeves County acreage. Of the amount invested, the Company capitalized $145,309 to oil and gas properties not subject to amortization and reduced costs capitalized to oil and gas properties subject to amortization by $125,280. Capital investments for the first nine months of 2018 were curtailed pending proposals of new drilling operations from the operators of our Reeves County and Yoakum County acreage.

As our allocable share of well costs will vary depending on the timing and number of wells drilled as well as our working interest in each such well and the level of participation of other interest owners, we have not established a drilling budget but will budget on a well-by-well basis as our operators propose wells. With the completion of sales lines and other infrastructure serving our Reeves County acreage and experience gained from drilling our initial wells, we anticipate that costs to drill and bring future wells onto production will decrease, and delays in bringing production on line will be minimized or eliminated, as compared to our experience in bringing our initial wells onto production.

Our cash holdings, including proceeds from our 2017 ATM Offering and escrow funds received subsequent to September 30, 2018, together with revenues from our initial Reeves County wells, are expected to be adequate to support operations for the next twelve months following the issuance of these financial statements, and, depending on our operator’s drilling and completion budget, may be adequate to fund our share of costs to drill a well in Yoakum County but are not expected to be adequate to fund our share of drilling and completion costs of any wells that may be drilled in Reeves County.

Given the ongoing delays in our operator’s proposing new wells in Reeves County, we continue to actively seek opportunities to acquire additional acreage or other strategic transactions with a view to adding scale to our operations.

In order to fund our estimated drilling and completion costs of additional wells in Reeves County, our costs of any new acquisition or other strategic transactions, and possibly our costs of drilling and completion of a Yoakum County well, we expect that we will be required to raise additional capital.

While we may, among other efforts, seek additional funding from our 2018 ATM Offering, and private sales of equity and debt securities, we presently have no commitments to provide additional funding, and there can be no assurance that we can secure the necessary capital to fund our share of drilling, acquisition or other costs on acceptable terms or at all. If, for any reason, we are unable to fund our share of drilling and completion costs and fail to satisfy commitments relative to our interest in our Reeves County, or other, acreage, we may be subject to penalties or to the possible loss of some of our rights and interests in prospects with respect to which we fail to satisfy funding commitments and we may be required to curtail operations and forego opportunities.

Off-Balance Sheet Arrangements

We had no off-balance sheet arrangements or guarantees of third party obligations at September 30, 2018.

Inflation

We believe that inflation has not had a significant impact on operations since inception.

ITEM 3 QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk

The price we receive for our oil and gas production heavily influences our revenue, profitability, access to capital and future rate of growth. Crude oil and natural gas are commodities and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the markets for oil and gas have been volatile, and these markets will likely continue to be volatile in the future. The price we receive for production depends on numerous factors beyond our control.

We have not historically entered into any hedges or other transactions designed to manage, or limit, exposure to oil and gas price volatility although we may, from time to time, evaluate the use of hedges or other transactions to manage or limit our exposure to oil and gas price volatility.

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ITEM 4 CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation as of September 30, 2018 of the effectiveness of the design and operation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Securities Exchange Act of 1934, as amended. Based on this evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were not effective as of September 30, 2018. Such conclusion reflects the 2013 departure of our chief financial officer and assumption of duties of principal financial officer by our chief executive officer and the resulting lack of segregation of duties. Until we are able to remedy these material weaknesses, we are relying on third party consultants and our accounting firm to assist with financial reporting.

Changes in Internal Control over Financial Reporting

No change in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) occurred during the quarter ended September 30, 2018 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II

ITEM 6 EXHIBITS

Exhibit

Number	Description
31.1	Certification of CEO and Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certification of CEO and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on behalf by the undersigned thereunto duly authorized.

	HOUSTON AMERICAN ENERGY CORP.
Date: November 13, 2018
	By:	/s/ James Schoonover
		James Schoonover
		Interim CEO and President (Principal Executive Officer and Principal Financial Officer)

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