TRCH Torchlight Energy Resources Inc

PART I FINANCIAL INFORMATION

 

ITEM 1. FINANCIAL STATEMENTS

 

TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED BALANCE SHEETS (Unaudited)
	June 30,	December 31,
	2019	2018
ASSETS
Current assets:
Cash	$ 415,985	$ 840,163
Accounts receivable	193,944	179,702
Production revenue receivable	106,237	294,715
Subscriptions receivable	156,000	-
Prepayments - development costs	1,781	146,422
Prepaid expenses	137,138	60,980
Total current assets	1,011,085	1,521,982
Oil and gas properties, net	40,401,982	36,565,461
Office equipment, net	7,309	4,076
Other assets	-	6,362
TOTAL ASSETS	$ 41,420,376	$ 38,097,881
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable	$ 741,853	$ 729,806
Unsecured promissory notes, net of discount and financing costs of $444,342	12,119,955	-
at June 30, 2019
Notes payable	8,000,000	-
Accrued payroll	906,176	816,176
Related party payables	45,000	45,000
Due to working interest owners	54,320	54,320
Accrued interest payable	900,393	553,370
Total current liabilities	22,767,697	2,198,672
Unsecured promissory notes, net of discount and financing costs of
$702,217 at December 31, 2018	-	11,862,080
Notes payable	-	6,000,000
Asset retirement obligations	20,962	14,353
Total liabilities	22,788,659	20,075,105
Commitments and contingencies
Stockholders’ equity:
Preferred stock, par value $0.001, 10,000,000 shares authorized;
-0- issued and outstanding at June 30, 2019 and December 31, 2018	-	-
Common stock, par value $0.001 per share; 150,000,000 shares authorized;	73,127	70,116
73,123,917 issued and outstanding at June 30, 2019,
70,112,376 issued and outstanding at December 31, 2018
Additional paid-in capital	110,441,403	107,266,965
Accumulated deficit	(91,882,813 )	(89,314,305 )
Total stockholders' equity	18,631,717	18,022,776
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 41,420,376	$ 38,097,881

    

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

    

 

 

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TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)
	Three Months	Three Months	Six Months	Six Months
	Ended	Ended	Ended	Ended
	June 30, 2019	June 30, 2018	June 30, 2019	June 30, 2018
Revenues
Oil and gas sales	$ 237,075	$ 283,263	$ 547,912	$ 764,426
Cost of revenues	(113,698 )	(184,425 )	(241,320 )	(413,328 )
Gross profit	123,377	98,838	306,592	351,098
Operating expenses:
General and administrative expense	(665,160 )	(907,595 )	(1,707,918 )	(2,583,434 )
Depreciation, depletion and amortization	(142,269 )	(154,805 )	(327,695 )	(261,938 )
Loss on settlement	-	(369,439 )	-	(369,439 )
Impairment loss	-	-	(474,357 )	(139,891 )
Total operating expenses	(807,429 )	(1,431,839 )	(2,509,970 )	(3,354,702 )
Other income (expense)
Interest expense and accretion of note discounts	(206,583 )	(159,260 )	(365,182 )	(263,201 )
Interest income	-	482	52	482
Total (expense)	(206,583 )	(158,778 )	(365,130 )	(262,719 )
Loss before income taxes	(890,634 )	(1,491,779 )	(2,568,508 )	(3,266,323 )
Provision for income taxes	-	-	-	-
Net loss	$ (890,634 )	$ (1,491,779 )	$ (2,568,508 )	$ (3,266,323 )
Loss per common share:
Basic and Diluted	$ (0.01 )	$ (0.02 )	$ (0.04 )	$ (0.05 )
Weighted average number of common shares outstanding:
Basic and Diluted	72,313,297	68,709,910	71,546,728	61,686,718

  

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

  

 

 

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TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)
	Six Months	Six Months
	Ended	Ended
	June 30, 2019	June 30, 2018
Cash Flows From Operating Activities
Net loss	$ (2,568,508 )	$ (3,266,323 )
Adjustments to reconcile net loss to net cash from operations:
Stock based compensation	658,250	1,000,146
Stock issued for interest payments on notes payable	379,275	221,025
Accrued interest payable in stock	254,377	135,398
Amortization of debt issuance costs	143,292	-
Accretion of note discounts	114,583	102,149
Depreciation, depletion and amortization	327,695	261,938
Net settlement offset	-	(100,561 )
Impairment loss	474,357	139,891
Change in:
Accounts receivable	(14,242 )	(256 )
Production revenue receivable	188,478	95,198
Prepayments - development costs	144,641	1,155,364
Prepaid expenses	(76,158 )	(72,601 )
Accounts payable and accrued expenses	157,707	(152,096 )
Accrued interest payable	92,646	(130,804 )
Net cash from operating activities	276,393	(611,532 )
Cash Flows From Investing Activities
Investment in oil and gas properties	(4,552,930 )	(7,531,151 )
Purchases of property, plant, and equipment	(6,564 )	-
Net cash from investing activities	(4,559,494 )	(7,531,151 )
Cash Flows From Financing Activities
Issuance of common stock	1,674,080	6,049,734
Proceeds from promissory notes	-	4,232,775
Repayment of promissory notes	-	(250,000 )
Proceeds from notes payable	2,000,000	-
Proceeds from warrant exercise	184,843	200,000
Net cash from financing activities	3,858,923	10,232,509
Net increase(decrease) in cash	(424,178 )	2,089,826
Cash - beginning of period	840,163	1,051,720
Cash - end of period	$ 415,985	$ 3,141,546
Supplemental disclosure of cash flow information: (Non Cash Items)
Common stock issued for lease interests	$ 125,000	$ -
Subscription receivable for sale of common stock	$ 156,000	$ -
Decrease in accounts payable for property development costs	$ 111,798	$ -
Cash paid for interest	$ 751,792	$ 706,338
Cash paid for income tax	$ -	$ -

  

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

 

 

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TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY (Unaudited)
	Common	Common	Additional
	stock	stock	paid-in	Accumulated
	shares	amount	capital	deficit	Total
Balance, December 31, 2018	70,112,376	$ 70,116	$ 107,266,965	$ (89,314,305 )	$ 18,022,776
Issuance of common stock for services	192,593	$ 192	$ 248,808		$ 249,000
Issuance of common stock for cash and subscriptions receivable	2,287,600	$ 2,288	$ 1,827,792		$ 1,830,080
Issuance of common stock for oil and gas lease extension	100,000	$ 100	$ 124,900		$ 125,000
Issuance of common stock for interest	60,342	$ 61	$ 65,107		$ 65,168
Issuance of common stock for Note PIK	202,316	$ 202	$ 313,906		$ 314,108
Issuance of common stock for warrant exercise	168,690	$ 168	$ 184,675		$ 184,843
Warrants issued for services			$ 273,000		$ 273,000
Stock options issued for services			$ 136,250		$ 136,250
Net loss				$ (2,568,508 )	$ (2,568,508 )
Balance, June 30, 2019	73,123,917	$ 73,127	$ 110,441,403	$ (91,882,813 )	$ 18,631,717

 

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

 

 

 

 

 

 

 

 

 

 

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TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

1. NATURE OF BUSINESS

 

Torchlight Energy Resources, Inc. (“Company”) was incorporated in October 2007 under the laws of the State of Nevada as Pole Perfect Studios, Inc. (“PPS”). From its incorporation to November 2010, the company was primarily engaged in business start-up activities.

 

On November 23, 2010, we entered into and closed a Share Exchange Agreement (the “Exchange Agreement”) between the major shareholders of PPS and the shareholders of Torchlight Energy, Inc. (“TEI”). As a result of the transactions effected by the Exchange Agreement, at closing TEI became our wholly-owned subsidiary, and the business of TEI became our sole business. TEI was incorporated under the laws of the State of Nevada in June 2010. We are engaged in the acquisition, exploitation and/or development of oil and natural gas properties in the United States. We operate our business through our subsidiaries Torchlight Energy Inc., Torchlight Energy Operating, LLC, Hudspeth Oil Corporation, Torchlight Hazel LLC, and Winkler Properties LLC.

 

 

2. GOING CONCERN

 

At June 30, 2019, the Company had not yet achieved profitable operations. We had a net loss of $2,568,508 for the six months ended June 30, 2019 and had accumulated losses of $91,882,813 since our inception. We expect to incur further losses in the development of our business. The Company had a working capital deficit as of June 30, 2019 of $21,756,612. These conditions raise substantial doubt about the Company’s ability to continue as a going concern.

 

The Company’s ability to continue as a going concern is dependent on its ability to generate future profitable operations and/or to obtain the necessary financing to meet its obligations and repay its liabilities arising from normal business operations when they come due. Management’s plan to address the Company’s ability to continue as a going concern includes: (1) obtaining debt or equity funding from private placement or institutional sources; (2) obtain loans from financial institutions, where possible, or (3) participating in joint venture transactions with third parties. Although management believes that it will be able to obtain the necessary funding to allow the Company to remain a going concern through the methods discussed above, there can be no assurances that such methods will prove successful.

 

These consolidated financial statements have been prepared assuming that the Company will continue as a going concern and therefore, the financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amount and classifications of liabilities that may result from the outcome of this uncertainty.

 

 

3. SIGNIFICANT ACCOUNTING POLICIES

 

The Company maintains its accounts on the accrual method of accounting in accordance with accounting principles generally accepted in the United States of America. Accounting principles followed and the methods of applying those principles, which materially affect the determination of financial position, results of operations and cash flows are summarized below:

 

Use of estimates – The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and certain assumptions that affect the amounts reported in these consolidated financial statements and accompanying notes. Actual results could differ from these estimates.

 

Basis of presentation —The financial statements are presented on a consolidated basis and include all of the accounts of Torchlight Energy Resources Inc. and its wholly owned subsidiaries, Torchlight Energy, Inc., Torchlight Energy Operating, LLC, Hudspeth Oil Corporation, Torchlight Hazel LLC, and Warwink Properties LLC. All significant intercompany balances and transactions have been eliminated.

 

These interim financial statements are unaudited and have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Certain disclosures have been condensed or omitted from these financial statements. Accordingly, they do not include all the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements, and should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2018.

 

In the opinion of management, the accompanying unaudited financial condensed consolidated financial statements include all adjustments, consisting of normal recurring adjustments, necessary to fairly present the financial position as of, and the results of operations for, all periods presented. In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect reported amounts in the condensed financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results. Certain reclassifications have been made to the prior period’s consolidated financial statements and related footnotes to conform them to the current period presentation.

 

 

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TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

3. SIGNIFICANT ACCOUNTING POLICIES - continued

 

Risks and uncertainties – The Company’s operations are subject to significant risks and uncertainties, including financial, operational, technological, and other risks associated with operating an emerging business, including the potential risk of business failure.

 

Concentration of risks – At times the Company’s cash balances are in excess of amounts guaranteed by the Federal Deposit Insurance Corporation. The Company’s cash is placed with a highly rated financial institution, and the Company regularly monitors the credit worthiness of the financial institutions with which it does business.

 

Fair value of financial instruments – Financial instruments consist of cash, receivables, payables and promissory notes, if any. The estimated fair values of cash, receivables, and payables approximate the carrying amount due to the relatively short maturity of these instruments. The carrying amounts of any promissory notes approximate their fair value giving affect for the term of the note and the effective interest rates.

 

For assets and liabilities that require re-measurement to fair value the Company categorizes them in a three-level fair value hierarchy as follows:

 

●	Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.

 

●	Level 2 inputs are quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or liability, either directly or indirectly through market corroboration.

 

●	Level 3 inputs are unobservable inputs based on management’s own assumptions used to measure assets and liabilities at fair value.

 

A financial asset or liability’s classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement.

 

Cash and cash equivalents - Cash and cash equivalents include certain investments in highly liquid instruments with original maturities of three months or less.

 

Accounts receivable – Accounts receivable consist of uncollateralized oil and natural gas revenues due under normal trade terms, as well as amounts due from working interest owners of oil and gas properties for their share of expenses paid on their behalf by the Company. Management reviews receivables periodically and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible. As of June 30, 2019 and December 31, 2018, no valuation allowance was considered necessary.

 

Oil and gas properties – The Company uses the full cost method of accounting for exploration and development activities as defined by the Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs of unsuccessful, as well as successful, exploration and development activities are capitalized as properties and equipment. This includes any internal costs that are directly related to property acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Gain or loss on the sale or other disposition of oil and gas properties is not recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves.

 

Oil and gas properties include costs that are excluded from costs being depleted or amortized. Oil and natural gas property costs excluded represent investments in unevaluated properties and include non-producing leasehold, geological, and geophysical costs associated with leasehold or drilling interests and exploration drilling costs. The Company allocates a portion of its acquisition costs to unevaluated properties based on relative value. Costs are transferred to the full cost pool as the properties are evaluated over the life of the reservoir. Unevaluated properties are reviewed for impairment at least quarterly and are determined through an evaluation considering, among other factors, seismic data, requirements to relinquish acreage, drilling results, remaining time in the commitment period, remaining capital plan, and political, economic, and market conditions.

 

Gains and losses on the sale of oil and gas properties are not generally reflected in income unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves. Sales of less than 100% of the Company’s interest in the oil and gas property are treated as a reduction of the capital cost of the field, with no gain or loss recognized, as long as doing so does not significantly affect the unit-of-production depletion rate. Costs of retired equipment, net of salvage value, are usually charged to accumulated depreciation.

  

 

 

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TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

3. SIGNIFICANT ACCOUNTING POLICIES - continued

 

Capitalized interest – The Company capitalizes interest on unevaluated properties during the periods in which they are excluded from costs being depleted or amortized. During the six months ended June 30, 2019 and 2018, the Company capitalized $1,362,244 and $885,006, respectively, of interest on unevaluated properties.

 

Depreciation, depletion, and amortization – The depreciable base for oil and natural gas properties includes the sum of all capitalized costs net of accumulated depreciation, depletion, and amortization (“DD&A”), estimated future development costs and asset retirement costs not included in oil and natural gas properties, less costs excluded from amortization. The depreciable base of oil and natural gas properties is amortized on a unit-of-production method.

 

Ceiling test – Future production volumes from oil and gas properties are a significant factor in determining the full cost ceiling limitation of capitalized costs. Under the full cost method of accounting, the Company is required to periodically perform a “ceiling test” that determines a limit on the book value of oil and gas properties. If the net capitalized cost of proved oil and gas properties, net of related deferred income taxes, plus the cost of unproved oil and gas properties, exceeds the present value of estimated future net cash flows discounted at 10 percent, net of related realizable tax affects, plus the cost of unproved oil and gas properties, the excess is charged to expense and reflected as additional accumulated DD&A. The Company recorded an impairment expense of $474,357 and $139,891 for the six months ended June 30, 2019 and 2018, respectively, to recognize the adjustment required by the ceiling test.

 

The ceiling test calculation uses a commodity price assumption which is based on the unweighted arithmetic average of the price on the first day of each month for each month within the prior 12 month period and excludes future cash outflows related to estimated abandonment costs.

 

The determination of oil and gas reserves is a subjective process, and the accuracy of any reserve estimate depends on the quality of available data and the application of engineering and geological interpretation and judgment. Estimates of economically recoverable reserves and future net cash flows depend on a number of variable factors and assumptions that are difficult to predict and may vary considerably from actual results. In particular, reserve estimates for wells with limited or no production history are less reliable than those based on actual production. Subsequent re-evaluation of reserves and cost estimates related to future development of proved oil and gas reserves could result in significant revisions to proved reserves. Other issues, such as changes in regulatory requirements, technological advances, and other factors which are difficult to predict could also affect estimates of proved reserves in the future.

 

Asset retirement obligations –The fair value of a liability for an asset’s retirement obligation (“ARO”) is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made, with the corresponding charge capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then-present value each subsequent period, and the capitalized cost is depleted over the useful life of the related asset. Abandonment costs incurred are recorded as a reduction of the ARO liability.

 

Inherent in the fair value calculation of an ARO are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit adjusted discount rates, timing of settlement, and changes in the legal, regulatory, environmental, and political environments. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the oil and gas property balance. Settlements greater than or less than amounts accrued as ARO are recorded as a gain or loss upon settlement.

 

Income taxes - Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss carry forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be realized.

 

Authoritative guidance for uncertainty in income taxes requires that the Company recognize the financial statement benefit of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an examination. Management has reviewed the Company’s tax positions and determined there were no uncertain tax positions requiring recognition in the consolidated financial statements. Company tax returns remain subject to Federal and State tax examinations. Generally, the applicable statutes of limitation are three to four years from their respective filings.

 

Estimated interest and penalties related to potential underpayment on any unrecognized tax benefits are classified as a component of tax expense in the statement of operation. The Company has not recorded any interest or penalties associated with unrecognized tax benefits for any periods covered by these financial statements.

 

Share-based compensation – Compensation cost for equity awards is based on the fair value of the equity instrument on the date of grant and is recognized over the period during which an employee is required to provide service in exchange for the award.  

  

 

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TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

3. SIGNIFICANT ACCOUNTING POLICIES - continued

 

The Company accounts for stock option awards using the calculated value method. The expected term was derived using the simplified method provided in Securities and Exchange Commission release Staff Accounting Bulletin No. 110, which averages an awards weighted average vesting period and contractual term for “plain vanilla” share options.

 

The Company accounts for any forfeitures of options when they occur. Previously recognized compensation cost for an award is reversed in the period that the award is forfeited.

 

The Company also issues equity awards to non-employees. The fair value of these option awards is estimated when the award recipient completes the contracted professional services. The Company recognizes expense for the estimated total value of the awards during the period from their issuance until performance completion.

 

In June 2018, the FASB issued ASU 2018-07, Compensation - Stock Compensation (Topic 718): Improvements to Nonemployee Share-Based Payment Accounting , which simplifies the accounting for share-based payments granted to nonemployees for goods and services. Under this ASU, the guidance on such payments to nonemployees is aligned with the requirements for share-based payments granted to employees. ASU 2018-07 was effective for fiscal years beginning after December 15, 2018, however the Company opted for early adoption effective July 1, 2018. In evaluating early adoption the Company determined that the change did not have a material impact on its consolidated financial statements.

 

The Company values warrant and option awards using the Black-Scholes option pricing model.

 

Revenue recognition – On January 1, 2018, the Company adopted ASC 606, Revenue from Contracts with Customers, and the related guidance in ASC 340-40 (the new revenue standard), and related guidance on gains and losses on derecognition of nonfinancial assets ASC 610-20, using the modified retrospective method applied to those contracts which were not completed as of January 1, 2018. Under the modified retrospective method, the Company recognizes the cumulative effect of initially applying the new revenue standard as an adjustment to the opening balance of retained earnings; however, no significant adjustment was required as a result of adopting the new revenue standard. Results for reporting periods beginning after January 1, 2018 are presented under the new revenue standard. The impact of the adoption of the new revenue standard was immaterial to the Company’s net loss.

 

The Company’s revenue is typically generated from contracts to sell natural gas, crude oil or NGLs produced from interests in oil and gas properties owned by the Company. Contracts for the sale of natural gas and crude oil are evidenced by (1) base contracts for the sale and purchase of natural gas or crude oil, which document the general terms and conditions for the sale, and (2) transaction confirmations, which document the terms of each specific sale. The transaction confirmations specify a delivery point which represents the point at which control of the product is transferred to the customer. These contracts frequently meet the definition of a derivative under ASC 815, and are accounted for as derivatives unless the Company elects to treat them as normal sales as permitted under that guidance. The Company elects to treat contracts to sell oil and gas production as normal sales, which are then accounted for as contracts with customers. The Company has determined that these contracts represent multiple performance obligations which are satisfied when control of the commodity transfers to the customer, typically through the delivery of the specified commodity to a designated delivery point.

 

Revenues from oil and gas sales are detailed as follows:

 

	Three Months	Three Months	Six Months	Six Months
	Ended	Ended	Ended	Ended
	June 30, 2019	June 30, 2018	June 30, 2019	June 30, 2018
Revenues
Oil sales	$ 223,038	$ 280,573	$ 525,183	$ 756,534
Gas sales	14,037	2,690	22,729	7,892
Total	$ 237,075	$ 283,263	$ 547,912	$ 764,426

 

Revenue is measured based on consideration specified in the contract with the customer, and excludes any amounts collected on behalf of third parties. The Company recognizes revenue in the amount that reflects the consideration it expects to be entitled to in exchange for transferring control of those goods to the customer. Amounts allocated in the Company’s price contracts are based on the standalone selling price of those products in the context of long-term contracts. Payment is generally received one or two months after the sale has occurred.

 

 

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TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

3. SIGNIFICANT ACCOUNTING POLICIES - continued

 

Gain or loss on derivative instruments is outside the scope of ASC 606 and is not considered revenue from contracts with customers subject to ASC 606. The Company may in the future use financial or physical contracts accounted for as derivatives as economic hedges to manage price risk associated with normal sales, or in limited cases may use them for contracts the Company intends to physically settle but do not meet all of the criteria to be treated as normal sales. 

 

Producer Gas Imbalances. The Company applies the sales method of accounting for natural gas revenue. Under this method, revenues are recognized based on the actual volume of natural gas sold to purchasers.

 

Basic and diluted earnings (loss) per share – Basic earnings (loss) per common share is computed by dividing net income (loss) available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per common share is computed in the same way as basic earnings (loss) per common share except that the denominator is increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued and if the additional common shares were dilutive. The calculation of diluted earnings per share excludes 11,764,211 shares issuable upon the exercise of outstanding warrants and options because their effect would be anti-dilutive.

 

Environmental laws and regulations – The Company is subject to extensive federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on their future economic benefit. The Company believes that it is in compliance with existing laws and regulations. The Company accrued no liability as of June 30, 2019 and December 31, 2018.

 

Recent adopted accounting pronouncements – In February 2016 the FASB, issued ASU, 2016-02, Leases. The ASU requires companies to recognize on the balance sheet the assets and liabilities for the rights and obligations created by leased assets. ASU 2016-02 was effective for the Company in the first quarter of 2019. The Company adopted the change which did not have a material impact on its consolidated financial statements.

 

Other recently issued or adopted accounting pronouncements are not expected to have, or did not have, a material impact on the Company’s financial position or results from operations.

 

Subsequent events – The Company evaluated subsequent events through August 9, 2019, the date of issuance of these financial statements. Subsequent events, if any, are disclosed in Note 11.

 

 

4. OIL & GAS PROPERTIES

 

The following table presents the capitalized costs for oil & gas properties of the Company as of June 30, 2019 and December 31, 2018:

 

Evaluated costs subject to amortization	$ 12,458,270	$ 11,664,586
Unevaluated costs	35,588,036	31,746,477
Total capitalized costs	48,046,306	43,411,063
Less accumulated depreciation, depletion and amortization	(7,644,324 )	(6,845,602 )
Total oil and gas properties	$ 40,401,982	$ 36,565,461

 

Unevaluated costs as of June 30, 2019 include cumulative costs on developing projects including the Orogrande, Hazel, and Winkler projects in West Texas.

 

The Company identified impairment of $2,300,626 in 2017 related to its unevaluated properties. The Company adjusted the separation of evaluated versus unevaluated costs within its full cost pool to recognize the value impairment related to the expiration of unevaluated leases in 2017 in the amount of $2,300,626. The impact of this change was to increase the basis for calculation of future period’s depletion, depreciation and amortization to include $2,300,626 of cost which will effectively recognize the impairment on the consolidated statement of operations over future periods. The $2,300,626 has also become an evaluated cost for purposes of ceiling tests and which may further recognize the impairment expense recognized in future periods. The impact of this cost reclassification at March 31, 2018 was a recognized impairment expense of $139,891. Impairment expense was recognized for the six months ended June 30, 2019 of $474,357 as required by the ceiling test calculation.

  

Due to the volatility of commodity prices, should oil and natural gas prices decline in the future, it is possible that a further write-down could occur. Proved reserves are estimated quantities of crude oil, natural gas, and natural gas liquids, which geological and engineering data demonstrate with reasonable certainty to be recoverable from known reservoirs under existing economic and operating conditions. The independent engineering estimates include only those amounts considered to be proved reserves and do not include additional amounts which may result from new discoveries in the future, or from application of secondary and tertiary recovery processes where facilities are not in place or for which transportation and/or marketing contracts are not in place. Estimated reserves to be developed through secondary or tertiary recovery processes are classified as unevaluated properties.

 

 

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TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

4. OIL & GAS PROPERTIES - continued

 

Current Projects

 

As of June 30, 2019, we had interests in four oil and gas projects: the Orogrande Project in Hudspeth County, Texas, the Hazel Project in Sterling, Tom Green, and Irion Counties, Texas, the Winkler Project in Winkler County, Texas and the Hunton wells in partnership with Husky Ventures in central Oklahoma.

 

Orogrande Project, West Texas

 

On August 7, 2014, we entered into a Purchase Agreement with Hudspeth Oil Corporation (“Hudspeth”), McCabe Petroleum Corporation (“MPC”), and Gregory McCabe, our Chairman. Mr. McCabe was the sole owner of both Hudspeth and MPC. Under the terms and conditions of the Purchase Agreement, at closing, we purchased 100% of the capital stock of Hudspeth which holds certain oil and gas assets, including a 100% working interest in approximately 172,000 mostly contiguous acres in the Orogrande Basin in West Texas. As of December 31, 2017, leases covering approximately 134,000 acres remain in effect. As consideration, at closing we issued 868,750 restricted shares of our common stock to Mr. McCabe and paid a total of $100,000 in geologic origination fees to third parties. Additionally, Mr. McCabe has, at his option, a 10% working interest back-in after payout and a reversionary interest if drilling obligations are not met, all under the terms and conditions of a participation and development agreement among Hudspeth, MPC and Mr. McCabe. Mr. McCabe also holds a 4.5% overriding royalty interest in the Orogrande acreage, which he obtained prior to, and was not a part of, the August 2014 transaction. We believe all drilling obligations through June 30, 2019 have been met.

 

On September 23, 2015, Hudspeth entered into a Farmout Agreement with Pandora Energy, LP (“Pandora”), Founders Oil & Gas, LLC (“Founders”), and for the limited purposes set forth therein, MPC and Mr. McCabe, for the entire Orogrande Project in Hudspeth County, Texas. The Farmout Agreement provided that Hudspeth and Pandora (collectively referred to as “Farmor”) would assign to Founders an undivided 50% of the leasehold interest and a 37.5% net revenue interest in the oil and gas leases and mineral interests in the Orogrande Project, which interests, except for any interests retained by Founders, would be reassigned to Farmor by Founders if Founders did not spend a minimum of $45.0 million on actual drilling operations on the Orogrande Project by September 23, 2017. Under a joint operating agreement also entered into on September 23, 2015, Founders was designated as operator of the leases.

 

On March 22, 2017, Founders, Founders Oil & Gas Operating, LLC, Founders’ operating partner, Hudspeth and Pandora signed a Drilling and Development Unit Agreement (the “DDU Agreement”), with the Commissioner of the General Land Office, on behalf of the State of Texas, and as approved by the Board for Lease of University Lands, or University Lands, on the Orogrande Project. The DDU Agreement has an effective date of January 1, 2017 and required a payment from Founders, Hudspeth and Pandora, collectively, of $335,323 as the initial consideration fee. The initial consideration fee was paid by Founders in April 2017 and was to be deducted from the required spud fee payable to us at commencement of the next well drilled.

 

The DDU Agreement allows for all 192 existing leases covering approximately 134,000 net acres leased from University Lands to be combined into one drilling and development unit for development purposes. The term of the DDU Agreement expires on December 31, 2023, and the time to drill on the drilling and development unit continues through December 2023. The DDU Agreement also grants the right to extend the DDU Agreement through December 2028 if compliance with the DDU Agreement is met and the extension fee associated with the additional time is paid. Our drilling obligations began with one well to be spudded and drilled on or before September 1, 2017, and increased to two wells in year 2018, three wells in year 2019, four wells in year 2020 and five wells per year in years 2021, 2022 and 2023. The drilling obligations are minimum yearly requirements and may be exceeded if acceleration is desired. The DDU Agreement replaces all prior agreements, and will govern future drilling obligations on the drilling and development unit if the DDU Agreement is extended. The Company drilled three wells during fourth quarter, 2018.

 

There are two vertical tests wells in the Orogrande Project, the Orogrande Rich A-11 test well and the University Founders B-19 #1 test well. The Orogrande Rich A-11 test well was spudded on March 31, 2015, drilled in the second quarter of 2015 and was evaluated and numerous scientific tests were performed to provide key data for the field development thesis. We believe that future utility of this well may be conversion to a salt water disposal well in the course of further development of the Orogrande acreage. The University Founders B-19 #1 was spudded on April 24, 2016 and drilled in the second quarter of 2016. The well successfully pumped down completion fluid in the third quarter of 2016 and indications of hydrocarbons were seen at the surface on this second Orogrande Project test well. We believe that future utility of this well may be conversion to a salt water disposal well in the course of further development of the Orogrande acreage.

 

 

 

 

 

 

 

 

13

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

4. OIL & GAS PROPERTIES - continued

 

During the fourth quarter of 2017, we took back operational control from Founders on the Orogrande Project. We were joined by Wolfbone Investments, LLC, (“Wolfbone”), a company owned by Mr. McCabe. We, along with Hudspeth, Wolfbone and, for the limited purposes set forth therein, Pandora, entered into an Assignment of Farmout Agreement with Founders, (the “Assignment of Farmout Agreement”), pursuant to which we and Wolfbone will share the remaining commitments under the Farmout Agreement. All original provisions of our carried interest were to remain in place including reimbursement to us on each wellbore. Founders was to remain a 9.5% working interest owner in the Orogrande Project for the $9.5 million it had spent as of the date of the Assignment of Farmout Agreement, and such interests were to be carried until $40.5 million is spent by Wolfbone and us, with each contributing 50% of such capital spend, under the existing agreement. Our working interest in the Orogrande Project thereby increased by 20.25% to a total of 67.75% and Wolfbone then owned 20.25%.

 

Founders was to operate a newly drilled horizontal well called the University Founders #A25 (at 5,540’ depth in a 1,000’ lateral) with supervision from us and our partners. The University Founders #A25 was spudded on November 28, 2017. During the month of April, 2018, we, MPC and Mr. McCabe were to assume full operational control including managing drilling plans and timing for all future wells drilled in the project.

On July 25, 2018, we and Hudspeth entered into a Settlement & Purchase Agreement (the “Settlement Agreement”) with Founders (and Founders Oil & Gas Operating, LLC), Wolfbone and MPC, which agreement provides for Hudspeth and Wolfbone to each immediately pay $625,000 and for Hudspeth or the Company and Wolfbone or MPC to each pay another $625,000 on July 20, 2019, as consideration for Founders assigning all of its working interest in the oil and gas leases of the Orogrande Project to Hudspeth and Wolfbone equally. The final payments were made on July 18, 2019. The assignments to Hudspeth and Wolfbone were made in July when the first payments were made. Future well capital spending obligations will require the same 50% contribution from Hudspeth and 50% from Wolfbone until such time as the $40.5 million to be spent on the project (as per our Assignment of Farmout Agreement with Founders) is completed. The Company estimates that there is still approximately $16 million remaining to be spent on the project until such time as the capital expenditures revert back to the percentages of the working interest owners.

 

After the assignment by Founders (for which Hudspeth’s total consideration is $1,250,000), Hudspeth’s working interest increased to 72.5%.

 

The Orogrande Project ownership as of June 30, 2019 is detailed as follows:

 

	Revenue		Working
	Interest		Interest
University Lands - Mineral Owner	20.000%		n/a
ORRI - Magdalena Royalties, LLC, an entity	4.500%		n/a
controlled by Gregory McCabe, Chairman
ORRI - Unrelated Party	0.500%		n/a
Hudspeth Oil Corporation, a subsidiary of Torchlight	54.375%		72.500%
Energy Resources Inc.
Wolfbone Investments LLC, an entity	18.750%		25.000%
controlled by Gregory McCabe, Chairman
Unrelated Party	1.875%		2.500%
	100.000%		100.000%

 

Additionally, the Settlement Agreement provides that the Founders parties will assign to the Company, Hudspeth, Wolfbone and MPC their claims against certain vendors for damages, if any, against such vendors for negligent services or defective equipment. Further, the Settlement Agreement has a mutual release and waivers among the parties.

 

Rich Masterson, our consulting geologist, is credited with originating the Orogrande Project in Hudspeth County in the Orogrande Basin. With Mr. Masterson’s assistance and based on all the science we have gathered to date, we have identified multiple unconventional and conventional target pay zones with depths between 3,000’ and 8,000’ with primary pay, described as the Penn formation, located at depths of 5,300 to 5,900’. Based on our geologic analysis to date, this basin has stacked pay with zones including the Wolfcamp, Penn, Barnett, Woodford, Atoka and more. These potential zones are prospective for oil and gas with a GOR of 1100 expected based on our gathered scientific information and analysis from independent third parties.

 

 

14

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

4. OIL & GAS PROPERTIES - continued

  

During the fourth quarter, 2018, the Company drilled three additional test wells in the Orogrande in order to stay in compliance with University Lands D&D Unit Agreement, as well as, to test for potential shallow pay zones and deeper pay zones that may be present on structural plays. Development of these wells continued into the six months ended June 30, 2019 to further capture and document the scientific base in support of demonstrating the production potential of the property. The Company is currently marketing the project for an outright sale or farm in partner. This marketing process has been long and ardous as the overall market is quite soft. In addition, due to the size and scope of the project, we are dealing with very large companies that have multitudes of people reviewing our material, which in itself is extensive. During the marketing process, the Company and Wolfbone will endeavor to complete the University Maverick A24 #1 as a potential producer in the Atoka formation. In addition, should a farm out partner or sale not occur, the Company and Wolfbone will proceed to drill two additional wells in the play prior to year-end, in order to fulfill the obligations under the DDU Agreement.

 

Hazel Project in the Midland Basin in West Texas

 

Effective April 4, 2016, TEI acquired from MPC a 66.66% working interest in approximately 12,000 acres in the Midland Basin in exchange for 1,500,000 warrants to purchase shares of our common stock with an exercise price of $1.00 for five years and a back-in after payout of a 25% working interest to MPC.

 

Initial development of the first well on the property, the Flying B Ranch #1, began July 9, 2016 and development continued through September 30, 2016. This well is classified as a test well in the development pursuit of the Hazel Project. We believe that this wellbore will be utilized as a salt water disposal well in support of future development.

 

In October 2016, the holders of all of our then-outstanding shares of Series C Preferred Stock (which were issued in July 2016) elected to convert into a total 33.33% working interest in our Hazel Project, reducing our ownership from 66.66% to a 33.33% working interest. As of December 31, 2018, no shares of our Series C Preferred Stock were outstanding.

 

On December 27, 2016, drilling activities commenced on the second Hazel Project well, the Flying B Ranch #2. The well is a vertical test similar to our first Hazel Project well, the Flying B Ranch #1. Recompletion in an alternative geological formation for this well was performed during the three months ended September 30, 2017; however, we believe that the results were uneconomic for continuing production. We believe that this wellbore will be utilized as a salt water disposal well in support of future development.

 

We commenced planning to drill the Flying B Ranch #3 horizontal well in the Hazel Project in June 2017 in compliance with the continuous drilling obligation. The well was spudded on June 10, 2017. The well was completed and began production in late September 2017. As of June 30, 2019 the well is shut in due to high lease operating expenses as a result of lack of three phase electricity to the property which forced the use of diesel generation equipment to power the production facilities.

 

Acquisition of Additional Interests in Hazel Project

 

On January 30, 2017, we and our then wholly-owned subsidiary, Torchlight Acquisition Corporation, a Texas corporation (“TAC”), entered into and closed an Agreement and Plan of Reorganization and a Plan of Merger with Line Drive Energy, LLC, a Texas limited liability company (“Line Drive”), and Mr. McCabe, under which agreements TAC merged with and into Line Drive and the separate existence of TAC ceased, with Line Drive being the surviving entity and becoming our wholly-owned subsidiary. Line Drive, which was wholly-owned by Mr. McCabe, owned certain assets and securities, including approximately 40.66% of 12,000 gross acres, 9,600 net acres, in the Hazel Project and 521,739 warrants to purchase shares of our common stock (which warrants had been assigned by Mr. McCabe to Line Drive). Upon the closing of the merger, all of the issued and outstanding shares of common stock of TAC automatically converted into a membership interest in Line Drive, constituting all of the issued and outstanding membership interests in Line Drive immediately following the closing of the merger, the membership interest in Line Drive held by Mr. McCabe and outstanding immediately prior to the closing of the merger ceased to exist, and we issued Mr. McCabe 3,301,739 restricted shares of our common stock as consideration therefor. Immediately after closing, the 521,739 warrants held by Line Drive were cancelled, which warrants had an exercise price of $1.40 per share and an expiration date of June 9, 2020. A Certificate of Merger for the merger transaction was filed with the Secretary of State of Texas on January 31, 2017. Subsequent to the closing the name of Line Drive Energy, LLC was changed to Torchlight Hazel, LLC. We are required to drill one well every six months to hold the entire 12,000 acre block for eighteen months, and thereafter two wells every six months starting June 2018. During the six months ended June 30, 2019 modifications were made to mineral owner leases as described below.

 

 

 

15

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

4. OIL & GAS PROPERTIES - continued

  

Also on January 30, 2017, TEI entered into and closed a Purchase and Sale Agreement with Wolfbone. Under the agreement, TEI acquired certain of Wolfbone’s Hazel Project assets, including its interest in the Flying B Ranch #1 well and the 40 acre unit surrounding the well, for consideration of $415,000, and additionally, Wolfbone caused to be cancelled a total of 2,780,000 warrants to purchase shares of our common stock, including 1,500,000 warrants held by MPC, and 1,280,000 warrants held by Green Hill Minerals, an entity owned by Mr. McCabe’s son, which warrant cancellations were effected through certain Warrant Cancellation Agreements. The 1,500,000 warrants held by MPC that were cancelled had an exercise price of $1.00 per share and an expiration date of April 4, 2021. The warrants held by Green Hill Minerals that were cancelled included 100,000 warrants with an exercise price of $1.73 and an expiration date of September 30, 2018 and 1,180,000 warrants with an exercise price of $0.70 and an expiration date of February 15, 2020.

 

Since Mr. McCabe held the controlling interest in both Line Drive and Wolfbone, the transactions were combined for accounting purposes. The working interest in the Hazel Project was the only asset held by Line Drive. The warrant cancellation was treated in the aggregate as an exercise of the warrants with the transfer of the working interests as the consideration. We recorded the transactions as an increase in its investment in the Hazel Project working interests of $3,644,431, which is equal to the exercise price of the warrants plus the cash paid to Wolfbone.

 

Upon the closing of the transactions, our working interest in the Hazel Project increased by 40.66% to a total ownership of 74%.

 

Effective June 1, 2017, we acquired an additional 6% working interest from unrelated working interest owners in exchange for 268,656 shares of common stock valued at $373,430, increasing our working interest in the Hazel project to 80%, and an overall net revenue interest of 74-75%.

 

Mr. Masterson is credited with originating the Hazel Project in the Midland Basin. With Mr. Masterson’s assistance, we are targeting prospects in the Midland Basin that have 150 to 130 feet of thickness, are likely to require six to eight laterals per bench, have the potential for 12 to 16 horizontal wells per section, and 200 long lateral locations, assuming only two benches.

  

In April 2018, we announced that we have commenced a process that could result in the monetization of the Hazel Project. We believe the development activity at the Hazel Project, coupled with nearby activities of other oil and gas operators, suggests that this project has achieved a level of value worth monetizing. We anticipate that the liquidity that would be provided from selling the Hazel Project could be redeployed into the Orogrande Project. While this process is underway, we will take all necessary steps to maintain the leasehold as required. As of this filing, we continue to maintain the leases in good standing and continue to market the acreage in an effort to focus on the Orogrande Project.

 

During the six months ended June 30, 2019 the Company deepened the Flying B #4 and took whole cores through all of the Wolfcamp A and the upper portion of the Wolfcamp B. We anticipate having the results of the core work back from Schlumberger before the end of August, 2019. In addition, in May, 2019 we entered into agreements with two of the three mineral owners on the northern section of the leases to keep the entire acreage block as one lease with a one year extension. We issued each of them 50,000 shares of our common stock as consideration for this extension. At June 30, 2019 we were structuring the extension agreement with the third mineral owner for cash consideration. Due to this extension, our obligation in November reduces to one obligation well.

 

The marketing process is ongoing for the Hazel project. We continue to encounter, as does the entire industry, a soft market for acquisitions and divestitures transactions. We will continue to look to sell the property or joint venture the property via farm in or a drillco transaction.

 

Winkler Project, Winkler County, Texas

 

On December 1, 2017, the Agreement and Plan of Reorganization that we and our then wholly-owned subsidiary, Torchlight Wolfbone Properties, Inc., a Texas corporation (“TWP”), entered into with MPC and Warwink Properties, LLC (Warwink Properties) on November 14, 2017 closed. Under the agreement, TWP merged with and into Warwink Properties and the separate existence of TWP ceased, with Warwink Properties being the surviving entity and becoming our wholly-owned subsidiary. Warwink Properties was wholly owned by MPC. Warwink Properties owns certain assets, including a 10.71875% working interest in approximately 640 acres in Winkler County, Texas. Upon the closing of the merger, all of the issued and outstanding shares of common stock of TWP converted into a membership interest in Warwink Properties, constituting all of the issued and outstanding membership interests in Warwink Properties immediately following the closing of the merger, the membership interest in Warwink Properties held by MPC and outstanding immediately prior to the closing of the merger ceased to exist, and we issued MPC 2,500,000 restricted shares of our common stock as consideration. Also on December 1, 2017, MPC closed its transaction with MECO IV, LLC (” MECO”), for the purchase and sale of certain assets as contemplated by the Purchase and Sale Agreement dated November 9, 2017 among MPC, MECO and additional parties thereto (the “MECO PSA”), to which we are not a party. Under the MECO PSA, Warwink Properties received a carry from MECO (through the tanks) of up to $1,179,076 in the next well drilled on the Winkler County leases. A Certificate of Merger for the merger transaction was filed with the Secretary of State of Texas on December 5, 2017.

 

Also on December 1, 2017, the transactions contemplated by the Purchase Agreement that TEI entered into with MPC closed. Under the Purchase Agreement, which was entered into on November 14, 2017, TEI acquired beneficial ownership of certain of MPC’s assets, including acreage and wellbores located in Ward County, Texas (the “Ward County Assets”). As consideration under the Purchase Agreement, at closing TEI issued to MPC an unsecured promissory note in the principal amount of $3,250,000, payable in monthly installments of interest only beginning on January 1, 2018, at the rate of 5% per annum, with the entire principal amount together with all accrued interest due and payable on January 1, 2021. In connection with TEI’s acquisition of beneficial ownership in the Ward County Assets, MPC sold those same assets, on behalf of TEI, to MECO at closing of the MECO PSA, and accordingly, TEI received $3,250,000 in cash for its beneficial interest in the Ward County Assets. Additionally, at closing of the MECO PSA, MPC paid TEI a performance fee of $2,781,500 in cash as compensation for TEI’s marketing and selling the Winkler County assets of MPC and the Ward County Assets as a package to MECO.  

 

16

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

4. OIL & GAS PROPERTIES - continued

 

Addition to the Winkler Project

 

As of May 7, 2018 our Winkler project in the Delaware Basin had begun the drilling phase of the first Winkler Project well, the UL 21 War-Wink 47 #2H. Our operating partner, MECO had begun the pilot hole on the project. The plan is to evaluate the various potential zones for a lateral leg to be drilled once logging is completed. We expect the most likely target to be the Wolfcamp A interval. The well is on 320 newly acquired acres offsetting the original leasehold we entered into in December, 2017. The additional acreage was leased by our operating partner under the Area of Mutual Interest Agreement (AMI) and we exercised its right to participate for its 12.5% in the additional 1,080 gross acres at a cash cost of $447,847 in July, 2018. Our carried interest in the first well, as outlined in the agreement, was originally planned to be on the first acreage acquired. That carried interest is being applied to this new well and will allow MECO to drill and produce potential revenues sooner than originally planned. The primary leasehold is a 320-acre block directly west of the current position and will allow for 5,000-foot lateral wells to be drilled. The well was completed and began production in October, 2018 and is producing currently. Recently the operator has informed us that there will be no planned additional wells in the acreage this year. All acreage is presently held by production.

 

In December 2018, the Company began to take measures on its own to market the Warwink Project in an effort to focus on the Orogrande. This process is ongoing.

 

Assets Held for Sale

 

With respect to marketing oil and natural gas properties, the Company has evaluated the properties being marketed to determine whether any should be reclassified as held-for-sale at June 30, 2019. The held-for-sale criteria include: management commits to a plan to sell; the asset is available for immediate sale; an active program to locate a buyer exists; the sale of the asset is probable and expected to be completed within one year; the asset is being actively marketed for sale; and it is unlikely that significant changes to the plan will be made. If each of these criteria is met, the property would be reclassified as held-for-sale on the Company’s consolidated balance sheets and measured at the lower of their carrying amount or estimated fair value less costs to sell. Fair values are estimated using accepted valuation techniques, such as a discounted cash flow model, valuations performed by third parties, earnings multiples, or indicative bids, when available. Management considers historical experience and all available information at the time the estimates are made; however, the fair value that is ultimately realized upon the sale of the assets to be divested may differ from the estimated fair values reflected in the consolidated financial statements. If each of these criteria is met, DD&A expense would not be recorded on assets to be divested once they are classified as held for sale. Based on management’s assessment, these criteria have not been met and no assets are classified as held for sale as of June 30, 2019.

 

 

5. RELATED PARTY PAYABLES

 

As of June 30, 2019 and December 31, 2018, related party payables of $45,000 and accrued payroll of $906,176 and $816,176, respectively, consist of accrued and unpaid compensation due to our executive officers.

 

 

6. COMMITMENTS AND CONTINGENCIES

 

Leases

 

The Company has a noncancelable lease for its office premises that expires on November 30, 2019 and which requires the payment of base lease amounts and executory costs such as taxes, maintenance and insurance. Effective June 1, 2019 the Company entered into an agreement with a company that had been subleasing a portion of its office space to become the primary obligor on the lease and to assume full responsibility for lease payments after lease expiration on November 30, 2019. The Company will continue after November 30, 2019 as a subtenant on a month to month basis.

 

Approximate future minimum rental commitments under the office premises lease total $32,220 through the expiration date of November 30, 2019.

 

Environmental matters

 

The Company is subject to contingencies as a result of environmental laws and regulations. Present and future environmental laws and regulations applicable to the Company’s operations could require substantial capital expenditures or could adversely affect its operations in other ways that cannot be predicted at this time. As of June 30, 2019 and December 31, 2018, no amounts had been recorded because no specific liability has been identified that is reasonably probable of requiring the Company to fund any future material amounts.

 

 

 

17

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

7. STOCKHOLDERS’ EQUITY

 

Common Stock

 

During the six months ended June 30, 2019, the Company issued 2,287,600 shares of common stock for cash of $1,674,080 and $156,000 in subscriptions receivable at June 30, 2019.

 

During the six months ended June 30, 2019, the Company issued 192,593 shares of common stock with a fair value of $249,000 as compensation for services.

 

During the six months ended June 30, 2019, the Company issued 60,342 shares of common stock valued at $65,168 in payment of interest accrued on notes payable.

 

During the six months ended June 30, 2019, the Company issued 168,690 shares of common stock resulting from warrant and option exercise for consideration totaling $184,843.

 

The Company issued 100,000 shares of common stock effective May 1, 2019, as compensation for an extension of oil and gas lease expiration valued at $125,000.

 

In April 2019, the Company issued 202,316 shares of common stock in satisfaction of the payment in kind valued at $314,108 due on April 10, 2019 to the holders of notes payable by the Company.

 

Warrants and Options

 

During the six months ended June 30, 2019, the Company issued 200,000 warrants and options with total fair value of $154,000 as compensation for services and recorded expense of $255,250 related to warrants and options issued in prior periods.

 

In connection with the issuance of common stock for cash during the six months ended June 30, 2019, 1,592,600 warrants were surrendered to the Company for cancellation.

      

A summary of warrants outstanding as of June 30, 2019 by exercise price and year of expiration is presented below:

 

Exercise	Expiration Date in
Price	2019	2020	2021	2023	2024	Total
$ 0.70	-	420,000	-	-	-	420,000
$ 1.03	-	-	120,000	-	-	120,000
$ 1.14	-	-	-	600,000	-	600,000
$ 1.21	-	-	-	120,000	-	120,000
$ 1.40	-	321,737	-	-	-	321,737
$ 1.63	-	-	-	-	100,000	100,000
$ 1.64	-	-	200,000	-	-	200,000
$ 1.80	-	1,250,000	-	-	-	1,250,000
$ 2.00	-	-	200,000	-	-	200,000
$ 2.23	-	339,901	-	-	-	339,901
$ 2.50	35,211	-	-	-	-	35,211
$ 3.50	15,000	-	-	-	-	15,000
$ 4.50	700,000	-	-	-	-	700,000
$ 6.00	24,594	-	-	-	-	24,594
$ 7.00	700,000	-	-	-	-	700,000
	1,474,805	2,331,638	520,000	720,000	100,000	5,146,443

 

 

18

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

7. STOCKHOLDERS’ EQUITY - continued

 

A summary of stock options outstanding as of June 30, 2019 by exercise price and year of expiration is presented below:

 

Exercise	Expiration Date in
Price	2020	2021	2022	2023	Total
$ 0.97	-	259,742	-	-	259,742
$ 1.10	-	-	800,000	-	800,000
$ 1.19	-	-	-	700,000	700,000
$ 1.57	4,500,000	-	-	-	4,500,000
$ 1.63	-	-	58,026	-	58,026
$ 1.79	300,000	-	-	-	300,000
	4,800,000	259,742	858,026	700,000	6,617,768

 

At June 30, 2019, the Company had reserved 11,764,211common shares for future exercise of warrants and options.

 

Warrants and options granted were valued using the Black-Scholes Option Pricing Model. The assumptions used in calculating the fair value of the warrants and options issued were as follows:

 

2019
Risk-free interest rate	2.40% - 2.46%
Expected volatility of common stock	105% - 107%
Dividend yield	0.00%
Discount due to lack of marketability	20%
Expected life of option/warrant	Five Years

 

2018
Risk-free interest rate	2.15% - 2.82%
Expected volatility of common stock	106% - 119%
Dividend yield	0.00%
Discount due to lack of marketability	20%
Expected life of option/warrant	Three to Five Years

 

 

8. INCOME TAXES

 

The Company recorded no income tax provision for 2019 and 2018 because of losses incurred.

 

The Company estimates its annual effective income tax rate in recording its quarterly provision for income taxes in the various jurisdictions in which it operates. Statutory tax rate changes and other significant or unusual items are recognized as discrete items in the quarter in which they occur. The Company recorded no income tax expense for the six months ended June 30, 2019 because the Company expects to incur a tax loss in the current year. Similarly, no income tax expense was recognized for the six months ended June 30, 2018.

 

The Company had a net deferred tax asset related to federal net operating loss carryforwards of $58,308,696 and $56,992,857 at June 30, 2019 and December 31, 2018, respectively. The federal net operating loss carryforward will begin to expire in 2033. Realization of the deferred tax asset is dependent, in part, on generating sufficient taxable income prior to expiration of the loss carryforwards. The Company has placed a 100% valuation allowance against the net deferred tax asset because future realization of these assets is not assured.

 

 

19

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

9. PROMISSORY NOTES

 

On April 10, 2017, the Company sold to investors in a private transaction two 12% unsecured promissory notes with a total of $8,000,000 in principal amount. Interest only is due and payable on the notes each month at the rate of 12% per annum, with a balloon payment of the outstanding principal due and payable at maturity on April 10, 2020. The holders of the notes will also receive annual payments of common stock at the rate of 2.5% of principal amount outstanding, based on a volume-weighted average price. Both notes were sold at an original issue discount of 94.25% and accordingly, we received total proceeds of $7,540,000 from the investors. We used the proceeds for working capital and general corporate purposes, which includes, without limitation, drilling capital, lease acquisition capital and repayment of prior debt.

 

These 12% promissory notes allow for early redemption. The notes also contain certain covenants under which we have agreed that, except for financing arrangements with established commercial banking or financial institutions and other debts and liabilities incurred in the normal course of business, we will not issue any other notes or debt offerings which have a maturity date prior to the payment in full of the 12% notes, unless consented to by the holders.

 

The effective interest rate is 16.15%.

 

On April 24, 2017, we used $2,509,500 of the proceeds from this financing to redeem and repay a portion of the outstanding 12% Series B Convertible Unsecured Promissory Notes. Separately, $1,000,000 of the principal amount of the Series B Notes plus accrued interest was converted into 1,007,890 shares of common stock and $64,297 was rolled into the new debt financing.

 

On February 6, 2018, we sold to an investor in a private transaction a 12% unsecured promissory note with a principal amount of $4,500,000. Interest only is due and payable on the note each month at the rate of 12% per annum, with a balloon payment of the outstanding principal due and payable at maturity on April 10, 2020. The holder of the note will also receive annual payments of common stock at the rate of 2.5% of principal amount outstanding, based on a volume-weighted average price. We sold the note at an original issue discount of 96.27% and accordingly, we received total proceeds of $4,332,150 from the investor. We used the proceeds for working capital and general corporate purposes, which includes, without limitation, drilling capital, lease acquisition capital and repayment of prior debt.

 

This 12% promissory note allows for early redemption, provided that if we redeem before February 6, 2019, we must pay the holder all unpaid interest and common stock payments on the portion of the note redeemed that would have been earned through February 6, 2019. The note also contains certain covenants under which we have agreed that, except for financing arrangements with established commercial banking or financial institutions and other debts and liabilities incurred in the normal course of business, we will not issue any other notes or debt offerings which have a maturity date prior to the payment in full of the 12% note, unless consented to by the holder.

 

The effective interest rate is 15.88%.

 

In April 2019 and 2018, respectively, the holders of the notes described above received 202,316 and 172,342 shares of common stock as a payment in kind representing the annual payments of common stock due at the rate of 2.5% of principal amount outstanding as of April 10 based on a volume-weighted average price calculation.

 

Unsecured promissory note transactions through June 30, 2019 are summarized as follows:

 

Unsecured promissory note balance - December 31, 2018	$ 11,862,080
Accretion of discount and amortization of debt issuance costs	257,875
Unsecured promissory note balance - June 30, 2019	$ 12,119,955

 

 

20

 

 

TORCHLIGHT ENERGY RESOURCES, INC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

 

9. PROMISSORY NOTES - continued

 

On October 17, 2018, we sold to certain investors in a private transaction 16% Series C Unsecured Convertible Promissory Notes with a total principal amount of $6,000,000. Interest and principal are due and payable on the notes in one balloon payment at maturity on April 17, 2020. The notes are convertible, at the election of the holders, into an aggregate 6% working interest in certain oil and gas leases in Hudspeth County, Texas, known as our “Orogrande Project.” After an analysis of the transaction and a review of applicable accounting pronouncements, management concluded that the notes issued on October 17, 2018 which contain a conversion right for holders to convert into a working interest in the Orogrande Project of the Company, meet a specific scope exception to the provisions requiring derivative accounting.

 

The notes allow us to redeem them early only upon the event of a fundamental transaction, such as a merger or sale of substantially all our assets. The notes provide that the noteholders may accelerate and declare any and all of the obligations under the notes to be immediately due and payable in the event of default, such as nonpayment, failure to perform required conversions, failure to perform any covenant or agreement under the notes, an insolvency event, or certain defaults or judgments. As part of the sale of the of the notes, the noteholders required that McCabe Petroleum Corporation, a Texas corporation owned by our Chairman Gregory McCabe (“MPC”), provide them a put option whereby they have the right to have MPC purchase from them any unpaid principal amount due on the notes. Additionally, if there is a fundamental transaction, Mr. McCabe will be required to pay a fee to each noteholder that elects not to convert or require MPC to purchase the principal amount under the note, which fee will be equal to such noteholder’s pro-rata share of a total fee amount of $1,500,000.

 

We received total proceeds of $6,000,000 from the sale of the notes, of which $3,000,000 was used to pay back the promissory note issued to MPC on December 1, 2017, which note was due on December 31, 2020. We used the remaining proceeds for working capital and general corporate purposes, which includes, without limitation, drilling and lease acquisition capital.

 

Prior to entering into the above transactions, our Board of Directors formed a special committee composed of independent directors to analyze and authorize the transactions on behalf of Torchlight Energy Resources, Inc. and determine whether the transactions are fair to the company. In this role, the special committee engaged an independent financial consulting firm which rendered a fairness opinion deeming that the transactions were fair to the company, from a financial point of view, and contained terms no less favorable to the company than those that could be obtained in arm’s length transactions.

 

In February and March, 2019 the Company raised a total of $2,000,000 from investors through the sale of 14% Series D Unsecured Convertible Promissory Notes. Principal is payable in a lump sum at maturity on May 11, 2020 with payments of interest payable monthly at the rate of 14% per annum. Holders of the notes have the right to convert principal and interest at any time into common stock at a conversion price of $1.08 per share. The Company has the right to redeem the notes at any time, provided that the redemption amount must include all interest that would have been earned through maturity. The Company evaluated the notes for beneficial conversion features and derivative accounting criteria and concluded that derivative accounting treatment is not applicable.

 

 

10. ASSET RETIREMENT OBLIGATIONS

 

The following is a reconciliation of the asset retirement obligations liability through June 30, 2019:

 

Asset retirement obligations – December 31, 2018	$ 14,353
Accretion expense	284
Estimated liabilities recorded	6,325
Asset retirement obligations – June 30, 2019	$ 20,962

 

 

11. SUBSEQUENT EVENTS

 

Subsequent to June 30, 2019 the Company issued 858,500 shares of its common stock in exchange for $686,800 in cash.

 

Additionally, the Company issued 8% Unsecured Convertible Promissory notes in the amount of $2,010,000. The principal and accrued interest on the notes are convertible into shares of common stock at $1.10 per common share at any time after the original issue date. Along with the notes, three year warrants equal to 20% of the number of shares of common stock issuable upon the conversion of the notes were issued to note holders. The warrants are exercisable at $1.35 per share.

 

 

21

 

 

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

 

Overview

 

We are engaged in the acquisition, exploration, exploitation, and/or development of oil and natural gas properties in the United States.

 

During the year ended December 31, 2016, the Board of Directors initiated a review of Company operations in view of the divestiture of its Oklahoma properties, which included the previous sale of the Chisholm Trail and Cimarron properties. During 2016 development had continued on the Orogrande Project in West Texas, and in April 2016 the Company acquired the Hazel Project in the Midland Basin also in West Texas. These West Texas properties demonstrate significant potential and future production capabilities based upon the analysis of scientific data being gathered in the day by day development activity. Therefore, the Board determined to focus its efforts and capital on these projects to maximize shareholder value for the long run. The strategy in divesting of projects was to refocus on the greatest potential future value for the Company while systematically eliminating debt as noncore assets are sold and operations are streamlined.

 

During 2017 the Company increased its commitment to the Orogrande and Hazel Projects. Additional working interests were acquired and test wells were drilled on the properties which is detailed in the Properties section of this filing. Near the end of 2017 the Warwink Project, also in West Texas, was acquired.

 

During 2018 the Company continued development in the Orogrande and Hazel Projects. Additional test wells were drilled to capture additional science data to support lease value. Production from the Hazel Flying B #3 continued through 2018. The carried well provision of the Warwink acquisition in 2017 was fulfilled with the drilling of the Warwink #47-H. That well began production in October, 2018.

 

Development continued in our Orogrande and Hazel Projects during the six months ended June 30, 2019 resulting in additional gathering of scientific data to be available to potential acquirers.

 

During the quarter ended June 30, 2019, the Company continued its offering of the Hazel and Warwink Projects for sale and to offer its Orogrande Project for sale or farm in.

 

The following discussion of our financial condition and results of operations should be read in conjunction with our unaudited financial statements included herewith and our audited financial statements for the year ended December 31, 2018. This discussion should not be construed to imply that the results discussed herein will necessarily continue into the future, or that any conclusion reached herein will necessarily be indicative of actual operating results in the future. Such discussion represents only the best present assessment by our management.

 

Historical Results for the three months ended June 30, 2019 and 2018:

 

Revenues and Cost of Revenues

 

For the three months ended June 30, 2019, we had production revenue of $237,075 compared to $283,263 for the three months ended June 30, 2018. Refer to the table of production and revenue included below for quarterly changes in revenue. Our cost of revenue, consisting of lease operating expenses and production taxes, was $113,698 and $184,425 for the three months ended June 30, 2019 and 2018, respectively.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

22

 

 

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - continued

 

Property	Quarter	Oil Production {BBLS}	Gas Production {MCF}	Oil Revenue	Gas Revenue	Total Revenue
Oklahoma	Q1 - 2019	56	1,072	$ 2,567	$ 2,333	$ 4,900
Hazel (TX)	Q1 - 2019	2,864	0	131,901	-	131,901
MECO (TX)	Q1 - 2019	3,525	2,565	167,677	6,359	174,036
Total Q1-2019		6,445	3,637	$ 302,145	$ 8,692	$ 310,837
Oklahoma	Q2 - 2019	43	1,770	$ 2,477	$ 2,450	$ 4,927
Hazel (TX)	Q2 - 2019	1,123	0	64,302	-	64,302
Meco (TX)	Q2 - 2019	2,585	2,623	156,259	11,587	167,846
Total Q2-2018		3,751	4,393	$ 223,038	$ 14,037	$ 237,075
2019 Year To Date		10,196	8,030	$ 525,183	$ 22,729	$ 547,912
Oklahoma	Q1 - 2018	72	2,008	$ 4,463	$ 5,202	$ 9,665
Hazel (TX)	Q1 - 2018	7,786	0	471,498	-	471,498
Total Q1-2018		7,858	2,008	$ 475,961	$ 5,202	$ 481,163
Oklahoma	Q2 - 2018	446	1,857	$ 10,912	$ 2,690	$ 13,602
Hazel (TX)	Q2 - 2018	4,368	0	266,506	-	266,506
Meco (TX)	Q2 - 2018	51	0	3,155	-	3,155
Total Q2-2018		4,865	1,857	$ 280,573	$ 2,690	$ 283,263
Oklahoma	Q3 - 2018	41	2,324	$ 1,264	$ 3,845	$ 5,109
Hazel (TX)	Q3 - 2018	2,283	0	123,566	-	123,566
Meco (TX)	Q3 - 2018	0	0	-	-	-
Total Q3-2018		2,324	2,324	$ 124,830	$ 3,845	$ 128,675
Oklahoma	Q4 - 2018	94	986	$ 4,878	$ 1,104	$ 5,982
Hazel (TX)	Q4 - 2018	3,779	0	178,015	-	178,015
Meco (TX)	Q4 - 2018	3,967	10,646	192,916	12,348	205,264
Total Q4-2018		7,840	11,632	$ 375,809	$ 13,452	$ 389,261
2018 Year To Date		22,887	17,821	$ 1,257,173	$ 25,189	$ 1,282,362

 

 

 

 

 

 

23

 

 

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - continued

 

We recorded depreciation, depletion, and amortization expense of $142,269 for the three months ended June 30, 2019 compared to $154,805 for the three months ended June 30, 2018.

 

General and Administrative Expenses

 

Our general and administrative expenses for the three months ended June 30, 2019 and 2018 were $665,160 and $907,595, respectively, a decrease of $242,435. Our general and administrative expenses consisted of consulting and compensation expense, substantially all of which was non-cash or deferred, accounting and administrative costs, professional consulting fees, and other general corporate expenses. The change in general and administrative expenses for the three months ended June 30, 2019 compared to 2018 is detailed as follows:

 

Increase(decrease) in non cash stock and warrant compensation	$ (2,600 )
Increase(decrease) in consulting expense	(92,236 )
Increase(decrease) in investor relations	(26,801 )
Increase(decrease) in travel expense	(407 )
Increase(decrease) in salaries and compensation	(28,478 )
Increase(decrease) in legal fees	(352 )
Increase(decrease) in filing and compliance fees	(19,223 )
Increase(decrease) in insurance	(23,119 )
Increase(decrease) in audit fees	(36,040 )
Increase(decrease) in general corporate expenses	(13,179 )
Total Decrease in General and Administrative Expenses	$ (242,435 )

 

Historical Results for the six months ended June 30, 2019 and 2018:

 

Revenues and Cost of Revenues

 

For the six months ended June 30, 2019, we had production revenue of $547,912 compared to $764,426 for the six months ended June 30, 2018. Refer to the table of production and revenue included above for quarterly changes in revenue. Our cost of revenue, consisting of lease operating expenses and production taxes, was $241,320 and $413,328 for the six months ended June 30, 2019 and 2018, respectively.

 

We recorded depreciation, depletion, and amortization expense of $327,695 for the six months ended June 30, 2019 compared to $261,938 for the six months ended June 30, 2018.

 

General and Administrative Expenses

 

Our general and administrative expenses for the six months ended June 30, 2019 and 2018 were $1,707,918 and $2,583,434, respectively, a decrease of $875,516. Our general and administrative expenses consisted of consulting and compensation expense, substantially all of which was non-cash or deferred, accounting and administrative costs, professional consulting fees, and other general corporate expenses. The change in general and administrative expenses for the six months ended June 30, 2019 compared to 2018 is detailed as follows:

 

Increase(decrease) in audit fees	$ (57,741 )
Increase(decrease) in consulting expense	(140,175 )
Increase(decrease) in filing and compliance fees	(95,861 )
Increase(decrease) in insurance	(13,098 )
Increase(decrease) in investor relations	(103,163 )
Increase(decrease) in legal fees	(32,649 )
Increase(decrease) in non cash stock and warrant compensation	(327,265 )
Increase(decrease) in salaries and compensation	(91,138 )
Increase(decrease) in travel expense	7,504
Increase(decrease) in general corporate expenses	(21,930 )
Total (Decrease) in General and Administrative Expenses	$ (875,516 )

 

 

24

 

 

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS - continued

 

Liquidity and Capital Resources

At June 30, 2019, we had working capital deficit of $21,756,612 and total assets of $41,420,376. Stockholders’ equity was $18,631,717. The negative working capital is principally due to the maturity of the Company’s promissory notes now due within one year (April 2020).The Company has begun efforts to either refinance and/or extend the maturities on the notes.

 

Cash flows from operating activities for the six months ended June 30, 2019 was $276,393 compared to $(611,532) for the six months ended June 30, 2018, an increase of $887,925. Cash flows from operating activities for the six months ended June 30, 2019 can be primarily attributed to net loss from operations of $2,568,508, stock based compensation of $658,250, an impairment expense of $474,357, and other noncash expense adjustments. Cash flows from operating activities for the six months ended June 30, 2018 can be primarily attributed to net loss from operations of $3,266,323 and $1,000,146 in stock compensation expense and the increase in prepayment of development costs. Reference the Consolidated Statements of Cash Flows for additional detail of the components that comprise the net use of cash in operations. We expect to continue to use cash flow in operating activities until such time as we achieve sufficient commercial oil and gas production to cover all of our cash costs.

 

Cash flows from investing activities for the six months ended June 30, 2019 was $(4,559,494) compared to $(7,531,151) for the six months ended June 30, 2018. Cash flows from investing activities principally consists of investment in oil and gas properties in Texas.

 

Cash flows from financing activities for the six months ended June 30, 2019 was $3,858,923 as compared to $10,232,509 for the six months ended June 30, 2018. Cash flows from financing activities consists of proceeds from issuance of our common stock and additional borrowings under notes payable. We expect to continue to have cash flow provided by financing activities as we seek new rounds of financing and continue to develop our oil and gas investments.

 

We will require additional debt or equity financing to meet our plans and needs. We face obstacles in continuing to attract new financing due to industry conditions and our history and current record of net losses. Despite our efforts, we can provide no assurance that we will be able to obtain the financing required to meet our stated objectives or even to continue as a going concern.

 

We do not expect to pay cash dividends on our common stock in the foreseeable future.

 

Commitments and Contingencies-

 

Operating Leases

 

The Company has a noncancelable lease for its office premises that expires on November 30, 2019 and which requires the payment of base lease amounts and executory costs such as taxes, maintenance and insurance. Effective June 1, 2019 the Company entered into an agreement with a company that had been subleasing a portion of its office space to become the primary obligor on the lease and to assume full responsibility for lease payments after lease expiration on November 30, 2019. The Company will continue after November 30, 2019 as a subtenant on a month-to- month basis.

 

Approximate future minimum rental commitments under the office premises lease total $32,220 through the expiration date of November 30, 2019.

 

Environmental matters

 

We are subject to contingencies as a result of environmental laws and regulations. Present and future environmental laws and regulations applicable to our operations could require substantial capital expenditures or could adversely affect our operations in other ways that cannot be predicted at this time. As of June 30, 2019 and December 31, 2018, no amounts have been recorded because no specific liability has been identified that is reasonably probable of requiring us to fund any future material amounts.

 

 

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 

Not Applicable

 

 

 

25

 

 

ITEM 4. CONTROLS AND PROCEDURES

 

Disclosure Controls and Procedures

 

Under the supervision and with the participation of our management, including our Chief Executive Officer (principal executive officer) and Chief Financial Officer (principal financial officer), we evaluated the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as of June 30, 2019. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective to ensure that the information required to be disclosed by us in the reports we submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the applicable rules and forms and that such information was accumulated and communicated to our Chief Executive Officer and Chief Financial Officer, in a manner that allowed for timely decisions regarding disclosure.

 

Changes in Internal Control over Financial Reporting

 

There were no changes during the quarter ended June 30, 2019 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II OTHER INFORMATION

   

 

ITEM 1. LEGAL PROCEEDINGS

 

None

 

 

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

 

In June 2019, the Company sold a total of 545,000 of shares of common stock through private placements for total consideration of $436,000.

 

In April 2019, the Company issued 100,000 shares of common stock as compensation for consulting services valued at $149,000.

 

The Company issued 100,000 shares of common stock effective May 1, 2019, as compensation for an extension of oil and gas lease expiration valued at $125,000.

 

In April and May 2019, the Company issued 46,796 shares of common stock valued at $50,540 in payment of interest accrued on notes payable.

 

In April 2019, the Company issued 202,316 shares of common stock in satisfaction of the payment in kind valued at $314,107 due on April 10, 2019 to the holders of notes payable by the Company.

 

In April 2019, the Company issued 68,690 shares of common stock for options exercised at the price of $1.57 per share for total consideration of $107,843.

 

All of the above sales of securities were sold under the exemption from registration provided by Section 4(a)(2) of the Securities Act of 1933 and the rules and regulations promulgated thereunder. The issuances of securities did not involve a “public offering” based upon the following factors: (i) the issuances of securities were isolated private transactions; (ii) a limited number of securities were issued to a limited number of purchasers; (iii) there were no public solicitations; (iv) the investment intent of the purchasers; and (v) the restriction on transferability of the securities issued.

 

 

 

 

26

 

 

ITEM 6. EXHIBITS

 

Exhibit No.

Description

 

2.1		Share Exchange Agreement dated November 23, 2010. (Incorporated by reference from Form 8-K filed with the SEC on November 24, 2010.) *
3.1		Articles of Incorporation. (Incorporated by reference from Form 10-K filed with the SEC on March 18, 2019.)
3.2		Certificate of Amendment to Articles of Incorporation dated December 10, 2014. (Incorporated by reference from Form 10-Q filed with the SEC on May 15, 2015.) *

 

3.3		Certificate of Amendment to Articles of Incorporation dated September 15, 2015. (Incorporated by reference from Form 10-Q filed with the SEC on November 12, 2015.) *
3.4		Certificate of Amendment to Articles of Incorporation dated August 18, 2017 (Incorporated by reference from Form 10-Q filed with the SEC on November 9, 2018.) *
3.5		Amended and Restated Bylaws (Incorporated by reference from Form 8-K filed with the SEC on October 26, 2016.) *

 

10.1		Employment Agreement (with John A. Brda) (Incorporated by reference from Form 8-K filed with the SEC on June 16, 2015.) *
10.2		Employment Agreement (with Roger Wurtele) (Incorporated by reference from Form 8-K filed with the SEC on June 16, 2015.) *

 

10.3		Farmout Agreement between Hudspeth Oil Corporation, Founders Oil & Gas, LLC and certain other parties (Incorporated by reference from Form 8-K filed with the SEC on September 29, 2015) *
10.4		Purchase and Sale Agreement with Husky Ventures, Inc. (Incorporated by reference from Form 8-K filed with the SEC on November 12, 2015) *
10.5		Purchase Agreement with McCabe Petroleum Corporation for acquisition of “Hazel Project” (Incorporated by reference from Form 10-Q filed with the SEC on August 15, 2016) *
10.6		Agreement and Plan of Reorganization and Plan of Merger with Line Drive Energy, LLC (Incorporated by reference from Form 10-K filed with the SEC on March 31, 2017) *

 

10.7

Purchase and Sale Agreement with Wolfbone Investments, LLC (Incorporated by reference from Form 10-K filed with the SEC on March 31, 2017) *

 

10.8		12% 2020 Senior Unsecured Promissory Note (form of) (Incorporated by reference from Form 10-Q filed with the SEC on May 12, 2017) *
10.9		Agreement and Plan of Reorganization and Plan of Merger with McCabe Petroleum Corporation and Warwink Properties, LLC(Incorporated by reference from Form 10-K filed with the SEC on March 16, 2018) *
10.10		Purchase Agreement with Torchlight Energy, Inc. and McCabe Petroleum Corporation (Incorporated by reference from Form 10-K filed with the SEC on March 16, 2018) *
10.11		Promissory Note for $3,250,000 by Torchlight Energy, Inc. to McCabe Petroleum Corporation (Incorporated by reference from Form 10-K filed with the SEC on March 16, 2018) *
10.12		Assignment of Farmout Agreement between Hudspeth Oil Corporation, Founders Oil & Gas, LLC and Wolfbone Investments, LLC (Incorporated by reference from Form 10-K filed with the SEC on March 16, 2018) *

 

 

27

 

 

ITEM 6. EXHIBITS - continued

 

10.13		12% 2020 Senior Unsecured Promissory Note for $4,500,000 with David A. Straz, Jr Revocable Trust of 1986 (Incorporated by reference from Form 10-K filed with the SEC on March 16, 2018) *
10.14		Underwriting Agreement, dated April 19, 2018, between Torchlight Energy Resources, Inc. and Roth Capital Partners, LLC (Incorporated by reference from Form 8-K filed with the SEC on April 19, 2018) *
10.15		Purchase & Settlement Agreement, dated July 24, 2018, between Torchlight Energy Resources, Inc., Hudspeth Oil Corporation, Founders Oil & Gas, LLC, Founders Oil & Gas Operating, LLC, Wolfbone Investments, LLC and McCabe Petroleum. Corporation (Incorporated by reference from Form 10-Q filed with the SEC on August 9, 2018) *
10.16		16% Series C Unsecured Convertible Promissory Note (form of) dated October 17, 2018 (Incorporated by reference from Form 8-K filed with the SEC on October 18, 2018)*

 

31.1		Certification of principal executive officer required by Rule 13a 14(1) or Rule 15d 14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2		Certification of principal financial officer required by Rule 13a 14(1) or Rule 15d 14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1		Certification of principal executive officer and principal financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and Section 1350 of 18 U.S.C. 63.

 

101.INS		XBRL Instance Document
101.SCH		XBRL Taxonomy Extension Schema
101.CAL		XBRL Taxonomy Extension Calculation Linkbase
101.DEF		XBRL Taxonomy Extension Definitions Linkbase
101.LAB		XBRL Taxonomy Extension Label Linkbase

 

* Incorporated by reference from our previous filings with the SEC

 

 

 

 

 

 

28

 

SIGNATURES

 

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

 

 

 

	Torchlight Energy Resources, Inc.
Date: August 9, 2019	/s/ John A. Brda
	By: John A. Brda
	Chief Executive Officer

 

 

 

 

Date: August 9, 2019	/s/ Roger Wurtele
	By: Roger Wurtele
	Chief Financial Officer and Principal Accounting Officer

 

 

 

 

 

 

 

 

 

 

 

 

 

29