The accompanying notes are an integral part of these financial statements.
5
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1.
NATURE OF BUSINESS
Torchlight Energy, Inc. (“TEI”) was formed in the state of Nevada on June 25, 2010. TEI’s operations commenced with initial funding on July 8, 2010. TEI is an Exploration Stage energy company formed as a corporation to engage in the acquisition, exploration, exploitation and/or development of oil and natural gas properties in the United States.
On November 23, 2010 Torchlight Energy Resources, Inc. (“we,” “us” and the “Company”), formerly, Pole Perfect Studios, Inc. (“Pole Perfect”) entered into a Share Exchange Agreement (the “Exchange Agreement”) with its major stockholders, TEI, and the persons owning 100% of the outstanding capital stock of TEI (the “TEI Stockholders”). At closing, the TEI Stockholders transferred 9,444,501 shares of TEI common stock, representing 100% of the common stock of TEI, to the Company in exchange for an aggregate of 2,361,125 shares (pre stock split) of newly issued common stock of the Company. Also at closing of the Exchange Agreement, the Pole Perfect shareholders transferred to the Company an aggregate of 3,600,000 shares of common stock of the Company for cancellation in exchange for an aggregate consideration of $270,000. This transaction was recorded as a reverse acquisition for accounting purposes where TEI is the accounting acquirer. The assets and liabilities of Pole Perfect were recorded at a fair value of $0. The Company recorded $447,084 of goodwill which represents the estimated fair value of the consideration exchanged. In addition, at closing (i) TEI became the Company’s wholly-owned subsidiary, (ii) the Company abandoned all of its previous business plans within the health and fitness industries, including opening and operating dance studios, and (iii) the business of TEI became the Company’s sole business. Descriptions of its business hereinafter refer to the business of TEI.
On December 10, 2010, the Company effected a 4-for-1 forward split of its shares of common stock outstanding. All owners of record at the close of business on December 10, 2010 (record date) received three additional shares for every one share they owned.
Effective February 8, 2011 the Company changed its name from “Pole Perfect Studios, Inc.” to “Torchlight Energy Resources, Inc.” In connection with the name change, the Company’s ticker symbol changed from “PPFT” to “TRCH.”
In an Exploration Stage company, management devotes most of its activities to establishing a new business, including raising capital to acquire interests in oil and gas properties. Planned principle activities have not yet produced any significant revenues, and the Company has incurred operating losses as is normal in Exploration Stage companies.
The Company is engaged in the acquisition, exploration, development and producing of oil and gas properties. The Company is interested in programs that have a short window of payback, a high internal rate of return and proven and bookable reserves. The Company’s success will depend in large part on its ability to obtain and develop oil and gas interests within the United States.
2.
GOING CONCERN
These consolidated financial statements have been prepared in accordance with generally accepted accounting principles applicable to a going concern, which assumes that the Company will be able to meet its obligations and continue its operations for its next fiscal year.
At March 31, 2012, the Company had not yet achieved profitable operations, has accumulated losses of $2,898,655 since its inception and expects to incur further losses in the development of its business, which casts substantial doubt about the Company’s 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. The accompanying consolidated financial statements do not include any adjustments that might 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.
6
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 subsidiary, Torchlight Energy, Inc. All significant intercompany balances and transactions have been eliminated.
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 – The Company’s cash is placed with a highly rated financial institution, and the Company conducts ongoing evaluations of the credit worthiness of the financial institutions with which it does business. At times during the three months ended March 31, 2012, and the twelve months ended December 31, 2011, cash balances were in excess of amounts guaranteed by the Federal Deposit Insurance Corporation.
Fair value of financial instruments – Financial instruments consist of cash, accounts receivable, accounts payable and convertible and non-convertible promissory notes. The estimated fair values of cash, accounts receivable and accounts payable approximate the carrying amount due to the relatively short maturity of these instruments. The carrying amounts of the convertible and non-convertible promissory notes approximates their fair value giving affect for the term of the note and the effective interest rates. See note 7.
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 March 31, 2012 and December 31, 2011 no valuation allowance was considered necessary.
Investment in 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.
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. During the three months ended March 31, 2012 and the twelve months ended December 31, 2011, the investment in oil and gas properties included only unevaluated oil and gas properties and other costs excluded from amortization; therefore, no depreciation, depletion or amortization has been recognized.
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 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 ceiling test calculation uses a commodity price assumption which is based on the un-weighed 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 Company did not recognize impairment on its oil and gas properties during the three months ended March 31, 2012 nor the twelve months ended December 31, 2011. Due to the volatility of commodity prices, should oil and natural gas prices decline in the future, it is possible that a write-down could occur.
7
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. As of March 31, 2012 and December 31, 2011 and December 31, 2010, the Company did not have any proved oil or gas reserves.
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 evaluation of the same reserves as well as cost estimates related to future development costs of proved oil and gas reserves could result in significant revisions due to changes in regulatory requirements, technological advances and other factors which are difficult to predict.
Gains and losses on the sale of oil and gas properties are generally reflected in income. 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. During the three months ended March 31, 2012 and the twelve months ended December 31, 2011, there were no gains or losses recognized from the sale of oil and gas properties.
Goodwill - Goodwill represents the excess of the purchase price over the fair value of the net identifiable tangible and intangible assets of acquired companies. Goodwill is not amortized; instead, it is tested for impairment annually or more frequently if indicators of impairment exist.
Goodwill was $447,084 as of March 31, 2012 and December 31, 2011 and was acquired on November 23, 2010 in connection with the Company’s reverse acquisition (Note 1).
Asset retirement obligations – Accounting principles require that the fair value of a liability for an asset’s retirement obligation (“ARO”) be recorded in the period in which it is incurred if a reasonable estimate of fair value can be made, and that the corresponding cost be 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 cost incurred is recorded as a reduction to 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.
Asset retirement obligation activity is disclosed in Note 10.
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. Compensation cost for liability awards is based on the fair value of the vested award at the end of each period.
Revenue recognition – The Company recognizes oil and gas revenues when production is sold at a fixed or determinable price, persuasive evidence of an arrangement exists, delivery has occurred and title has transferred, and collectability is reasonably assured.
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.
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.
8
Recent accounting pronouncements – In January 2010, the Financial Accounting Standards Board (“FASB”) issued its updates to oil and gas accounting rules to align the oil and gas reserve estimation and disclosure requirements of Extractive Industries — Oil and Gas with the requirements in the SEC’s final rule, Modernization of the Oil and Gas Reporting Requirements, which was issued on December 31, 2008. It is intended to provide investors with a more meaningful and comprehensive understanding of oil and gas reserves to help investors evaluate their investments in oil and gas companies. The amendments are also designed to modernize the oil and gas disclosure requirements to align them with current practices and changes in technology. Revised requirements in this guidance include, but are not limited to:
·
Oil and gas reserves must be reported using the average price over the prior 12-month period, determined as an un-weighted arithmetic average of the first-day-of-the-month price for each month within such period, rather than year-end prices;
·
Companies are allowed to report, on an optional basis, probable and possible reserve;
·
Non-traditional reserves, such as oil and gas extracted from coal and shales, are included in the definitions of “oil and gas producing activities”;
·
Companies are permitted to use new technologies to determine proved reserves, as long as those technologies have been demonstrated empirically to lead to reliable conclusions with respect to reserve volumes;
·
Companies are required to disclose, in narrative form, additional details on their proved undeveloped reserves (PUDs), including the total quantity of PUDs at year end, any material changes to PUDs to developed oil and gas reserves and an explanation of the reasons why material concentrations of PUDs in individual fields or countries have remained undeveloped for five years or more after disclosure as PUDs;
·
Companies are required to report the qualifications and measures taken to assure the independence and objectivity of any business entity or employee primarily responsible for preparing or auditing the reserves estimates.
The Company adopted this guidance effective June 25, 2010 (inception). As of March 31, 2012 and December 31, 2011, the Company did not have any proved reserves.
In December 2010, the FASB issued amended accounting guidance relating to goodwill impairment test for reporting units with zero or negative carrying amounts. For those reporting units, an entity is required to perform “Step two” of the goodwill impairment test if it is more likely than not that a goodwill impairment exists. In determining whether it is more likely than not, that a goodwill impairment exists, an entity should consider whether there are any adverse qualitative factors indicating that an impairment may exist. The adoption of this guidance did not have a material effect on the Company’s consolidated financial statements.
In September 2011, the FASB issued guidance that amends and simplifies the rules related to testing goodwill for impairment. The revised guidance allows an entity to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination whether it is more likely than not that the fair value of reporting unit is less than its carrying amount. The results of this assessment will determine whether it is necessary to perform the currently required two-step impairment test. Under this update, an entity also has the option to bypass the qualitative assessment for any reporting unit in any period and proceed directly to performing the two-step goodwill impairment test. The adoption of this guidance did not have a material effect on the Company’s consolidated financial statements.
The two preceding amendments listed above are effective for fiscal years, and interim periods within those years, beginning after December 15, 2011, with early adoption permitted.
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 all subsequent events through May 15, 2012, the date of issuance of the financial statements.
Reclassifications – Certain amounts from the prior year have been reclassified to conform to the current year presentation. The reclassifications had no impact on total assets or the net loss.
4.
RELATED PARTY TRANSACTIONS
On January 24, 2012, the Company entered into an employment agreement with a related party. In exchange for $240,000 per year and other mutual covenants and agreements, the related party agrees to supply management and executive services. The Company recognized payments due the related party of $60,000 for the period from January 1, 2012 through March 31, 2012.
In February and March of 2012, the Company issued four non-interest bearing promissory notes totaling $64,000 to an individual and officer of the Company for cash received. The notes are due upon demand.
9
In February 2012 the Company issued 25,000 shares of common stock each to Wayne Turner and Ken Danneberg in consideration for serving on the Board of Directors in 2011. The Company recognized $56,000 in expenses related to the issuance of these shares.
In exchange for management services provided to the Company, Opal Marketing & Consulting, Inc. (“Opal”) charges the Company a management fee of $240,000 per year. The Company’s Chief Executive Officer is the President of Opal. The Company recognized payments due Opal of $60,000 for the three months ended March 31, 2012, and $240,000 for the twelve months ended December 31, 2011. The Company recognized payments due Opal of $420,000 for the period from June 25, 2010 (inception) through March 31, 2012.
On December 1, 2010, the Company entered into a Business Consultant Agreement with a former Director and Chief Executive Officer. The agreement provided that in consideration for consulting services, the Company will pay $4,000 per month for the term of the agreement (three months) and issue 50,000 restricted shares of common stock. On December 17, 2010, the Company issued the 50,000 shares of common stock which were valued at $150,000 on that date. For the year ended December 31, 2010, the Company paid the former Director and CEO a total of $4,000 in cash under the agreement. For the year ended December 31, 2011 a total of $8,000 in cash was paid under the agreement. This agreement was terminated in early 2011.
5.
COMMITMENTS AND CONTINGENCIES
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 March 31, 2012 and December 31, 2011, 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.
6.
STOCKHOLDERS’ EQUITY
The Board of Directors has the authority to issue up to 5,000,000 shares of preferred stock in one or more series, to fix the number of shares constituting any such series, and to fix the rights and preferences of the shares constituting any series, without any further vote or action by the stockholders. There are no issued and outstanding shares of preferred stock; there are no agreements or understandings for the issuance of preferred stock, and the Board of Directors has no present intention to issue preferred stock.
Through subscription agreements, the Company received $2,699,242 for the issuance of 771,212 Units during the period of January 1, 2011 through December 31, 2011. Each Unit consisted of two restricted shares of common stock and one three year warrant to purchase a share of restricted common stock at the price of $5.00. The Company also issued common shares as compensation for services during this time.
On October 7, 2011, the Company placed 1,672,375 shares of common stock into escrow in connection with a letter of intent with Wexco Resources to acquire leases in Wilson County, Texas and two farm-in agreements with Hockley Energy. Under the terms, and subject to closing, Hockley Energy was to fund a deposit of $1,500,000 by November 6, 2011. To date no funds have been deposited, and the Company has filed a lawsuit against Hockley Energy. Subsequent to December 31, 2011, the Company requested the return of the shares held in escrow from the escrow agent. At this time we are awaiting receipt of the shares.
In February, 2012, the Company issued 25,000 shares of common stock each to Wayne Turner and Ken Danneberg as consideration for serving on the board of Directors in 2011.
10
A summary of warrant activity for the period from June 25, 2010 (inception) to March 31, 2012 is presented below:
| | | | | | | | | |
| | | | | | | Weighted | | Weighted |
| | | | | | | Average | | Average |
| | | | | Number of | | Exercise | | Exercise |
| | | | | Warrants | | Price | | Price |
Outstanding June 25, 2010 | | - | | - | | - |
| Issued | | 12/28/2010 | | 225,000 | | $2.50 | | 3.00 years |
| Issued | | 02/18/2011 | | 30,000 | | $5.00 | | 2.25 years |
| Issued | | 03/08/2011 | | 30,000 | | $5.00 | | 2.25 years |
| Issued | | 03/08/2011 | | 30,000 | | $5.00 | | 2.25 years |
| Issued | | 03/14/2011 | | 25,000 | | $5.00 | | 2.25 years |
| Issued | | 03/15/2011 | | 154,857 | | $5.00 | | 2.25 years |
| Issued | | 04/13/2011 | | 142,850 | | $5.00 | | 2.50 years |
| Issued | | 05/03/2011 | | 40,000 | | $5.00 | | 2.50 years |
| Issued | | 05/09/2011 | | 22,500 | | $5.00 | | 2.50 years |
| Issued | | 06/02/2011 | | 10,000 | | $5.00 | | 2.50 years |
| Issued | | 06/03/2011 | | 9,000 | | $5.00 | | 2.50 years |
| Issued | | 06/07/2011 | | 14,500 | | $5.00 | | 2.50 years |
| Issued | | 06/20/2011 | | 7,142 | | $5.00 | | 2.50 years |
| Issued | | 06/21/2011 | | 7,143 | | $5.00 | | 2.50 years |
| Issued | | 06/22/2011 | | 11,143 | | $5.00 | | 2.50 years |
| Issued | | 06/28/2011 | | 34,500 | | $5.00 | | 2.50 years |
| Issued | | 08/12/2011 | | 113,640 | | $5.00 | | 2.75 years |
| Issued | | 09/23/2011 | | 25,000 | | $5.00 | | 2.75 years |
| Issued | | 10/25/2011 | | 7,143 | | $5.00 | | 3.00 years |
| Issued | | 11/05/2011 | | 7,144 | | $5.00 | | 3.00 years |
| Issued | | 11/14/2011 | | 49,650 | | $5.00 | | 3.00 years |
| Issued | | 12/21/2011 | | 385,000 | | $5.00 | | 3.00 years |
| Issued | | 01/01/2012 | | 247,500 | | $5.00 | | 3.00 years |
Outstanding March 31, 2012 | | 1,628,712 | | | | |
At December 31, 2011, the Company had reserved 1,381,212 shares for future exercise of warrants. At March 31, 2012 the Company had reserved 1,628,712 shares for future exercise of warrants.
Warrants issued in relation to the promissory notes issued (see note 9) and the equity Units above were valued using the Black Scholes Option Pricing Model. The assumptions used in calculating the fair value of the warrants issued are as follows:
| |
Risk-free interest rate | 0.68% - 0.64% |
Expected volatility of common stock | 60.00% - 40.00% |
Dividend yield | 0.00% - 0.00% |
Discount due to lack of marketability | 30.00% - 30.00% |
Expected life of warrant | 4 years - 2 years |
7.
FAIR VALUE MEASUREMENTS
Assets and liabilities that require measurement to fair value on a recurring basis are categorized 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. At March 31, 2012 and December 31, 2011 there were no financial assets or liabilities measured on a recurring or a nonrecurring basis.
11
8.
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 carryforwards. 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. The Company’s tax returns remain subject to Federal and State tax examinations for all tax years since inception as none of the statutes have expired. 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 during the three months ended March 31, 2012, the three months ended March 31, 2011 and the period from June 25, 2010 (inception) to March 31, 2012.
The following is a reconciliation between the federal income tax benefit computed at the statutory federal income tax rate of 34% and actual income tax provision for three months ended March 31, 2012, the year ended December 31, 2011 and, the period from June 25, 2010 (inception) to March 31, 2012 :
| | | | | | |
| | 3 Months ended | | Year ended | | June 25, 2010 (inception) through |
| | March 31, 2012 | | Dec. 31, 2011 | | March 31, 2012 |
Federal income tax benefit at statutory rate | $ | (96,955) | $ | (669,185) | $ | (985,543) |
Permanent Differences | | 9,281 | | 22,947 | | 32,228 |
Change in valuation allowance | | 87,674 | | 646,238 | | 953,315 |
Provision for income taxes | $ | - | $ | - | $ | - |
The tax effects of temporary differences that gave rise to significant portions of deferred tax assets and liabilities are as follows:
| | | | | | |
| | March 31, 2012 | | Dec. 31, 2011 | | |
Deferred tax assets: | | | | | | |
Net operating loss carryforward | $ | 1,316,841 | $ | 1,241,407 | | |
Accruals | | 102,000 | | 61,200 | | |
Deferred tax liabilities: | | | | | | |
Intangible drilling and other costs for oil and gas properties | | (465,526) | | (436,966) | | |
Net deferred tax assets and liabilities | | 953,315 | | 865,641 | | |
Less valuation allowance | | (953,315) | | (865,641) | | |
Total deferred tax assets and liabilities | $ | - | $ | - | | |
The Company had a net deferred tax asset related to federal net operating loss carryforwards of $3,873,061 and $3,651,197 at March 31, 2012 and December 31, 2011, respectively. The federal net operating loss carryforward will begin to expire in 2030. 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.
12
9.
PROMISSORY NOTES
The Company entered into an extension agreement, effective January 1, 2012, with stockholders Sawtooth Properties, LLLP, Black Hills Properties, LLLP and Pine River Ranch, LLC (collectively the “Note Holders”). Previously on June 24, 2011, the Company issued a total of three 10% Convertible Promissory Notes with an aggregate principal amount of $262,500 to the Note Holders who paid $262,500 in aggregate consideration for the notes. Each of the notes bears interest at the rate of 10% per annum and was due on December 31, 2011. Under the terms of the extension agreement, the Note Holders agreed to extend the maturity date of each of the notes to December 31, 2012 in consideration of the following: (i) the pro-rata issuance of a total of 75,000 shares of common stock to the Note Holders, (ii) the continued right to convert any of the outstanding principal and interest of the notes into Units of the Company’s securities at the conversion price of $3.50 per Unit, which Units each consist of two shares of common stock and one three-year warrant to purchase a share of common stock at the price of $5.00 per share, and (iii) upon such conversion set forth in “(ii)” above, the right to receive two additional three-year warrants to purchase a share of common stock at the price of $5.00 per share for each Unit into which outstanding principal and interest is converted. The convertible notes were recorded net of discount that includes the relative fair value of the warrants amounting to $42,900. The discount is accreted over the life of the debt using the effective interest method. Accretion expense was $1,148 for the three months ended March 31, 2012. The initial value of the warrants was calculated using the Black Scholes Option Pricing Model.
On December 21, 2011, the Company issued a 10% promissory note and a warrant to purchase shares of common stock to an accredited investor who paid $385,000 in aggregate consideration for the securities. The 10% promissory note bears interest at the rate of 10% per annum, has a principal amount of $385,000 and has a maturity date of September 21, 2012.The warrant is exercisable into 385,000 shares of common stock as of December 20, 2011 at a price of $1.75 per share and expires on December 21, 2015. The note was collateralized by 1,000,000 shares of pledged securities of a related party. The convertible note was recorded net of discount that includes the relative fair value of the warrants amounting to $61,600. The discount is accreted over the life of the debt using the effective interest method. Accretion expense was $20,384 for the three months ended March 31, 2012 and $2,240 for the 10 days ended December 31, 2011. The initial value of the warrants was calculated using the Black Scholes Option Pricing Model.
On March 26, 2012, the Company issued two Series A 10% Convertible Promissory Notes to Sawtooth Properties, LLLP and Pine River Ranch, LLC for aggregate consideration of $150,000. The notes are due on September 26, 2012 and bear interest at the rate of 10% per annum. Each of the notes is convertible on and after the earlier to occur of (i) August 26, 2012, (ii) an un-cured event of default and (iii) the Company’s election to pre-pay the note. The notes are convertible into shares of common stock at the conversion price of $1.75 per share. The notes are collateralized with (i) a first lien on the Company’s interest in the Johnson #4 well, (ii) a second lien on the Company’s interest in the John Coulter #1-R well, and (iii) shares of stock pledged by the Company’s President. In connection with the issuance of the notes, the Company also issued the holders three-year warrants to purchase an aggregate of 150,000 shares of common stock at the exercise price of $1.75 per share, which warrants are not exercisable until August 26, 2012. Also in connection with the issuance of the notes, the Company entered into allonges that amended the promissory notes it had previously issued Sawtooth Properties, LLLP, Pine River Ranch, LLC and Black Hills Properties, LLLP on June 24, 2011, which notes has subsequently been amended pursuant to an extension agreement effective January 1, 2012. The allonges give the holders collateral in the Company’s interest in the Johnson #4 well and the John Coulter #1-R well. The allonges also provide that each holder will not have the right to convert outstanding principal and interest of the note or the right to receive additional warrants to purchase shares of common stock until the earlier to occur of (i) December 1, 2012, (ii) an un-cured event of default and (iii) the Company’s election to pre-pay the note.
In February and March of 2012, the Company issued four non-interest bearing promissory notes totaling $64,000 to an individual and officer of the Company for cash received. The notes are due upon demand.
10.
ASSET RETIREMENT OBLIGATIONS
The following is a reconciliation of the asset retirement obligation liability for the three months ended March 31, 2012 and the year ended December 31, 2011:
| | |
Asset retirement obligation – January 1, 2011 | $ | - |
Liabilities incurred | | 10,828 |
Accretion expense | | 541 |
Asset retirement obligation – December 31, 2011 | | 11,369 |
Accretion expense | | 28 |
Asset retirement obligation – March 31, 2012 | $ | 11,397 |
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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The information set forth and discussed in this Management’s Discussion and Analysis and Results of Operations is derived from our historical financial statements and the related notes thereto which are included in this Form 10-Q. The following information and discussion should be read in conjunction with such financial statements and notes. Additionally, this Management’s Discussion and Analysis and Plan of Operations contain certain statements that are not strictly historical and are “forward-looking” statements within the meaning of the Private Securities Litigation Reform Act of 1995 and involve a high degree of risk and uncertainty. Actual results may differ materially from those projected in the forward-looking statements due to other risks and uncertainties that exist in our operations, development efforts and business environment, and due to other risks and uncertainties relating to our ability to obtain additional capital in the future to fund our planned expansion, the demand for oil and natural gas, and other general economic factors. All forward-looking statements included herein are based on information available to us as of the date hereof, and we assume no obligation to update any such forward-looking statements.
Basis of Presentation of Financial Information
On November 23, 2010, the Share Exchange Agreement (the “Exchange Agreement” or “Transaction”) between Pole Perfect Studios, Inc. (“Pole Perfect”) and Torchlight Energy, Inc. (“TEI”) was entered into and closed, through which the former shareholders of TEI became shareholders of Pole Perfect. At closing, Pole Perfect abandoned its previous business. Consequently, as a result of the Transaction, the business of TEI became our sole business. Because TEI became the successor business to Pole Perfect and because the operations and assets of TEI represent our entire business and operations from the closing date of the Exchange Agreement, the Management’s Discussion and Analysis and audited and unaudited financial statements are based on the consolidated financial results of Pole Perfect and its wholly owned subsidiary TEI for the relevant periods. Effective February 8, 2011, we changed our name from “Pole Perfect Studios, Inc.” to “Torchlight Energy Resources, Inc.
Summary of Key Results
Overview
Our sole business is that of Torchlight Energy, Inc., an exploration stage company formed as a corporation in the state of Nevada on June 25, 2010. We are engaged in the acquisition, exploration, exploitation and/or development of oil and natural gas properties in the United States.
Results of Operations
The following discussion of our financial condition and results of operations should be read in conjunction with our unaudited financial statements, included herewith. 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.
We had no active operations prior to the inception of TEI on June 25, 2010. Due to this fact, comparisons to previous years are not necessarily indicative of actual operating results.
Recent Activity
On January 10, 2012, we entered into a farm-in agreement, titled the “Coulter Limited Partnership Agreement” (the “Coulter Agreement”), with La Sal Energy, LLC (“La Sal”). La Sal owns a 100% working interest and a 75% net revenue interest in certain oil, gas and mineral leases in Waller County, Texas, upon which the well known as “John Coulter #1-R” is located. Pursuant to the Coulter Agreement, we acquired a 34% working interest and a 34% net revenue interest in La Sal’s interest in the John Coulter #1-R for the purchase price of $350,000. It is anticipated this amount will fund the fracing of the well. Upon production, the net revenue split will be 80% to us and 20% to La Sal until net revenue is an accumulated $437,500. During this period, expenses above the $350,000 initially paid in will be split according to actual percentage interests in the well. After net revenue is an accumulated $437,500, net revenue will be split according to the actual percentage interests in the well. The Coulter Agreement also provides us with multiple options under which we can acquire additional interests in La Sal’s interest in the well. The well was stimulated on February 22, 2012, and we are awaiting completion.
On February 1, 2012, we attended a settlement meeting with Mercer Well Services and Bayshore Operating Co. in San Antonio to discuss damages to the Johnson #1 well caused by Mercer. No resolution was made at the meeting but Mercer did confirm that they would respond back after they reviewed the information supplied by Bayshore. A meeting is now tentatively scheduled for May 21, 2012, at which we hope to resolve this matter. The long lead time was due to an accident in which Mercer was involved in another state.
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On February 13, 2012, the Johnson #4 well was treated with acid to stimulate its production. The well had been testing oil and appeared to be tight. The acid job went well and we still are testing its capability. A small amount of oil from the Johnson #4 was sold in January and February at a price of $97.50 per barrel. Production in March averaged 55 BOPD for the month, producing in excess of 1,600 barrels.
Historical Results for the Three Months Ended March 31, 2012, Three Months Ended March 31, 2011 and the Period from June 25, 2010 (Inception) to March 31, 2012.
Revenues and Cost of Revenues
We had revenue of $24,216, $0 and $48,368 consisting entirely of test oil and gas sales during the three months ended March 31, 2012, the three months ended March 31, 2011 and June 25, 2010 (Inception) to March 31, 2012, respectively. The increase in revenue for the three months ended March 31, 2012 compared to the three months ended March 31, 2011 is due to the fact that we did not have any production prior to the three months ended June 30, 2011. We recognized cost of revenue of $16,523, $0 and $41,796 during the three months ended March 31, 2012, the three months ended March 31, 2011 and June 25, 2010 (Inception) to March 31, 2012, respectively.
General and Administrative Expenses
Our total operating expenses for the three months ended March 31, 2012, three months ended March 31, 2011, and the period from June 25, 2010 (Inception) to March 31, 2012 were $231,221, $550,429 and $2,749,182 respectively and consisted entirely of general and administrative expenses. Our general and administrative expenses consisted of accounting and administrative costs, professional consulting fees and other general corporate expenses. The decrease in operating expenses for the three months ended March 31, 2012 compared to the three months ended March 31, 2011 is directly related to higher professional and consulting costs incurred during the prior period.
Liquidity and Capital Resources
We have minimal assets and have achieved nominal operating revenues since our inception. We have depended on loans and sales of equity securities to conduct operations. As of March 31, 2012, we had total current assets of $144,039, consisting of $45,050 in cash, $24,967 in receivables, $50,794 in debt issue costs and $23,228 in prepaid costs. As of December 31, 2011, we had total current assets of $551,822, consisting of $518,281 in cash, $17,274 in receivables and $16,267 in prepaid costs. As of March 31, 2012, we had $3,706,286 in investment in oil and gas properties and $447,084 in goodwill. For the year ended December 31, 2011, we had $3,182,128 in investment in oil and gas properties and $447,084 in goodwill.
During the three months ended March 31, 2012, we had $337,725 in net cash provided by financing activities. It was attributable to $67,725 of private placement, $56,000 of shares issued to management and $214,000 of issuances of convertible notes.
Commitments and Contingencies
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 its operations in other ways that cannot be predicted at this time. As of March 31, 2012 and December 31, 2011, 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.
In July 2010, TEI entered into an Agreement to participate in an Oil and Gas Development Joint Venture (the “Participation Agreement”) with Bayshore Operating Corporation, LLC (“Bayshore”). Bayshore is currently the holder of an oil, gas and mineral lease covering approximately 1,045 acres in Wilson County, Texas, known as the Marcelina Creek Field Development. The Participation Agreement provides for the drilling of four (4) wells. Upon execution of the agreement, TEI paid Bayshore an initial deposit of $50,000, which amount was credited to the initial $50,000 payment due for the first well, in exchange for a 50% working interest in the first well. TEI will pay 100% of total drilling and completion costs.
The first well, the Johnson #1-BH, was a re-entry and drilled a lateral section of the Buda Formation of approximately 1840 feet in August 2010. After mutual agreement as to the location, the second well was drilled beginning July 2011. For the second well, TEI paid Bayshore $50,000 at rig move-in and will pay $200,000 when the well is completed or plugged and abandoned, whichever comes first. Further, TEI will pay 100% of the total drilling and completion costs for a 75% working interest.
For the third and fourth wells, TEI will pay Bayshore $50,000 at rig move-in and $150,000 when the well is completed or plugged and abandoned, whichever comes first. Further, TEI will pay 100% of the total drilling costs and 75% of the completion costs for a 75% working interest with Bayshore to pay 25% of the completion costs.
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On December 31, 2011 the company executed an agreement with Bayshore for an extension of its drilling obligation deadline from January 6, 2011 to April 15, 2011. As a condition for the extension the company paid to Bayshore $50,000, on January 6, 2011 and issued 25,000 shares of the company’s stock in January 2011. Further a $25,000 cash payment was made concurrent with the approval of the Authority for Expenditure (AFE) for the Johnson #4 well. As additional consideration Bayshore is no longer obligated to pay its proportionate share of completion costs on the second vertical well.
The Johnson #1-BH encountered good shows and a completion was attempted. The well however produced large volumes of water, some introduced by Bayshore during drilling and some from another source, either a deeper formation or from a nearby well. In July 2011 a workover crew was brought in to service the well, replace a broken rod and re-work the downhole pump. On July 27, 2011 the crew dropped two joints of pipe in the hole and on July 28 another six joints. The well was damaged sufficiently to be shut-in. Discussions to resolve this matter with the service company, Mercer Well Services, are ongoing (see “Recent Activity” above).
The Johnson #4, the first vertical well, began drilling operations on July 2011. The well encountered several pay zones and an attempt to complete in the Buda Formation was made. The well has experienced several mechanical problems which had delayed its completion. Following correcting the mechanical problems the well acted as if the Buda was tight and a subsequent acid job was done in February 2012 to stimulate the well (see “Recent Activity” above).
In late August 2011, Torchlight entered into discussions with Hockley Energy on a farm-in to TEI’s position in Marcelina Creek and nearby acreage in the Stockdale, Texas area. After numerous meetings a Letter of Intent was executed in October 2011 which included the terms of Hockley’s farm-in to TEI’s position. On November 4, 2011, TEI and Hockley Energy executed two farm-in agreements, one for Marcelina Creek and one for the East Stockdale acreage. Under the terms, Hockley was to fund a deposit of $1.5 million by November 6, 2011. To date no funds have been deposited, and we have filed a lawsuit against Hockley Energy alleging breach of contract, fraudulent inducement and promissory estoppel.
On September 27, 2011, we entered into an agreement with Wexco to acquire leases in Wilson County, Texas. Under the terms of the agreement, we provided Wexco’s attorney to hold in escrow 1,672,375 shares of our common stock to secure the option to acquire the leases. Our financial partner, Hockley Oil and Gas, failed to fund and the shares have been requested to be returned to us. At this time we are awaiting receipt of the shares.
In November 2011, we entered into discussions and an evaluation of a possible farm-in to La Sal Oil & Gas on a prospect in Waller County, Texas. A subsequent farm-in agreement was reached and executed in January 2012 (see “Recent Activity” above).
Going Concern
The accompanying unaudited consolidated financial statements have been prepared in accordance with generally accepted accounting principles applicable to a going concern, which assumes that we will be able to meet our obligations and continue our operations for our next fiscal year.
At March 31, 2012, we had not yet achieved profitable operations, has accumulated losses of $2,898,655 since its inception and expects to incur further losses in the development of its business, which casts substantial doubt about our ability to generate future profitable operations and/or to obtain the necessary financing to meet our obligations and repay our liabilities arising from normal business operations when they come due. Management’s plan to address our 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 we will be able to obtain the necessary funding to allow us to remain a going concern through the methods discussed above, there can be no assurances that such methods will prove successful. The accompanying consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Not Applicable.
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ITEM 4. CONTROLS AND PROCEDURES
Under the supervision and with the participation of our management, including our principal executive officer and 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 March 31, 2012. Based on this evaluation, our principal executive officer and our principal financial officer concluded that, as of the end of the period covered by this report, our disclosure controls and procedures were effective and adequately designed 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 principal executive officer and principal financial officer, in a manner that allowed for timely decisions regarding disclosure.
Our principal executive officer and principal financial officer have also indicated that, upon evaluation, there were no changes in our internal control over financial reporting or other factors during the period covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
PART II OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
On February 16, 2012, we filed a lawsuit against Hockley Energy, Inc. and Frank O. Snortheim in the District Court of Harris County, Texas. The lawsuit is in connection with farmout agreements we entered into with Hockley Energy in November 2011 for the Marcelina Creek prospect and the East Stockdale prospect. We allege that Hockley Energy did not perform its obligations under the agreements, which obligations included providing the agreed upon funding, and we seek damages against both Hockley Energy and Mr. Snortheim (who is a shareholder of Hockley Energy) for breach of contract, fraudulent inducement and promissory estoppel. The defendants have answered our original petition with a general denial. We have also had discussions with the defendants regarding resolving this matter out of court, but we have not reached an agreement to date.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
We entered into an extension agreement, effective January 1, 2012, with Sawtooth Properties, LLLP, Black Hills Properties, LLLP and Pine River Ranch, LLC (collectively the “Note Holders”). Previously on June 24, 2011, we issued a total of three 10% Convertible Promissory Notes with an aggregate principal amount of $262,500 to the Note Holders who paid $262,500 in aggregate consideration for the notes. Each of the notes bears interest at the rate of 10% per annum and was due on December 31, 2011. Under the terms of the extension agreement, the Note Holders agreed to extend the maturity date of each of the notes to December 31, 2012 in consideration of the following: (i) the pro-rata issuance of a total of 75,000 restricted shares of common stock to the Note Holders, (ii) the continued right to convert any of the outstanding principal and interest of the notes into Units of our securities at the conversion price of $3.50 per Unit, which Units each consist of two shares of common stock and one three-year warrant to purchase a share of common stock at the price of $5.00 per share, and (iii) for each Unit the Note Holder receives upon such conversion set forth in “(ii)” above, the Note Holder will receive two additional three-year warrants to purchase a share of common stock at the exercise price of $1.75 per share and one additional three-year warrant to purchase a share of common stock at the exercise price of $5.00 per share. All other terms and conditions of the notes remain unchanged. The securities (including the 75,000 shares of stock and the adjustment to the conversion terms of the notes) were sold under the exemption from registration provided by Section 4(2) of the Securities Act of 1933 and the rules and regulations promulgated thereunder. The sale of securities did not involve a “public offering” based upon the following factors: (i) the sale of the securities was an isolated private transaction; (ii) a limited number of securities were sold to a limited number of offerees; (iii) there was no public solicitation; (iv) the offerees were “accredited investors”; (v) the investment intent of the offerees; and (vi) the restriction on transferability of the securities sold.
In February 2012, we issued an aggregate of 50,000 restricted shares of common stock two of our directors, Kenneth Danneberg and Wayne Turner, in consideration for serving on the Board of Directors during 2011. The securities were sold under the exemption from registration provided by Section 4(2) of the Securities Act of 1933 and the rules and regulations promulgated thereunder. The sale of securities did not involve a “public offering” based upon the following factors: (i) the sale of the securities was an isolated private transaction; (ii) a limited number of securities were sold to a limited number of offerees; (iii) there was no public solicitation; (iv) the offerees were “accredited investors”; (v) the investment intent of the offerees; and (vi) the restriction on transferability of the securities sold.
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In March 2012, we issued two Series A 10% Convertible Promissory Notes to Sawtooth Properties, LLLP and Pine River Ranch, LLC for aggregate consideration of $150,000. The notes are due on September 26, 2012 and bear interest at the rate of 10% per annum. Each of the notes is convertible on and after the earlier to occur of (i) August 26, 2012, (ii) an un-cured event of default or (iii) our election to pre-pay the note. The notes are convertible into shares of common stock at the conversion price of $1.75 per share. The notes are collateralized with (i) a first lien on our interest in the Johnson #4 well, (ii) a second lien on our interest in the two John Coulter wells, and (iii) shares of stock pledged by our President. In connection with the issuance of the notes, we also issued the holders three-year warrants to purchase an aggregate of 150,000 shares of common stock at the exercise price of $1.75 per share, which warrants are not exercisable until August 26, 2012. Also in connection with the issuance of the notes, we amended the promissory notes we had previously issued Sawtooth Properties, LLLP, Pine River Ranch, LLC and Black Hills Properties, LLLP on June 24, 2011, which notes had previously been amended pursuant to an extension agreement effective January 1, 2012. The new amendments to the notes give the holders collateral in our interest in the Johnson #4 well and the two John Coulter wells. The new amendments also provide that each holder will not have the right to convert outstanding principal and interest of the note or the right to receive additional warrants to purchase shares of common stock until the earlier to occur of (i) December 1, 2012, (ii) an un-cured event of default and (iii) our election to pre-pay the note. The securities (including the convertible notes, the warrants and the adjustment to the conversion terms of the notes) were sold under the exemption from registration provided by Section 4(2) of the Securities Act of 1933 and the rules and regulations promulgated thereunder. The sale of securities did not involve a “public offering” based upon the following factors: (i) the sale of the securities was an isolated private transaction; (ii) a limited number of securities were sold to a limited number of offerees; (iii) there was no public solicitation; (iv) the offerees were “accredited investors”; (v) the investment intent of the offerees; and (vi) the restriction on transferability of the securities sold.
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 S-1 filed with the SEC on May 2, 2008.) * |
| | |
3.2 | | Amended and Restated Bylaws (Incorporated by reference from Form 8-K filed with the SEC on January 12, 2011.) * |
| | |
10.1 | | Employment Agreement between Thomas Lapinski and Torchlight Energy, Inc. (Incorporated by reference from Form 8-K filed with the SEC on November 24, 2010.) * |
| | |
10.2 | | Agreement to Participate in Oil and Gas Development Joint Venture between Bayshore Operating Corporation, LLC and Torchlight Energy, Inc. (Incorporated by reference from Form 8-K filed with the SEC on November 24, 2010) * |
| | |
10.3 | | Employment Agreement between John Brda and Torchlight Energy Resources, Inc. (Incorporated by reference from Form 8-K filed with the SEC on January 27, 2012)* |
| | |
14.1 | | Code of Ethics (Incorporated by reference from Form S-1 filed with the SEC on May 2, 2008.) * |
| | |
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 pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and Section 1350 of 18 U.S.C. 63. |
| | |
32.2 | | Certification of 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 |
101.PRE | | XBRL Taxonomy Extension Presentation Linkbase |
* Incorporated by reference from our previous filings with the SEC
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| |
| Torchlight Energy Resources, Inc. |
| |
Date: May 15, 2012 | /s/ Thomas Lapinski |
| By: Thomas Lapinski |
| Chief Executive Officer and Principal Financial Officer |
| |
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