10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

x Quarterly report under Section 13 or 15(d) of the Securities Exchange Act of 1934

For the Quarter Ended March 31, 2016

o Transition report under Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from _______ to _______.

Commission file number: 001-36247

TORCHLIGHT ENERGY RESOURCES, INC.

(Name of registrant in its charter)

Nevada	74-3237581
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

5700 West Plano Pkwy, Suite 3600

Plano, Texas 75093

(Address of Principal Executive Offices)

(214) 432-8002

(Registrant's Telephone Number, Including Area Code)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.:

Large accelerated filer	o	Accelerated filer	o
Non-accelerated filer	o	Smaller reporting company	x

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

As of May 11, 2016, there were 36,165,741 shares of the registrant’s common stock outstanding (the only class of voting common stock).  

1

FORM 10-Q

TABLE OF CONTENTS

Note About Forward-Looking Statements		3
PART I	FINANCIAL INFORMATION	4
Item 1.	Consolidated Financial Statements	4
	Consolidated Balance Sheets (Unaudited)	4
	Consolidated Statements of Operations (Unaudited)	5
	Consolidated Statements of Cash Flows (Unaudited)	6
	Notes to Consolidated Financial Statements (Unaudited)	7
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	15
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	20
Item 4.	Controls and Procedures	21
PART II	OTHER INFORMATION	21
Item 1.	Legal Proceedings	21
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	21
Item 3.	Defaults Upon Senior Securities	22
Item 6.	Exhibits	22
	Signatures	24

2

NOTE ABOUT FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These statements include, among other things, statements regarding plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements, which are other than statements of historical facts. Forward-looking statements may appear throughout this report, including without limitation, Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” Forward-looking statements generally can be identified by words such as “anticipates,” “believes,” “estimates,” “expects,” “intends,” “plans,” “predicts,” “projects,” “will be,” “will continue,” “will likely result,” and similar expressions. These forward-looking statements are based on current expectations and assumptions that are subject to risks and uncertainties, which could cause our actual results to differ materially from those reflected in the forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed in this report and in our Annual Report on Form 10-K for the year ended December 31, 2015, and in particular, the risks discussed in our Form 10-K under the caption “Risk Factors” in Item 1A therein, and those discussed in other documents we file with the Securities and Exchange Commission (“SEC”). Important factors that in our view could cause material adverse effects on our financial condition and results of operations include, but are not limited to, risks associated with the company's ability to obtain additional capital in the future to fund planned expansion, the demand for oil and natural gas, general economic factors, competition in the industry and other factors that may cause actual results to be materially different from those described herein as anticipated, believed, estimated or expected. We undertake no obligation to revise or publicly release the results of any revision to any forward-looking statements, except as required by law. Given these risks and uncertainties, readers are cautioned not to place undue reliance on such forward-looking statements.

As used herein, the “Company,” “we,” “Torchlight,” “our,” and similar terms include Torchlight Energy Resources, Inc. and its subsidiaries, unless the context indicates otherwise.

3

PART I   FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED CONDENSED BALANCE SHEETS
	March 31,			December 31,
	2016			2015
ASSETS
Current assets:
Cash	$	626,602		$	1,026,600
Accounts receivable		499,841			741,653
Production revenue receivable		203,967			199,317
Note receivable		-			613
Prepayments - development costs		88,614			-
Prepaid expenses		-			38,776
Total current assets		1,419,024			2,006,959
Investment in oil and gas properties, net		9,253,184			7,057,671
Office equipment		39,772			43,110
Debt issuance costs, net		6,851			8,224
Other assets		48,299			72,082
TOTAL ASSETS	$	10,767,130		$	9,188,046
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	2,458,483		$	1,114,409
Accrued liabilities		652,079			628,876
Related party payables		130,000			130,000
Note payable within one year - related party		128,125			205,000
Notes payable within one year		602,527			129,741
Due to working interest owners		108,451			103,364
Interest payable		283,493			173,710
Total current liabilities		4,363,158			2,485,100
Convertible promissory notes, (Series B) net of discount of $231,533 at March 31, 2016 and $277,911 at December 31, 2015		3,337,967			3,291,589
Asset retirement obligation		29,830			29,083
Commitments and contingencies		-			-
Stockholders’ equity:
Preferred stock, par value $.001, 10,000,000 shares authorized,
133,750 shares issued and outstanding		134			134
Common stock, par value $0.001 per share; 100,000,000 shares authorized;		35,219			33,168
35,216,205 issued and outstanding at March 31, 2016
33,166,344 issued and outstanding at December 31, 2015
Additional paid-in capital		62,832,108			61,921,450
Warrants outstanding		16,679,472			16,330,961
Accumulated deficit		(76,510,758	)		(74,903,439	)
Total stockholders' equity		3,036,175			3,382,274
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	10,767,130		$	9,188,046

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

4

TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
	THREE MONTHS			THREE MONTHS
	ENDED			ENDED
	March 31, 2016			March 31, 2015
Revenue
Oil and gas sales	$	194,235		$	534,562
SWD and royalties		78			56,696
Cost of revenue		(105,998	)		(230,897	)
Gross income		88,315			360,361
Operating expenses:
General and administrative expense		951,285			688,711
Depreciation, depletion and amortization		621,972			494,475
Total operating expenses		1,573,257			1,183,186
Other income (expense)
Interest income		-			-
Interest and accretion expense		(122,376	)		(1,391,442	)
Total other income (expense)		(122,376	)		(1,391,442	)
Net loss before taxes		(1,607,318	)		(2,214,267	)
Provision for income taxes		-			-
Net (loss)	$	(1,607,318	)	$	(2,214,267	)
Loss per share:
Basic and Diluted	$	(0.07	)	$	(0.12	)
Weighted average shares outstanding:
Basic and Diluted		23,113,892			18,378,669

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

5

TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENTS OF CASH FLOW
	Three			Three
	Months Ended			Months Ended
	March 31, 2016			March 31, 2015
Cash Flows From Operating Activities
Net (loss)	$	(1,607,318	)	$	(2,214,267	)
Adjustments to reconcile net loss to net cash from operations:
Stock based compensation		82,922			(97,000	)
Accretion of convertible note discounts		48,498			1,099,058
Depreciation, depletion and amortization		621,972			494,475
Change in:
Accounts receivable		241,812			(16,646	)
Note receivable		613			(160	)
Production revenue receivable		(4,650	)		(160,516	)
Prepayment of development costs		(88,614	)		7,457
Prepaid expenses		38,776			29,634
Other assets		23,784			131
Accounts payable and accrued liabilities		1,367,276			1,946,804
Due to working interest owners		5,087			(643	)
Asset retirement obligation		-			1,107
Interest payable		109,783			151,989
Capitalized interest		(41,912	)		(205,341	)
Net cash provided by (used) in operating activities		798,029			1,036,082
Cash Flows From Investing Activities
Investment in oil and gas properties		(1,481,507	)		(1,507,162	)
Proceeds from sale of Leases		-			270,000
Net cash used in investing activities		(1,481,507	)		(1,237,162	)
Cash Flows From Financing Activities
Proceeds from sale of common stock		-			-
Proceeds from sale of preferred stock		-			-
Payment of preferred stock dividends		(112,430	)		-
Proceeds from warrant exercise		-			-
Proceeds from promissory notes		505,652			33,381
Repayment of promissory notes		(109,742	)		-
Net cash provided by financing activities		283,480			33,381
Net increase (decrease) in cash		(399,998	)		(167,699	)
Cash - beginning of period		1,026,600			179,787
Cash - end of period	$	626,602		$	12,088
Supplemental disclosure of cash flow information:
Non cash transactions:
Common stock issued for services	$	53,173		$	(94,500	)
Common stock issued for lease interests	$	971,966		$	-
Warrants issued for services	$	2,000		$	4,000
Warrants issued in connection with promissory notes	$	27,750		$	-
Warrants issued in connection with lease interests	$	318,761		$	-
Reduction in accounts receivable for WI acquisition	$	-		$	101,058
Common stock issued in warrant exercises	$	-		$	-
Cash paid for interest	$	34,741		$	323,248

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

6

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

1. NATURE OF BUSINESS

Torchlight Energy Resources, Inc. 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.  In addition to TEI, we also operate our business through our wholly-owned subsidiaries Torchlight Energy Operating, LLC, a Texas limited liability company and Hudspeth Oil Corporation, a Texas corporation.

On December 10, 2010, we effected a 4-for-1 forward split of our 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.  All share amounts reflected throughout this report take into account the 4-for-1 forward split.

Effective February 8, 2011, we changed our name to “Torchlight Energy Resources, Inc.”  In connection with the name change, our ticker symbol changed from “PPFT” to “TRCH.”

The Company is engaged in the acquisition, exploration, development and production of oil and gas properties within the United States. The Company’s success will depend in large part on its ability to obtain and develop profitable oil and gas interests.

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, 2016, the Company had not yet achieved profitable operations. We had a net loss of approximately $1.6 million for the quarter ended March 31, 2016 and had accumulated losses of $76,510,758 since our inception to March 31, 2016, and expect to incur further losses in the development of our business.  Working Capital as of March 31, 2016 was negative $2,944,134. 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; (3) participating in joint venture transactions with third parties; or (4) sale of assets.  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.

Planned Divestiture of Hunton Project

Management has previously announced that they were seeking to divest certain of the Cimarron assets located in Logan and Kingfisher Counties, Oklahoma including lease rights and current production.  As of March 31, 2016 negotiations and documentation of the sale of the Company’s Cimarron assets in Oklahoma was nearing completion. The sale closed on April 29, 2016 with a sales price $750,000 and an effective date of May 1, 2016.

 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.

7

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

3. SIGNIFICANT ACCOUNTING POLICIES- continued

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, and Hudspeth Oil Corporation. 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 periodically reviews the credit worthiness of the financial institutions with which it does business. At times the Company’s cash balances are 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, notes payable to related party, and convertible promissory notes. The estimated fair values of cash, accounts receivable, accounts payable, and related party payables approximate the carrying amount due to the relatively short maturity of these instruments. The carrying amounts of the convertible 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.

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, 2016 and December 31, 2015 no valuation allowance was considered necessary.

As of December 31, 2015, the Company had a $419,839 account receivable from Husky Ventures for the estimated balance of the sale proceeds from the sale of the Chisholm Trail properties in fourth quarter, 2015. The Chisholm Trail properties were sold to Husky Ventures who then included them with the Husky interests in Chisholm Trail and then entered into a sale agreement with Gastar Exploration Inc. for the combined Torchlight and Husky interests. Receipt of the balance of the sale proceeds was subject to final determination of mineral lease classification and was to occur by February 28, 2016. The account receivable was not collected as of March 31, 2016.

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.

8

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 periods ended March 31, 2016 and March 31, 2015, the Company capitalized $41,912 and $205,341, 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 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 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 Company recognized impairment of $22,438,114 on its oil and gas properties during the three months ended June 30, 2015 and an additional impairment at December 31, 2015 of $3,236,009 for a total impairment adjustment for 2015 of $25,674,123. No impairment was recognized at March 31, 2016. 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. 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.

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.

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.

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.

9

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) 

3. SIGNIFICANT ACCOUNTING POLICIES - continued

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 Company has not included potentially dilutive securities in the calculation of loss per share for any periods presented as the effects 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.

Recent accounting pronouncements –

On August 27, 2014, the FASB issued ASU 2014-15, which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of the Company’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The ASU applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted.

In May 2014, the FASB issued ASU 2014-09 that introduces a new five-step revenue recognition model in which an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This ASU also requires disclosures sufficient to enable users to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including qualitative and quantitative disclosures about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. This standard is effective for fiscal years beginning after December 15, 2017, including interim periods within that reporting period. The Company is currently evaluating the new guidance to determine the impact it will have on its consolidated financial statements.

In April 2014, the FASB issued ASU 2014-08, which includes amendments that change the requirements for reporting discontinued operations and require additional disclosures about discontinued operations. Under the new guidance, only disposals representing a strategic shift in operations - that is, a major effect on the organization’s operations and financial results should be presented as discontinued operations. Additionally, the ASU requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income, and expenses of discontinued operations. The new standard is effective in the first quarter of 2015 for public organizations with calendar year ends. Early adoption would be permitted for any annual or interim period for which an entity’s financial statements have not yet been made available for issuance. The adoption of this guidance is not expected to have an impact on the Company’s 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 May 16, 2016, the date of issuance of the financial statements. Subsequent events are disclosed in Note 11.

4. RELATED PARTY PAYABLES

As of March 31, 2016, related party payables consisted of accrued and unpaid compensation to two of our executive officers totaling $90,000 and a Director Fee payable to one of our Directors, Mr. Edward J. Devereaux of $40.000. Mr. Devereaux elected to receive $50,000 of the Director Fee in cash when funds are available. As of March 31, 2016 $10,000 had been paid to Mr. Devereaux.

On November 4, 2014, Eunis L. Shockey, a member of the Board of directors, loaned us $500,000 under a 30 day promissory note.  The promissory note accrues interest at an annual rate of 10%.  The balance of the note at March 31, 2016 was $128,125. The due date of the note is December 31, 2016.

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, 2016, 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.

10

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) 

6. STOCKHOLDERS’ EQUITY

During the three months ended March 31, 2016 the Company issued 59,297 shares of common stock as compensation for services, with total value of $53,173.

During the three months ended March 31, 2016 the Company issued 1,718,425 shares of common stock in connection with oil and gas lease related costs of $971,966.

During the three months ended March 31, 2016, the Company issued 21,739 shares of common stock in conversion of Preferred Stock valued at $25,000.

During the three months ended March 31, 2016, the Company issued 250,400 shares of common stock for dividends on preferred stock with an aggregate value of $287,960.

During the three months ended March 31, 2016, the Company vested 20,000 warrants as compensation for services, with a total value of $2,000.

During the three months ended March 31, 2016, the Company issued 637,525 warrants in connection with oil and gas lease related costs of $318,761.

During the three months ended March 31, 2016, the Company issued 37,500 warrants in connection with renewal of a loan from a Director valued at $27,750.

A summary of stock options and warrants outstanding as of March 31, 2016 by exercise price and year of expiration is presented below:

Exercise		Expiration Date in
Price		2016		2017		2018		2019		2020		Total
$	0.50						800,000						800,000
$	0.70										425,000		425,000
$	1.00		-		150,000		-		212,525				362,525
$	1.08								37,500				37,500
$	1.40										1,704,346		1,704,346
$	1.57										3,750,000		3,750,000
$	1.73						100,000						100,000
$	1.75		1,135,714		-		-		-				1,135,714
$	1.79										225,000		225,000
$	1.80										850,000		850,000
$	2.00		936,071		126,000		1,696,380		-				2,758,451
$	2.03						2,000,000						2,000,000
$	2.09		-		-		2,800,000		-				2,800,000
$	2.23										911,330		911,330
$	2.29						120,000						120,000
$	2.31						500,000						500,000
$	2.50		100,000		-		-		80,779				180,779
$	2.82		-		-		38,174		-				38,174
$	3.00		100,000		-		-		-				100,000
$	3.50								15,000				15,000
$	4.50		-		-		-		700,000				700,000
$	5.00		8,391		210,000		-		-				218,391
$	6.00		-		-		577,501		327,675				905,176
$	7.00		-		-		-		700,000				700,000
			2,280,176		486,000		8,632,055		2,073,479		7,865,676		21,337,386

11

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) 

6. STOCKHOLDERS’ EQUITY - continued

At March 31, 2016 the Company had reserved 21,337,386 shares for future exercise of warrants.

Warrants issued in relation to the promissory notes issued (see note 9) 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	0.78%
Expected volatility of common stock	191% - 253%
Dividend yield	0.00%
Discount due to lack of marketability	20-30%
Expected life of warrant	3 years - 5 years

7. CAPITALIZED COSTS

The following table presents the capitalized costs of the Company as of March 31, 2016 and December 31, 2015:

	2016			2015
Evaluated costs subject to amortization	$	19,693,962		$	24,177,851
Unevaluated costs		16,975,461			9,677,425
Accumulated impairment expense		(22,783,989	)		(22,783,989	)
Total capitalized costs		13,885,434			11,071,287
Less accumulated depreciation, depletion  and amortization		(4,632,250	)		(4,013,616	)
Net capitalized costs	$	9,253,184		$	7,057,671

Unevaluated costs as of March 31, 2016 include $696,949 associated with the Company’s interest in the Coulter #1 well. The Coulter is a non-core, non-producing asset which we will attempt to monetize by sale of the lease. We presently have approximately 940 acres.

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 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.  The Company has placed a 100% valuation allowance against the net deferred tax asset because future realization of these assets is not assured.

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 for any periods covered by these financial statements.

The Company had a net deferred tax asset related to federal net operating loss carry forwards at March 31, 2016 of $25,142,099 available to offset future taxable income.   The federal net operating loss carry forward 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 carry forwards.  The Company has placed a 100% valuation allowance against the net deferred tax asset because future realization of these assets is not assured.

12

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) 

9. PROMISSORY NOTES

During the quarter ended June 30, 2014, the Company issued $3,197,500 in principal value of 12% Series B Convertible Unsecured Promissory Notes. The 12% Notes are due and payable on June 30, 2017 and provide for conversion into common stock at a price of $4.50 per share and included the issuance of one warrant for each $22.50 of principal amount purchased.  The Company issued a total of 142,111 of these five-year warrants to purchase common stock at an exercise price of $6.00 per share.  The value of the warrant shares was $405,016 and the amount recorded for the beneficial conversion feature was $195,466.  These amounts were recorded as a discount on the 12% Notes.

During the quarter ended September 30, 2014, the Company issued an additional $1,372,000 in principal value of 12% Series B Convertible Unsecured Promissory Notes. The 12% Notes are due and payable on June 30, 2017 and provide for conversion into common stock at a price of $4.50 per share and included the issuance of one warrant for each $22.50 of principal amount purchased.  The Company issued a total of 60,974 of these five-year warrants to purchase common stock at an exercise price of $6.00 per share.  The value of the warrant shares was $157,388 and the amount recorded for the beneficial conversion feature was $-0-.  These amounts were recorded as a discount on the 12% Notes.

During the fourth quarter of 2015 $1 million in note principal was converted into common stock. The total outstanding balance of Series “B” Notes at March 31, 2016 was $3,569,500.

Notes Payable within one year 

The Company is obligated on short term notes and advances payable totaling $602,527 as of March 31, 2016. The due dates are as follows:

Advance due April 30, 2016	$500,000
Note due December 31, 2016	$102,527

The advance of $500,000 which was due on April 30 has been paid in full.

The note payable to a related party of $128,125 is payable with interest to a Director on December 31, 2016.

13

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) 

10. ASSET RETIREMENT OBLIGATIONS

The following is a reconciliation of the asset retirement obligation liability through March 31, 2016:

Asset retirement obligation – December 31, 2014	$	35,951
Estimated liabilities recorded		-
Accretion Expense		1,107
Asset retirement obligation – March 31, 2015	$	37,058
Estimated liabilities recorded		-
Accretion Expense		819
Removal of ARO for wells sold		(1,152	)
Asset retirement obligation – June 30, 2015	$	36,725
Estimated liabilities recorded		-
Accretion Expense		819
Asset retirement obligation – September 30, 2015	$	37,544
Estimated liabilities recorded		-
Accretion Expense		747
Removal of ARO for wells sold		(9,208	)
Asset retirement obligation – December 31, 2015	$	29,083
Estimated liabilities recorded		-
Accretion Expense		747
Asset retirement obligation – March 31, 2016	$	29,830

11. SUBSEQUENT EVENTS

Divestiture of Hunton Play Assets

Management has previously announced that they were seeking to divest certain of the Cimarron assets located in Logan and Kingfisher Counties, Oklahoma including lease rights and current production.  As of March 31, 2016 negotiations and documentation of the sale of the Company’s Cimarron assets in Oklahoma was nearing completion. The sale closed on April 29, 2016 with a sales price $750,000 and an effective date of May 1, 2016.

Legal Proceeding 

On May 4, 2016, Torchlight Energy Resources, Inc. and its subsidiary Torchlight Energy, Inc. filed a lawsuit in the 429th judicial district court in Collin County, Texas against Husky Ventures, Inc., Charles V. Long, April Glidewell, Silverstar of Nevada, Inc., Maximus Exploration, LLC, Atwood Acquisitions, LLC, Gastar Exploration Inc., J. Russell Porter, Michael A. Gerlich, Jerry R. Schuyler, and John M. Selser, Sr. 

Reference Item 2. Management’s Discussion and Analysis regarding the Hunton Play for further detail.

Asset Acquisition

Effective April 1, 2016, Torchlight Energy Inc. acquired from McCabe Petroleum Corporation (Seller) a 66.66% working interest in approximately 12,000 acres in the Midland Basin in exchange for 1,500,000 warrants to purchase Torchlight common stock with an exercise price of $1.00 for five years and a back-in after payout of a 25% working interest to the seller. The Warrant provides that in the event an initial well is not drilled on the Oil and Gas Leases on or before July 10, 2016, that (i) if as of July 10, 2016 the Seller has exercised no portion of the Warrant, the number of Warrant Shares that the Seller will be able to acquire will be reduced to 500,000, (ii) if as of July 10, 2016 the Seller has exercised a portion of the Warrant in an amount less than 500,000 Warrant Shares, the number of Warrant Shares that the Seller will be able to acquire will be reduced to the difference between 500,000 and the number of Warrant Shares for which the Warrant has already been exercised, and (iii) if as of July 10, 2016 the Seller has exercised a portion of the Warrant in an amount more than 500,000 Warrant Shares, the number of Warrant Shares that the Seller will be able to acquire will be reduced to zero.

14

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

Basis of Presentation of Financial Information

On November 23, 2010, the Share Exchange Agreement (the “Exchange Agreement” or “Transaction”) between Pole Perfect Studios, Inc. (“PPS”) and Torchlight Energy, Inc. (“TEI”) was entered into and closed, through which the former shareholders of TEI became shareholders of PPS. At closing, PPS abandoned its previous business. Consequently, as a result of the Transaction, the business of TEI became our sole business.  In addition to TEI, we also operate our business through our subsidiaries Torchlight Energy Operating, LLC, and Hudspeth Oil Corporation.

Summary of Key Results

Overview

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

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 included with our Form 10-K for the year ended December 31, 2015.  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.

Current Projects

As of March 31, 2016 the Company had interests in four oil and gas projects: the Marcelina Creek Field Development in Wilson County, Texas, the Ring Energy Joint Venture in Southwest Kansas, Hunton wells operated by Husky Ventures in Central Oklahoma and the Orogrande Project in Hudspeth County, Texas.

Marcelina Creek Field Development.

On July 6, 2010, TEI entered into a participation agreement with Bayshore Operating Corporation, LLC (“Bayshore”), which 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 wells. Three of the obligation wells have been drilled.  The first three wells include a horizontal re-entry well known as the Johnson-1-H, a vertical well known as the Johnson #4, and a lateral well known as the Johnson #2-H.  These three wells were producing a total of approximately 85 BOPD as of March 31, 2016.  The remaining well (Johnson #3) is to be a vertical development well at a location to be determined within the existing lease. Drilling is anticipated for midyear 2016.

The Company initiated a reentry project on the Johnson #4 well early in 2016 which has been completed. Initial production at completion was 2,920 barrels for the month of February, 2016. Production has declined to approximately 8 barrels per day. However additional work is underway which is expected to substantially restore the rate of production.

Additionally, work is being done on the Johnson #2 applying an acid treatment to increase production. This well is expected to be back in production in the second quarter, 2016.

The Marcelina Creek Field Development is located over the Austin Chalk, Buda, and Eagle Ford Formations, which formations are well known and established producers in central Texas.  Their production is controlled by vertical fracturing of the rock with high productivity in wells which encounter the greatest amount of fractures.  With the advent of horizontal drilling technology, numerous opportunities exist in areas and fields that were only drilled vertically.

15

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

The Ring Energy Joint Venture, Southwest Kansas

In October 2013, we entered into a Joint Venture agreement with Ring Energy.  The agreement called for us to provide for $6.2 million in drilling capital to, in effect, match Ring Energy’s expenditures for leasing.  In exchange for this commitment, we would receive a 50% interest in each well bore drilled and the acreage unit it held, until we had spent $6.2 million.  At such time, we would then receive a 50% Working Interest in the entire lease block consisting of 17,000 +/- acres.  We were to provide $3.1 million in advance of the program commencing, which would cover approximately 5 wells to be drilled and completed.  Once the initial five wells are completed, we and Ring would evaluate the program and the drilling activity and determine if another five wells are to be drilled.  Should we continue with the program, we would then deposit another $3.1 million with Ring for drilling and completion of the next five wells.

We have made the initial $3.1 million deposit and the first five well drilling program is completed. Drilling operations commenced in March, 2014. Seven wells have been drilled – three are producing, one can be converted to a salt water disposal well, one was not completed, and two were plugged and abandoned.  Based upon results from drilling, the participants elected to suspend further drilling and obtain seismic data to guide continuing development. The seismic data has been analyzed at the date of this filing and discussions with potential parties to further develop the property are in process.   As of March 31, 2016, the Company had invested approximately $5,500,000 in the Ring Joint Venture.  The Company believes this project is still considered to be in the testing phase.

Hunton Play, Central Oklahoma

The initial Hunton acquisition included three Hunton wells, the Hancock, Robinson and Lenhart.  The Hancock and Robinson are producing wells but have small working interests of 1% and .25 of 1%, respectively. The Lenhart well was a 62% working interest and was planned for recompletion to return to production. We identified a shallow sandstone that could potentially be productive and tested this formation, and although there were hydrocarbons present, they are not in sufficient quantities to be economic.  The Lenhart property was sold for $25,000 and buyer’s assumption of plugging liability in 2015.

As of March 31, 2016, we were actively producing from ten wells in Cimarron, one in Viking, and one in Prairie Grove.

Cimarron AMI

The Company negotiated a 15% working interest in approximately 3,700 acres in the Cimarron Area of Logan County in May 2013.  Leasing continued monthly which resulted in the total acreage in which the Company had an interest increasing to 5,200 as of March 31, 2016 (Net undeveloped acres = 160). Our net cumulative investment through March 31, 2016 in undeveloped acres in the Cimarron AMI was $761,295.

Management has previously announced that they were seeking to divest certain of the Cimarron assets located in Logan and Kingfisher Counties, Oklahoma including lease rights and current production.  As of March 31, 2016 negotiations and documentation of the sale of the Company’s Cimarron assets in Oklahoma was nearing completion. The sale closed on April 29, 2016 with a sales price $750,000 and an effective date of May 1, 2016.

Chisholm Trail AMI

In the third quarter of 2013, we acquired from a third party for stock, a 15.3% working interest in 5011+/- acres in the Chisolm Trail AMI with Husky Ventures Inc. as the operator. Additional acquisition and  continued monthly leasing in this AMI increased the total acreage in which the Company had an interest and increased the Company’s working interest to 18%.

The Chisholm Trail properties were sold to Husky Ventures during fourth quarter, 2015 who then combined them with the Husky interests in Chisholm Trail and entered into a sale agreement with Gastar Exploration Inc. for the combined Torchlight and Husky interests. The estimated final sale price to Torchlight pending final review by Gastar of lease classification, is $4,150,000. Sale proceeds were applied to reduce Torchlight’s Joint Interest payable to Husky of $2,830,161 with the balance to be received in cash. The Company received $900,000 in cash and has recorded an account receivable as of December 31, 2015 of $419,839. Receipt of the balance of the sale proceeds was subject to final determination of lease classification and was to occur by February 28, 2016. Proceeds have not been received at date of this filing.

16

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

Viking AMI

In the fourth quarter of 2013 we entered into our third Area of Mutual Interest (AMI) with Husky Ventures, the Viking Prospect.  This AMI covers four townships in size. We acquired a 25% interest in 3,945 acres in the Viking. We subsequently acquired an additional 5% in May, 2014.   Leasing continued monthly so that we had an interest in 8,800 total acres in which the Company has an interest as of March 31, 2016. (Net undeveloped acres = 2,600) Husky drilled the first two wells in the AMI in second quarter, 2014.  Our net cumulative investment through March 31, 2016 in undeveloped acres in the Viking AMI was $1,387,928.

Rosedale AMI

In January of 2014, we again elected to continue to expand in the Hunton Play with Husky Ventures.  We contracted for a 25% Working Interest in approximately 5,000 acres in the Rosedale AMI consisting of eight townships in South Central Oklahoma. We subsequently acquired an additional 5% in May, 2014.  Leasing continued monthly so that the Company had an interest in 11,600 total acres as of March 31, 2016 (Net undeveloped acres = 3,500). Our cumulative investment through March 31, 2016 in the Rosedale AMI was $2,834,514.

Prairie Grove – Judy Well

In February of 2014, we acquired a 10% Working Interest in a well in the Prairie Grove AMI from a non-consenting third party who elected not to participate in the well.

Thunderbird AMI

In July of 2014, we elected to further expand in the Hunton Play with Husky Ventures.  We contracted for a 25% Working Interest in the Thunderbird AMI.  There was an ongoing leasing program in this AMI so that the total acres in which the Company has an interest at March 31, 2016 totals 4,300 acres (Net undeveloped acres = 1,100). Our cumulative investment through March 31, 2016 in the Thunderbird AMI was $949,530.

Legal Proceeding 

On May 4, 2016, Torchlight Energy Resources, Inc. and its subsidiary Torchlight Energy, Inc. filed a lawsuit in the 429th judicial district court in Collin County, Texas against Husky Ventures, Inc., Charles V. Long, April Glidewell, Silverstar of Nevada, Inc., Maximus Exploration, LLC, Atwood Acquisitions, LLC, Gastar Exploration Inc., J. Russell Porter, Michael A. Gerlich, Jerry R. Schuyler, and John M. Selser, Sr.  In the lawsuit, we allege, among other things, that the defendants acted improperly in connection with multiple transactions, and that the defendants misrepresented and omitted material information to us with respect to these transactions.  The lawsuit seeks damages arising from 15 different causes of action, including without limitation, violations of the Texas Securities Act, fraud, negligent misrepresentation, breach of fiduciary duty, breach of contract, unjust enrichment and tortious interference.  The lawsuit also seeks a complete accounting as to how our investment funds were used, including all transfers between and among the defendants.  We are seeking the full amount of our damages on $20,000,000 invested.  At this time we believe our damages to be in excess of $1,000,000, but the precise amount will be determined in the litigation.

Orogrande Project, West Texas

On August 7, 2014, we entered into a Purchase Agreement with Hudspeth Oil Corporation (“Hudspeth”), McCabe Petroleum Corporation (“MPC”), and Greg McCabe. 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 172,000 mostly contiguous acres in the Orogrande Basin in West Texas. This acreage is in the primary term under five-year leases that carry additional five-year extension provisions. As consideration, at closing we issued 868,750 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 will have an optional 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.  Closing of the transactions contemplated by the Purchase Agreement occurred on September 23, 2014.

17

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

Of the 172,000 acres, 40,154 were scheduled for renewal in December, 2014.  The Company renewed the leases for the 40,154 acres during second quarter, 2015. Prior to March 31, 2015, the Company had the obligation to begin drilling its first well in order to hold the acreage block. The well was permitted and spudded and drilling began by March 31, 2015.

The Company finalized an agreement to sell a 5% working interest in the Orogrande acreage on June 30, 2015 with an effective date of April 1, 2015. Sale proceeds were $500,000 which were received in April, 2015. In addition, the Company issued 250,000 three year warrants with an exercise price of $.50 to the purchaser.

On September 23, 2015, our subsidiary, Hudspeth Oil Corporation (“HOC”), entered into a Farmout Agreement by and between HOC, Pandora Energy, LP (“Pandora”), Founders Oil & Gas, LLC (“Founders”), McCabe Petroleum Corporation and Greg McCabe (McCabe Petroleum Corporation and Greg McCabe are parties to the Farmout Agreement for limited purposes) for the entire Orogrande Project in Hudspeth County, Texas.  The Farmout Agreement provides for Founders to earn from HOC and Pandora (collectively, the “Farmor”) an undivided 50% of the leasehold interest in the Orogrande Project by Founder’s spending a minimum of $45 million on actual drilling operations on the Orogrande Project in the next two years.  Founders is to pay Farmor a total cost reimbursement of $5,000,000 in multiple installments as follows: (1) $1,000,000 at the signing of the Farmout Agreement, the balance of which was received on September 24, 2015; (2) within 90 days from the closing, Founders will frac and complete the Rich A-11 No. 1 Well; and (3) within five days of the spudding of each of the next eight wells drilled by Founders, Founders will pay to Farmor $500,000 resulting in the payment of the remaining amount; provided that, in the event that within 90 days after the fracing of the Rich Well, Founders notifies Farmor of its election not to drill any additional wells, Founders shall have no further obligation to make further payment.  Upon payment of the first $1,000,000, Farmor assigned to Founders an undivided 50% of the leasehold interest and a 37.5% net revenue interest in the leases subject to the terms of the Farmout Agreement (including obligations to re-assign to HOC and Pandora if the 50% interest in the entire Orogrande Project is not earned) and a proportionate share of the McCabe 10% BIAPO (back in after pay out) interest; provided, however, that for each well that Founders drills prior to earning the acreage, it will be assigned a 50% working interest in the wellbore and in the lease on which it sits.

Under a joint operating agreement (on A.A.P.L. Form 610 – 1989 Model Form Operating Agreement with COPAS 2005 Accounting Procedures) (“JOA”) also entered into on September 23, 2015, Founders Oil & Gas Operating, LLC is designated as operator of the leases.  Any variance to the operating plan will be determined by a Development Committee, which committee will be made up of members from Founders and Farmor, or their designees, to discuss and recommend the location of the drill wells, data to be gathered and the form of same.  As contemplated under the Farmout Agreement, starting within 90 days of the completion of the fracing on the Rich Well, and at all times subject to the 90 day continuous drilling clause, Founders has the option, but not the obligation, to retain the assigned interest as follows: (1) if Founders spends a minimum of $45 million on actual drilling operations while maintaining compliance with the continuous drilling clause, subject to reasonable delays resulting from reasonable Force Majeure conditions, Founders will have fulfilled its farmout obligations and will be entitled to retain the assigned interests. If Founders does not meet such obligations, it will reassign to Farmor the assigned interest except it will be entitled to retain its interest in the leases covering all wells drilled by Founders and the sections in which such wells are located. Additionally, Founders will resign as operator of the JOA as to all lands reassigned; and (2) Farmor will be carried in all drilling operations during the first two years and/or $45 million in drilling operations, whichever comes last, subject to Founders’ right to recoup certain expenses on “Gap Wells.”  After three years and after Founders has earned its working interest, either party may elect to market the acreage as an entire block, including operatorship.  Should an acceptable bid arise, and both parties agree, the block will be sold 100% working interest to that third party bidder.  However, if only one party wants to accept the outside offer, the other party (the party who wishes not to sell) has the right to purchase the working interest from the selling party.

The Rich A-11 well that was drilled by Torchlight in second quarter, 2015 has been evaluated and numerous scientific tests were performed to provide key data for the field development thesis. During the testing process a poor cement bond was identified preventing a cost effective production test for the primary pay zones. Repair to the well bore necessary for a subsequent frac procedure was determined to be economically unfeasible due to the limitations related to casing size. With the Rich A-11 designed as a test well rather than commercial target, planning began for drilling the next well(s) using larger casing typically utilized for commercial production.

Torchlight Energy and Founders have elected to move forward on planning the next phase of drilling in the Orogrande Project. The project operator plans to permit three new wells starting with the University Founders B-19 #1 well. The new wells would be   drilled vertically for test purposes and would have sufficient casing size to support lateral entry into any pay zone(s) encountered once the well is tested vertically. Torchlight and the project operator would then run a battery of tests on each well to gain information for future development of the field.

18

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

Historical Results for the quarters ended March 31, 2016 and 2015:

Revenues and Cost of Revenues

For the quarter ended March 31, 2016, we had production revenue of $194,235 compared to $534,562 for the quarter ended March 31, 2015. Refer to the table of production and revenue history below.  Our cost of revenue, consisting of lease operating expenses and production taxes, was $105,998, and $230,897 for the quarters ended March 31, 2016 and 2015, respectively.

Property	Quarter		Oil Production {BBLS}		Gas Production {MCF}		Oil Revenue		Gas Revenue		Total Revenue
Marcelina		Q1 - 2015		2,425		0	$	98,787	$	-	$	98,787
Oklahoma		Q1 - 2015		5,931		37,226	$	277,574	$	117,521	$	395,095
Kansas		Q1 - 2015		979		0	$	40,680	$	-	$	40,680
Total Q1-2015				9,335		37,226		417,041		117,521		534,562
Marcelina		Q2 - 2015		1,957		0	$	101,291	$	-	$	101,291
Oklahoma		Q2 - 2015		5,495		32,348	$	290,540	$	97,374	$	387,914
Kansas		Q2 - 2015		889		0	$	19,060	$	-	$	19,060
Total Q2-2015				8,341		32,348	$	410,891	$	97,374	$	508,265
Marcelina		Q3 - 2015		2,177		0	$	86,845	$	-	$	86,845
Oklahoma		Q3 - 2015		4,550		31,275	$	212,156	$	87,791	$	299,947
Kansas		Q3 - 2015		370		0	$	13,238	$	-	$	13,238
Total Q3-2015				7,097		31,275	$	312,239	$	87,791	$	400,030
Marcelina		Q4 - 2015		1,337		0	$	44,391	$	-	$	44,391
Oklahoma		Q4 - 2015		1,624		12,380	$	93,864	$	37,349	$	131,213
Kansas		Q4 - 2015		247		0	$	9,573	$	-	$	9,573
Total Q4-2015				3,208		12,380	$	147,828	$	37,349	$	185,177
Year Ended 12/31/15				27,981		113,229	$	1,287,999	$	340,035	$	1,628,034
Marcelina		Q1 - 2016		3,000		0	$	92,546	$	-	$	92,546
Oklahoma		Q1 - 2016		2,026		21,148	$	54,211	$	38,624	$	92,835
Kansas		Q1 - 2016		312		0	$	8,854	$	-	$	8,854
Total Q1-2016				5,338		21,148		155,611		38,624		194,235

We recorded depreciation, depletion, and amortization expense of $621,972 for the quarter ended March 31, 2016 compared to $494,475 for the quarter ended March 31, 2015.

General and Administrative Expenses

Our general and administrative expenses for the quarters ended March 31, 2016 and 2015 were $951,285 and $688,711, respectively, an increase of $262,574. 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 quarters ended March 31, 2016 compared to 2015 is detailed as follows:

Increase(decrease) in non cash stock and warrant compensation	$	180,843
Increase(decrease) in consulting expense	$	(40,417	)
Increase(decrease) in professional fees / legal fees	$	39,533
Increase(decrease) in travel expense	$	7,962
Increase(decrease) in salaries and compensation	$	52,375
Increase(decrease) investor relations	$	20,403
Increase(decrease) in insurance	$	(14,330	)
Increase(decrease) in general corporate expenses	$	16,205
Total Increase in General and Administrative Expenses	$	262,574

19

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

Liquidity and Capital Resources

At March 31, 2016, we had working capital of ($2,944,134), current assets of $1,419,024 consisting of cash, accounts receivable, notes receivable, and prepaid expenses and total assets of $10,767,130 consisting of current assets, investments in oil and gas properties, and other assets. As of March 31, 2016, we had current liabilities of $4,363,158, consisting of, accounts payable (principally for development costs), payables to related parties, notes payable, and accrued interest. Stockholders’ equity was $3,036,175.

Cash flow provided by (used) in operating activities for the quarter ended March 31, 2016 was $798,029 compared to $1,036,082 for the quarter ended March 31, 2015, a decrease of $238,053. Cash flow provided by operating activities for the quarter ended March 31, 2016 can be primarily attributed to net losses from operations of $1,607,318 which consists primarily of $951,285 in general and administrative expenses, depreciation, depletion and amortization of $621,972, accretion of convertible note discounts of $48,498. Cash flow provided by operating activities for the quarter ended March 31, 2015 can be primarily attributed to net losses from operations of $2,214,267, which consists primarily of $688,711 in general and administrative expenses, depreciation, depletion, and amortization of $494,475, and accretion of convertible note discounts $1,099,058. 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 flow used in investing activities for the quarter ended March 31, 2016 was $1,481,507 compared to $1,237,162 for the quarter ended March 31, 2015.  Cash flow used in investing activities consists primarily of oil and gas investments in Texas properties during the quarter ended March 31, 2016.

Cash flow provided by financing activities for the quarter ended March 31, 2016 was $283,481 as compared to $33,381 for the quarter ended March 31, 2015.  Cash flow provided by financing activities consists primarily of proceeds from common stock issues, promissory notes, and warrant exercises.  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.

Our current assets are insufficient to meet our current obligations or to satisfy our cash needs over the next twelve months and as such 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 and working capital deficits.   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

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 March 31, 2016 and March 31, 2015, 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.

As of March 31, 2016 the Company had interests in four oil and gas projects: the Marcelina Creek Field Development in Wilson County, Texas, the Ring Energy Joint Venture in Southwest Kansas, the Hunton play in Central Oklahoma and the Orogrande Project in Hudspeth County, Texas. See the description under “Current Projects” above under “Overview” for more information and disclosure regarding commitments and contingencies relating to these projects.  

ITEM 3.   QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not Applicable.

20

ITEM 4.   CONTROLS AND PROCEDURES

Disclosure 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, 2016. Based on this evaluation, our principal executive officer and principal financial officer concluded that, as of the end of the period covered by this report, 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 principal executive officer and principal financial officer, in a manner that allowed for timely decisions regarding disclosure. 

Changes in Internal Control over Financial Reporting

Our principal executive officer and principal financial officer have 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, Torchlight Energy Inc. filed a lawsuit against Hockley Energy, Inc. and Frank O. Snortheim in the District Court of Harris County, Texas in connection with farmout agreements entered into with Hockley Energy in November 2011.  In the lawsuit, we sued Hockley Energy and Snortheim for breach of contract, fraudulent inducement, promissory estoppel pertaining to failure to perform two farmout agreements entered into on November 4, 2011, the first relating to the Marcelina Creek prospect and the second relating to the East Stockdale prospect.  Under the Marcelina Farmout, Hockley Energy had an obligation to fund $2,231,250.00 no later than November 18, 2011.  They did not perform as promised.  On February 23, 2015, we obtained a summary judgment against Hockley Energy in the amount of $16,400,000 in damages and $21,877 in attorney fees.  On March 31, 2016, we obtained a judgement against Snortheim for $16,400,000 in damages plus prejudgement interest of $3,385,587. We are currently seeking to enforce the judgment, but it is doubtful that any substantial portion of the judgment is recoverable from Hockley Energy.  

On May 4, 2016, Torchlight Energy Resources, Inc. and its subsidiary Torchlight Energy, Inc. filed a lawsuit in the 429th judicial district court in Collin County, Texas against Husky Ventures, Inc., Charles V. Long, April Glidewell, Silverstar of Nevada, Inc., Maximus Exploration, LLC, Atwood Acquisitions, LLC, Gastar Exploration Inc., J. Russell Porter, Michael A. Gerlich, Jerry R. Schuyler, and John M. Selser, Sr.  In the lawsuit, we allege, among other things, that the defendants acted improperly in connection with multiple transactions, and that the defendants misrepresented and omitted material information to us with respect to these transactions.  The lawsuit seeks damages arising from 15 different causes of action, including without limitation, violations of the Texas Securities Act, fraud, negligent misrepresentation, breach of fiduciary duty, breach of contract, unjust enrichment and tortious interference.  The lawsuit also seeks a complete accounting as to how our investment funds were used, including all transfers between and among the defendants.  We are seeking the full amount of our damages on $20,000,000 invested.  At this time we believe our damages to be in excess of $1,000,000, but the precise amount will be determined in the litigation.

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

During the three months ended March 31, 2016 the Company issued 59,297 shares of common stock as compensation for consulting services.

During the three months ended March 31, 2016 the Company issued 1,718,425 shares of common stock in connection with lease related costs.

21

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

During the three months ended March 31, 2016, the Company issued 21,739 shares of common stock in conversion of Preferred Stock.

During the three months ended March 31, 2016, the Company issued 250,400 shares of common stock for dividends on preferred stock.

During the three months ended March 31, 2016, the Company issued 637,525 warrants in connection with lease related costs, including 212,525 warrants in January 2016 with an exercise price of $1.00 per shares that expire in January 2019, and 425,000 warrants in February 2016 with an exercise price of $0.70 per share that expire in February 2020.

In January 2016, the Company issued 37,500 warrants in connection with renewal of a loan from a Director. The warrants have an exercise price of $1.08 per share and expire in January 2019.

In February 2016, the Company vested 20,000 warrants as compensation for services.  The warrants have an exercise price of $5.00 per share and expire in February 2017.

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.

ITEM 3.  DEFAULTS UPON SENIOR SECURITIES.

None

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	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	Amended and Restated Bylaws (Incorporated by reference from Form 8-K filed with the SEC on January 12, 2011.) *
4.1	Certificate of Designation for Series A Convertible Preferred Stock (Incorporated by reference from Form 8-K filed with the SEC on June 9, 2015.) *
4.2	Certificate of Designation for Series B Convertible Preferred Stock (Incorporated by reference from Form 8-K filed with the SEC on September 30, 2015.) *
10.1	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) *
10.2	Purchase and Sale Agreement between Torchlight Energy Inc. and Xtreme Oil and Gas Inc..effective April 1, 2013. (Incorporated by reference from Form 10-Q filed with the SEC on May 15, 2013)*
10.3	Development Agreement between Ring Energy, Inc. and Torchlight Energy Resources, Inc. (Incorporated by reference from Form 8-K filed with the SEC on October 22, 2013.) *
10.4	Coulter Limited Partnership Agreement dated January 10, 2012 (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2014.) *

22

ITEM 6.  EXHIBITS - continued

10.5	Promissory Note with Boeckman Well LLC dated May 1, 2013 and amendments thereto (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2014.) *
10.6	Securities Purchase Agreement (form of), January 2014  (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2014.) *
10.7	Registration Rights Agreement (form of), January 2014  (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2014.) *
10.8	Purchase Agreement with Hudspeth Oil Corporation, McCabe Petroleum Corporation and Greg McCabe dated August 7, 2014 (Incorporated by reference from Form 10-Q/A filed with the SEC on October 21, 2014.) *
10.9	Purchase and Sale Agreement between Torchlight Energy, Inc. and Zenith Petroleum Corporation (Incorporated by reference from Form 8-K filed with the SEC on June 10, 2014) *
10.10	Securities Purchase Agreement with Castleton Commodities Opportunities Master Fund, L.P. (Incorporated by reference from Form 8-K filed with the SEC on August 20, 2014) *
10.11	Purchase Agreement with Hudspeth Oil Corporation, McCabe Petroleum Corporation and Greg McCabe dated August 7, 2014 (Incorporated by reference from Form 10-Q/A filed with the SEC on October 21, 2014) *
10.12	12% Series B Unsecured Convertible Promissory Note (form of) (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2015.) *

10.13	Securities Purchase Agreement (for Series A Convertible Preferred Stock) (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2015.) *
10.14	Employment Agreement (with John A. Brda) (Incorporated by reference from Form 8-K filed with the SEC on June 16, 2015.) *
10.15	Employment Agreement (with Willard G. McAndrew) (Incorporated by reference from Form 8-K filed with the SEC on June 16, 2015.) *
10.16	Employment Agreement (with Roger Wurtele) (Incorporated by reference from Form 8-K filed with the SEC on June 16, 2015.) *
10.17	Loan documentation and warrants with Eunis L. Shockey (Incorporated by reference from Form 10-Q filed with the SEC on August 14, 2015.) *
10.18	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) *
10.19	Securities Purchase Agreement and Amendment to Securities Purchase Agreement (for Series B Convertible Preferred Stock) (Incorporated by reference from Form 10-Q filed with the SEC on November 12, 2015) *
10.20	Purchase and Sale Agreement with Husky Ventures, Inc. (Incorporated by reference from Form 8-K filed with the SEC on November 12, 2015) *
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

23

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 16, 2016	/s/ John A. Brda
	By: John A. Brda
	Chief Executive Officer

Date: May 16, 2016	/s/ Roger Wurtele
	By: Roger Wurtele
	Chief Financial Officer and Principal Accounting Officer

24

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO SECTION 302 OF THE

SARBANES-OXLEY ACT OF 2002

I, John A. Brda, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Torchlight Energy Resources, Inc. for the quarter ended March 31, 2016;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15 (e) and 15d- 15 (e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

     a)  Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material  information relating to the small  business issuer, including its consolidated subsidiary, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

     b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

     c) Evaluated the effectiveness of the registrant's disclosure controls and procedures, and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

     d)  Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's fourth quarter that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over the financial reporting; and

5. I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

     a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

     b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ John A. Brda

By: John A. Brda

Chief Executive Officer

(Principal Executive Officer)

Date: May 16, 2016

EX-31.2

Exhibit 31.2

CERTIFICATION PURSUANT TO SECTION 302 OF THE

SARBANES-OXLEY ACT OF 2002

I, Roger Wurtele, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Torchlight Energy Resources, Inc. for the quarter ended March 31, 2016;

2.  Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.  Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15 (e) and 15d- 15 (e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

     a)  Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material  information relating to the small  business issuer, including its consolidated subsidiary, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

     b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

     c) Evaluated the effectiveness of the registrant's disclosure controls and procedures, and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

     d)  Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's fourth quarter that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over the financial reporting; and

5. I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

     a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

     b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Roger Wurtele

By: Roger Wurtele,

Chief Financial Officer

(Principal Financial Officer)

Date: May 16, 2016

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

I, John A. Brda, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the quarterly report on Form 10-Q of Torchlight Energy Resources, Inc. for the quarter ended March 31, 2016, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in such quarterly report on Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Torchlight Energy Resources, Inc.

/s/ John A. Brda

John A. Brda,

Chief Executive Officer (Principal Executive Officer)

Date: May 16, 2016

I, Roger Wurtele, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that the quarterly report on Form 10-Q of Torchlight Energy Resources, Inc. for the quarter ended March 31, 2016, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934 and that information contained in such quarterly report on Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of Torchlight Energy Resources, Inc.

/s/ Roger Wurtele

Roger Wurtele,

Chief Financial Officer (Principal Financial Officer)

Date: May 16, 2016

The foregoing certification is not deemed filed with the Securities and Exchange Commission for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (“Exchange Act”), and is not to be incorporated by reference into any filing of Torchlight Energy Resources, Inc. under the Securities Act of 1933, as amended, or the Exchange Act, whether made before or after the date hereof, regardless of any general incorporation language in such filing.

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	May. 11, 2016
Document and Entity Information
Entity Registrant Name	TORCHLIGHT ENERGY RESOURCES INC
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Entity Central Index Key	0001431959
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		36,165,741
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1

XML

CONSOLIDATED CONDENSED BALANCE SHEETS - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash	$ 626,602	$ 1,026,600
Accounts Receivable	499,841	741,653
Production revenue receivable	203,967	199,317
Note receivable	0	613
Prepayments - development costs	88,614	0
Prepaid expenses	0	38,776
Total current assets	1,419,024	2,006,959
Investment in oil and gas properties, net	9,253,184	7,057,671
Office Equipment	39,772	43,110
Debt issuance costs, net	6,851	8,224
Other Assets	48,299	72,082
TOTAL ASSETS	10,767,130	9,188,046
Current liabilities:
Accounts payable	2,458,483	1,114,409
Accrued liabilities	652,079	628,876
Related party payables	130,000	130,000
Note payable within one year - related party	128,125	205,000
Notes payable within one year	602,527	129,741
Due to working interest owners	108,451	103,364
Interest payable	283,493	173,710
Total current liabilities	4,363,158	2,485,100
Convertible promissory notes, (Series B) net of discount of $231,533 at March 31, 2016 and $277,911 at December 31, 2015	3,337,967	3,291,589
Asset retirement obligation	$ 29,830	$ 29,083
Commitments and contingencies
Stockholders' equity:
Preferred stock, par value $.001, 10,000,000 shares authorized, 133,750 shares issued and outstanding	$ 134	$ 134
Common stock, par value $0.001 per share; 100,000,000 shares authorized; 35,216,205 issued and outstanding at March 31, 2016, 33,166,344 issued and outstanding at December 31, 2015	35,219	33,168
Additional paid-in capital	62,832,108	61,921,450
Warrants outstanding	16,679,472	16,330,961
Accumulated deficit	(76,510,758)	(74,903,439)
Total stockholders' equity	3,036,175	3,382,274
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 10,767,130	$ 9,188,046

XML

CONSOLIDATED CONDENSED BALANCE SHEETS (Parenthetical) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Assets [Abstract]
Discount on Convertible promissory notes noncurrent	$ 231,533	$ 277,911
Preferred Stock, par value	$ 0.001	$ 0.001
Preferred Stock, shares authorized	10,000,000	10,000,000
Preferred Stock, shares issued	134,000	134,000
Preferred Stock, shares outstanding	133,750	134,000
Common Stock, par or stated value	$ 0.001	$ 0.001
Common Stock, shares authorized	100,000,000	100,000,000
Common Stock, shares issued	35,216,205	33,166,344
Common Stock, shares outstanding	35,216,205	33,166,344

XML

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Revenue:
Oil and gas sales	$ 194,235	$ 534,562
SWD and royalties	78	56,696
Cost of revenue	(105,998)	(230,897)
Gross income	88,315	360,361
Operating expenses:
General and administrative expenses	951,285	688,711
Depreciation, depletion and amortization	621,972	494,475
Total operating expenses	1,573,257	1,183,186
Other income (expense)
Interest income	0	0
Interest and accretion expense	(122,376)	(1,391,442)
Total other income (expense)	(122,376)	(1,391,442)
Net loss before taxes	(1,607,318)	(2,214,267)
Provision for income taxes	0	0
Net (loss)	$ (1,607,318)	$ (2,214,267)
Loss per share:Basic and Diluted	$ (0.07)	$ (0.12)
Weighted average shares outstanding: Basic and Diluted	23,113,892	18,378,669

XML

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOW - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash Flows From Operating Activities
Net (loss)	$ (1,607,318)	$ (2,214,267)
Adjustments to reconcile net loss to net cash from operating activities:
Stock based compensation	82,922	(97,000)
Accretion of convertible note discounts	48,498	1,099,058
Depreciation, depletion and amortization	621,972	494,475
Change in:
Accounts receivable	241,812	(16,646)
Note receivable	613	(160)
Production revenue receivable	(4,650)	(160,516)
Prepayment of development costs	(88,614)	7,457
Prepaid expenses	38,776	29,634
Other assets	23,784	131
Accounts payable and accrued liabilities	1,367,276	1,946,804
Due to working interest owners	5,087	(643)
Asset retirement obligation	0	1,107
Interest payable	109,783	151,989
Capitalized interest	(41,912)	(205,341)
Net cash provided by (used in) operating activities	798,029	1,036,082
Cash Flows From Investing Activities
Investment in oil and gas properties	(1,481,507)	(1,507,162)
Proceeds from Sale of Leases	0	270,000
Net cash used in investing activities	(1,481,507)	(1,237,162)
Cash Flows From Financing Activities
Proceeds from sale of common stock	0	0
Proceeds from sale of preferred stock	0	0
Payment of preferred stock dividends	(112,430)	0
Proceeds from warrant exercise	0	0
Proceeds from promissory notes	505,652	33,381
Repayment of promissory notes	(109,742)	0
Net cash provided by financing activities	283,480	33,381
Net increase (decrease) in cash	(399,998)	(167,699)
Cash - beginning of period	1,026,600	179,787
Cash - end of period	626,602	12,088
Non cash transactions:
Common stock issued for services	53,173	(94,500)
Common stock issued for mineral interests	971,966	0
Warrants issued for services	2,000	4,000
Warrants issued in connection with promissory notes	27,750	0
Warrants issued in connection with lease interests	318,761	0
Reduction in accounts receivable for WI acquisition	0	101,058
Common stock issued in warrant exercises	0	0
Cash paid for interest	$ 34,741	$ 323,248

XML

1. NATURE OF BUSINESS

3 Months Ended

Mar. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

NATURE OF BUSINESS

Torchlight Energy Resources, Inc. 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.  In addition to TEI, we also operate our business through our wholly-owned subsidiaries Torchlight Energy Operating, LLC, a Texas limited liability company and Hudspeth Oil Corporation, a Texas corporation.

On December 10, 2010, we effected a 4-for-1 forward split of our 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.  All share amounts reflected throughout this report take into account the 4-for-1 forward split.

Effective February 8, 2011, we changed our name to “Torchlight Energy Resources, Inc.”  In connection with the name change, our ticker symbol changed from “PPFT” to “TRCH.”

The Company is engaged in the acquisition, exploration, development and production of oil and gas properties within the United States. The Company’s success will depend in large part on its ability to obtain and develop profitable oil and gas interests.

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2. GOING CONCERN

3 Months Ended

Mar. 31, 2016

GOING CONCERN

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, 2016, the Company had not yet achieved profitable operations. We had a net loss of approximately $1.6 million for the quarter ended March 31, 2016 and had accumulated losses of $76,510,758 since our inception to March 31, 2016, and expect to incur further losses in the development of our business.  Working Capital as of March 31, 2016 was negative $2,944,134. 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; (3) participating in joint venture transactions with third parties; or (4) sale of assets.  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.

Planned Divestiture of Hunton Project

Management has previously announced that they were seeking to divest certain of the Cimarron assets located in Logan and Kingfisher Counties, Oklahoma including lease rights and current production.  As of March 31, 2016 negotiations and documentation of the sale of the Company’s Cimarron assets in Oklahoma was nearing completion. The sale closed on April 29, 2016 with a sales price $750,000 and an effective date of May 1, 2016.

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3. SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Mar. 31, 2016

Accounting Policies [Abstract]

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, and Hudspeth Oil Corporation. 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 periodically reviews the credit worthiness of the financial institutions with which it does business. At times the Company’s cash balances are 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, notes payable to related party, and convertible promissory notes. The estimated fair values of cash, accounts receivable, accounts payable, and related party payables approximate the carrying amount due to the relatively short maturity of these instruments. The carrying amounts of the convertible 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.

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, 2016 and December 31, 2015 no valuation allowance was considered necessary.

As of December 31, 2015, the Company had a $419,839 account receivable from Husky Ventures for the estimated balance of the sale proceeds from the sale of the Chisholm Trail properties in fourth quarter, 2015. The Chisholm Trail properties were sold to Husky Ventures who then included them with the Husky interests in Chisholm Trail and then entered into a sale agreement with Gastar Exploration Inc. for the combined Torchlight and Husky interests. Receipt of the balance of the sale proceeds was subject to final determination of mineral lease classification and was to occur by February 28, 2016. The account receivable was not collected as of March 31, 2016.

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.

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 periods ended March 31, 2016 and March 31, 2015, the Company capitalized $41,912 and $205,341, 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 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 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 Company recognized impairment of $22,438,114 on its oil and gas properties during the three months ended June 30, 2015 and an additional impairment at December 31, 2015 of $3,236,009 for a total impairment adjustment for 2015 of $25,674,123. No impairment was recognized at March 31, 2016. 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. 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.

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.

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.

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.  The Company has not included potentially dilutive securities in the calculation of loss per share for any periods presented as the effects 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.

Recent accounting pronouncements –

On August 27, 2014, the FASB issued ASU 2014-15, which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of the Company’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The ASU applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted.

In May 2014, the FASB issued ASU 2014-09 that introduces a new five-step revenue recognition model in which an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This ASU also requires disclosures sufficient to enable users to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including qualitative and quantitative disclosures about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. This standard is effective for fiscal years beginning after December 15, 2017, including interim periods within that reporting period. The Company is currently evaluating the new guidance to determine the impact it will have on its consolidated financial statements.

In April 2014, the FASB issued ASU 2014-08, which includes amendments that change the requirements for reporting discontinued operations and require additional disclosures about discontinued operations. Under the new guidance, only disposals representing a strategic shift in operations - that is, a major effect on the organization’s operations and financial results should be presented as discontinued operations. Additionally, the ASU requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income, and expenses of discontinued operations. The new standard is effective in the first quarter of 2015 for public organizations with calendar year ends. Early adoption would be permitted for any annual or interim period for which an entity’s financial statements have not yet been made available for issuance. The adoption of this guidance is not expected to have an impact on the Company’s 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 May 16, 2016, the date of issuance of the financial statements. Subsequent events are disclosed in Note 11.

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4. RELATED PARTY PAYABLES

3 Months Ended

Mar. 31, 2016

RELATED PARTY TRANSACTIONS

RELATED PARTY PAYABLES

As of March 31, 2016, related party payables consisted of accrued and unpaid compensation to two of our executive officers totaling $90,000 and a Director Fee payable to one of our Directors, Mr. Edward J. Devereaux of $40.000. Mr. Devereaux elected to receive $50,000 of the Director Fee in cash when funds are available. As of March 31, 2016 $10,000 had been paid to Mr. Devereaux.

On November 4, 2014, Eunis L. Shockey, a member of the Board of directors, loaned us $500,000 under a 30 day promissory note.  The promissory note accrues interest at an annual rate of 10%.  The balance of the note at March 31, 2016 was $128,125. The due date of the note is December 31, 2016.

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5. COMMITMENTS AND CONTINGENCIES

3 Months Ended

Mar. 31, 2016

COMMITMENTS AND CONTINGENCIES

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, 2016, 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.

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6. STOCKHOLDERS' EQUITY

3 Months Ended

Mar. 31, 2016

Stockholders' equity:

STOCKHOLDERS' EQUITY

During the three months ended March 31, 2016 the Company issued 59,297 shares of common stock as compensation for services, with total value of $53,173.

During the three months ended March 31, 2016 the Company issued 1,718,425 shares of common stock in connection with oil and gas lease related costs of $971,966.

During the three months ended March 31, 2016, the Company issued 21,739 shares of common stock in conversion of Preferred Stock valued at $25,000.

During the three months ended March 31, 2016, the Company issued 250,400 shares of common stock for dividends on preferred stock with an aggregate value of $287,960.

During the three months ended March 31, 2016, the Company vested 20,000 warrants as compensation for services, with a total value of $2,000.

During the three months ended March 31, 2016, the Company issued 637,525 warrants in connection with oil and gas lease related costs of $318,761.

During the three months ended March 31, 2016, the Company issued 37,500 warrants in connection with renewal of a loan from a Director valued at $27,750. 

A summary of stock options and warrants outstanding as of March 31, 2016 by exercise price and year of expiration is presented below:

Exercise		Expiration Date in
Price		2016		2017		2018		2019		2020		Total
$	0.50						800,000						800,000
$	0.70										425,000		425,000
$	1.00		-		150,000		-		212,525				362,525
$	1.08								37,500				37,500
$	1.40										1,704,346		1,704,346
$	1.57										3,750,000		3,750,000
$	1.73						100,000						100,000
$	1.75		1,135,714		-		-		-				1,135,714
$	1.79										225,000		225,000
$	1.80										850,000		850,000
$	2.00		936,071		126,000		1,696,380		-				2,758,451
$	2.03						2,000,000						2,000,000
$	2.09		-		-		2,800,000		-				2,800,000
$	2.23										911,330		911,330
$	2.29						120,000						120,000
$	2.31						500,000						500,000
$	2.50		100,000		-		-		80,779				180,779
$	2.82		-		-		38,174		-				38,174
$	3.00		100,000		-		-		-				100,000
$	3.50								15,000				15,000
$	4.50		-		-		-		700,000				700,000
$	5.00		8,391		210,000		-		-				218,391
$	6.00		-		-		577,501		327,675				905,176
$	7.00		-		-		-		700,000				700,000
			2,280,176		486,000		8,632,055		2,073,479		7,865,676		21,337,386

At March 31, 2016 the Company had reserved 21,337,386 shares for future exercise of warrants.

Warrants issued in relation to the promissory notes issued (see note 9) 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	0.78%
Expected volatility of common stock	191% - 253%
Dividend yield	0.00%
Discount due to lack of marketability	20-30%
Expected life of warrant	3 years - 5 years

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7. CAPITALIZED COSTS

3 Months Ended

Mar. 31, 2016

Extractive Industries [Abstract]

7. CAPITALIZED COSTS

The following table presents the capitalized costs of the Company as of March 31, 2016 and December 31, 2015:

	2016			2015
Evaluated costs subject to amortization	$	19,693,962		$	24,177,851
Unevaluated costs		16,975,461			9,677,425
Accumulated impairment expense		(22,783,989	)		(22,783,989	)
Total capitalized costs		13,885,434			11,071,287
Less accumulated depreciation, depletion  and amortization		(4,632,250	)		(4,013,616	)
Net capitalized costs	$	9,253,184		$	7,057,671

Unevaluated costs as of March 31, 2016 include $696,949 associated with the Company’s interest in the Coulter #1 well. The Coulter is a non-core, non-producing asset which we will attempt to monetize by sale of the lease. We presently have approximately 940 acres.

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8. INCOME TAXES

3 Months Ended

Mar. 31, 2016

Income Taxes

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.  The Company has placed a 100% valuation allowance against the net deferred tax asset because future realization of these assets is not assured.

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 for any periods covered by these financial statements.

The Company had a net deferred tax asset related to federal net operating loss carry forwards at March 31, 2016 of $25,142,099 available to offset future taxable income.   The federal net operating loss carry forward 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 carry forwards.  The Company has placed a 100% valuation allowance against the net deferred tax asset because future realization of these assets is not assured.

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9. PROMISSORY NOTES

3 Months Ended

Mar. 31, 2016

PROMISSORY NOTES

Promissory Notes

During the quarter ended June 30, 2014, the Company issued $3,197,500 in principal value of 12% Series B Convertible Unsecured Promissory Notes. The 12% Notes are due and payable on June 30, 2017 and provide for conversion into common stock at a price of $4.50 per share and included the issuance of one warrant for each $22.50 of principal amount purchased.  The Company issued a total of 142,111 of these five-year warrants to purchase common stock at an exercise price of $6.00 per share.  The value of the warrant shares was $405,016 and the amount recorded for the beneficial conversion feature was $195,466.  These amounts were recorded as a discount on the 12% Notes.

During the quarter ended September 30, 2014, the Company issued an additional $1,372,000 in principal value of 12% Series B Convertible Unsecured Promissory Notes. The 12% Notes are due and payable on June 30, 2017 and provide for conversion into common stock at a price of $4.50 per share and included the issuance of one warrant for each $22.50 of principal amount purchased.  The Company issued a total of 60,974 of these five-year warrants to purchase common stock at an exercise price of $6.00 per share.  The value of the warrant shares was $157,388 and the amount recorded for the beneficial conversion feature was $-0-.  These amounts were recorded as a discount on the 12% Notes.

During the fourth quarter of 2015 $1 million in note principal was converted into common stock. The total outstanding balance of Series “B” Notes at March 31, 2016 was $3,569,500.

Notes Payable within one year 

The Company is obligated on short term notes and advances payable totaling $602,527 as of March 31, 2016. The due dates are as follows:

Advance due April 30, 2016                                  $500,000

Note due December 31, 2016                                 $102,527

The advance of $500,000 which was due on April 30 has been paid in full.

The note payable to a related party of $128,125 is payable with interest to a Director on December 31, 2016.

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10. ASSET RETIREMENT OBLIGATIONS

3 Months Ended

Mar. 31, 2016

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS

The following is a reconciliation of the asset retirement obligation liability through March 31, 2016:

Asset retirement obligation – December 31, 2014	$	35,951
Estimated liabilities recorded		-
Accretion Expense		1,107
Asset retirement obligation – March 31, 2015	$	37,058
Estimated liabilities recorded		-
Accretion Expense		819
Removal of ARO for wells sold		(1,152	)
Asset retirement obligation – June 30, 2015	$	36,725
Estimated liabilities recorded		-
Accretion Expense		819
Asset retirement obligation – September 30, 2015	$	37,544
Estimated liabilities recorded		-
Accretion Expense		747
Removal of ARO for wells sold		(9,208	)
Asset retirement obligation – December 31, 2015	$	29,083
Estimated liabilities recorded		-
Accretion Expense		747
Asset retirement obligation – March 31, 2016	$	29,830

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11. SUBSEQUENT EVENTS

3 Months Ended

Mar. 31, 2016

Subsequent Events [Abstract]

11. SUBSEQUENT EVENTS

Divestiture of Hunton Play Assets

Management has previously announced that they were seeking to divest certain of the Cimarron assets located in Logan and Kingfisher Counties, Oklahoma including lease rights and current production.  As of March 31, 2016 negotiations and documentation of the sale of the Company’s Cimarron assets in Oklahoma was nearing completion. The sale closed on April 29, 2016 with a sales price $750,000 and an effective date of May 1, 2016.

Legal Proceeding 

On May 4, 2016, Torchlight Energy Resources, Inc. and its subsidiary Torchlight Energy, Inc. filed a lawsuit in the 429th judicial district court in Collin County, Texas against Husky Ventures, Inc., Charles V. Long, April Glidewell, Silverstar of Nevada, Inc., Maximus Exploration, LLC, Atwood Acquisitions, LLC, Gastar Exploration Inc., J. Russell Porter, Michael A. Gerlich, Jerry R. Schuyler, and John M. Selser, Sr. 

Reference Item 2. Management’s Discussion and Analysis regarding the Hunton Play for further detail.

Asset Acquisition

Effective April 1, 2016, Torchlight Energy, Inc. acquired from McCabe Petroleum Corporation (Seller) a 66.66% working interest in approximately 12,000 acres in the Midland Basin in exchange for 1,500,000 warrants to purchase Torchlight common stock with an exercise price of $1.00 for five years and a back-in after payout of a 25% working interest to the seller. The Warrant provides that in the event an initial well is not drilled on the Oil and Gas Leases on or before July 10, 2016, that (i) if as of July 10, 2016 the Seller has exercised no portion of the Warrant, the number of Warrant Shares that the Seller will be able to acquire will be reduced to 500,000, (ii) if as of July 10, 2016 the Seller has exercised a portion of the Warrant in an amount less than 500,000 Warrant Shares, the number of Warrant Shares that the Seller will be able to acquire will be reduced to the difference between 500,000 and the number of Warrant Shares for which the Warrant has already been exercised, and (iii) if as of July 10, 2016 the Seller has exercised a portion of the Warrant in an amount more than 500,000 Warrant Shares, the number of Warrant Shares that the Seller will be able to acquire will be reduced to zero.

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3. SIGNIFICANT ACCOUNTING POLICIES (POLICIES)

3 Months Ended

Mar. 31, 2016

SIGNIFICANT ACCOUNTING POLICIES (POLICIES)

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, and Hudspeth Oil Corporation. 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 periodically reviews the credit worthiness of the financial institutions with which it does business. At times the Company’s cash balances are 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, notes payable to related party, and convertible promissory notes. The estimated fair values of cash, accounts receivable, accounts payable, and related party payables approximate the carrying amount due to the relatively short maturity of these instruments. The carrying amounts of the convertible 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.

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, 2016 and December 31, 2015 no valuation allowance was considered necessary.

As of December 31, 2015, the Company had a $419,839 account receivable from Husky Ventures for the estimated balance of the sale proceeds from the sale of the Chisholm Trail properties in fourth quarter, 2015. The Chisholm Trail properties were sold to Husky Ventures who then included them with the Husky interests in Chisholm Trail and then entered into a sale agreement with Gastar Exploration Inc. for the combined Torchlight and Husky interests. Receipt of the balance of the sale proceeds was subject to final determination of mineral lease classification and was to occur by February 28, 2016. The account receivable was not collected as of March 31, 2016.

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.

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 periods ended March 31, 2016 and March 31, 2015, the Company capitalized $41,912 and $205,341, 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 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 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 Company recognized impairment of $22,438,114 on its oil and gas properties during the three months ended June 30, 2015 and an additional impairment at December 31, 2015 of $3,236,009 for a total impairment adjustment for 2015 of $25,674,123. No impairment was recognized at March 31, 2016. 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. 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.

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.

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.

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.  The Company has not included potentially dilutive securities in the calculation of loss per share for any periods presented as the effects 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.

Recent accounting pronouncements

On August 27, 2014, the FASB issued ASU 2014-15, which provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of the Company’s ability to continue as a going concern within one year of the date the financial statements are issued. An entity must provide certain disclosures if conditions or events raise substantial doubt about the entity’s ability to continue as a going concern. The ASU applies to all entities and is effective for annual periods ending after December 15, 2016, and interim periods thereafter, with early adoption permitted.

In May 2014, the FASB issued ASU 2014-09 that introduces a new five-step revenue recognition model in which an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. This ASU also requires disclosures sufficient to enable users to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers, including qualitative and quantitative disclosures about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. This standard is effective for fiscal years beginning after December 15, 2017, including interim periods within that reporting period. The Company is currently evaluating the new guidance to determine the impact it will have on its consolidated financial statements.

In April 2014, the FASB issued ASU 2014-08, which includes amendments that change the requirements for reporting discontinued operations and require additional disclosures about discontinued operations. Under the new guidance, only disposals representing a strategic shift in operations - that is, a major effect on the organization’s operations and financial results should be presented as discontinued operations. Additionally, the ASU requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income, and expenses of discontinued operations. The new standard is effective in the first quarter of 2015 for public organizations with calendar year ends. Early adoption would be permitted for any annual or interim period for which an entity’s financial statements have not yet been made available for issuance. The adoption of this guidance is not expected to have an impact on the Company’s 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 May 16, 2016, the date of issuance of the financial statements. Subsequent events are disclosed in Note 11.

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6. STOCKHOLDERS' EQUITY (Tables)

3 Months Ended

Mar. 31, 2016

STOCKHOLDERS' EQUITY (TABLES)

Summary of warrant activity

Exercise		Expiration Date in
Price		2016		2017		2018		2019		2020		Total
$	0.50						800,000						800,000
$	0.70										425,000		425,000
$	1.00		-		150,000		-		212,525				362,525
$	1.08								37,500				37,500
$	1.40										1,704,346		1,704,346
$	1.57										3,750,000		3,750,000
$	1.73						100,000						100,000
$	1.75		1,135,714		-		-		-				1,135,714
$	1.79										225,000		225,000
$	1.80										850,000		850,000
$	2.00		936,071		126,000		1,696,380		-				2,758,451
$	2.03						2,000,000						2,000,000
$	2.09		-		-		2,800,000		-				2,800,000
$	2.23										911,330		911,330
$	2.29						120,000						120,000
$	2.31						500,000						500,000
$	2.50		100,000		-		-		80,779				180,779
$	2.82		-		-		38,174		-				38,174
$	3.00		100,000		-		-		-				100,000
$	3.50								15,000				15,000
$	4.50		-		-		-		700,000				700,000
$	5.00		8,391		210,000		-		-				218,391
$	6.00		-		-		577,501		327,675				905,176
$	7.00		-		-		-		700,000				700,000
			2,280,176		486,000		8,632,055		2,073,479		7,865,676		21,337,386

Assumptions used in calculating the fair value of the warrants

Risk-free interest rate	0.78%
Expected volatility of common stock	191% - 253%
Dividend yield	0.00%
Discount due to lack of marketability	20-30%
Expected life of warrant	3 years - 5 years

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7. CAPITALIZED COSTS (Tables)

3 Months Ended

Mar. 31, 2016

Capitalized Costs (Table):

Capitalized Costs (Table)

	2016			2015
Evaluated costs subject to amortization	$	19,693,962		$	24,177,851
Unevaluated costs		16,975,461			9,677,425
Accumulated impairment expense		(22,783,989	)		(22,783,989	)
Total capitalized costs		13,885,434			11,071,287
Less accumulated depreciation, depletion  and amortization		(4,632,250	)		(4,013,616	)
Net capitalized costs	$	9,253,184		$	7,057,671

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10. ASSET RETIREMENT OBLIGATIONS (Tables)

3 Months Ended

Mar. 31, 2016

ASSET RETIREMENT OBLIGATIONS (Tables)

Asset retirement obligation

Asset retirement obligation – December 31, 2014	$	35,951
Estimated liabilities recorded		-
Accretion Expense		1,107
Asset retirement obligation – March 31, 2015	$	37,058
Estimated liabilities recorded		-
Accretion Expense		819
Removal of ARO for wells sold		(1,152	)
Asset retirement obligation – June 30, 2015	$	36,725
Estimated liabilities recorded		-
Accretion Expense		819
Asset retirement obligation – September 30, 2015	$	37,544
Estimated liabilities recorded		-
Accretion Expense		747
Removal of ARO for wells sold		(9,208	)
Asset retirement obligation – December 31, 2015	$	29,083
Estimated liabilities recorded		-
Accretion Expense		747
Asset retirement obligation – March 31, 2016	$	29,830

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2. Going Concern (Details Narrative) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Going Concern Accumulated Losses
Accumulated deficit	$ (76,510,758)	$ (74,903,439)

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6. STOCKHOLDERS' EQUITY (Details)	3 Months Ended
	Mar. 31, 2016
Risk-free interest rate	0.78%
Dividend yield	0.00%
Minimum
Expected volatility of common stock	191.00%
Discount due to lack of marketability	20.00%
Expected life of warrant in years	3 years
Maximum
Expected volatility of common stock	253.00%
Discount due to lack of marketability	30.00%
Expected life of warrant in years	5 years

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7. CAPITALIZED COSTS (Details) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Presents the capitalized costs as follows:
Evaluated costs subject to amortization	$ 19,693,962	$ 24,177,851
Unevaluated costs	16,975,461	9,677,425
Impairment expense	(22,783,989)	(22,783,989)
Total capitalized costs	13,885,434	11,071,287
Less accumulated depreciation, depletion and amortization	(4,632,250)	(4,013,616)
Net capitalized costs	$ 9,253,184	$ 7,057,671

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8. INCOME TAXES (Details Narrative)	Mar. 31, 2016 USD ($)
Income Taxes Operating loss carryforwards
Net operating loss carryforwards	$ 25,142,099

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10. ASSET RETIREMENET OBLIGATION (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015
Asset Retiremenet Obligation Details
Asset retirement obligation	$ 29,083	$ 37,544	$ 36,725	$ 37,058	$ 35,951
Estimated liabilities recorded	0	0	0	0	0
Accretion expense	747	747	819	819	1,107
Removal of ARO for wells sold	0	(9,208)	0	(1,152)	0
Asset retirement obligation	$ 29,830	$ 29,083	$ 37,544	$ 36,725	$ 37,058