UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
X .Annual report under Section 13 or 15(d) of the Securities Exchange Act of 1934
For the fiscal year ended December 31, 2013.
.Transition report under Section 13 or 15(d) of the Securities Exchange Act of 1934 (No fee required)
For the transition period from _______ to _______.
Commission file number: 000-53473
Torchlight Energy Resources, Inc.
(Exact name of registrant in its charter)
Nevada
(State or other jurisdiction of incorporation or
Organization)
74-3237581
(I.R.S. Employer Identification No.)
5700 W. Plano Parkway, Suite 3600
Plano, Texas 75093
(Address of principal executive offices)
(214) 432-8002
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Exchange Act:
Common Stock ($0.001 Par Value)
(Title of Each Class)
NASDAQ
(Name of each exchange on which registered)
Securities registered pursuant to Section 12(g) of the Exchange Act:
None
Indicate by check mark if the registrant is a well-known seasoned issuer as defined in Rule 405 of the Securities Act. Yes . No X .
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes . No X .
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities
Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports),
and (2) has been subject to such filing requirements for the past 90 days. Yes X . No .
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be
contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of
this Form 10-K or any amendment to this Form 10-K. .
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. (Check one):
Large accelerated filer
Non-accelerated filer
.
. (Do not check if a smaller reporting company)
Accelerated filer
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 . No X .
At June 30, 2013, the aggregate market value of shares held by non-affiliates of the registrant (based upon 8,242,315 shares held by
non-affiliates on June 30, 2013) was approximately $16,402,207.
At March 20, 2014, there were 18,270,408 shares of the registrant’s common stock outstanding (the only class of common stock).
DOCUMENTS INCORPORATED BY REFERENCE
None.
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NOTE ABOUT FORWARD-LOOKING STATEMENTS
This Annual Report on Form 10-K 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, the following sections: Item 1 “Business,” Item 1A “Risk
Factors,” and Item 7 “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 Annual Report on Form 10-K, and in particular, the risks discussed under the caption “Risk Factors”
in Item 1A 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,” “our,” and similar terms include Torchlight Energy Resources, Inc. and its subsidiaries, unless
the context indicates otherwise.
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TABLE OF CONTENTS
PART I
Item 1.
Item 1A.
Item 1B.
Item 2.
Item 3.
Item 4.
Business
Risk Factors
Unresolved Staff Comments
Properties
Legal Proceedings
Mine Safety Disclosures
PART II
Item 5.
Item 6.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Selected Financial Data
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Quantitative and Qualitative Disclosures About Market Risk
Financial Statements and Supplementary Data
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
Controls and Procedures
Other Information
PART III
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
Item 15.
Directors, Executive Officer and Corporate Governance
Executive Compensation
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Certain Relationships and Related Transactions, and Director Independence
Principal Accountant Fees and Services
Exhibits, Financial Statement Schedules
Signatures
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ITEM 1. BUSINESS
Corporate History and Background
PART I
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 is an
exploration stage energy company, incorporated under the laws of the State of Nevada in June 2010. We are engaged in the acquisition,
exploration, exploitation and/or development of oil and natural gas properties in the United States. In addition to TEI, we also operate
our business through Torchlight Energy Operating, LLC, a Texas limited liability company and wholly-owned subsidiary.
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.”
Business Overview
Our business model is to focus on drilling and working interest programs within the United States that have a short window of
payback, a high internal rate of return and proven and bookable reserves. We currently have interests in four oil and gas projects, which
projects are described in more detail below in the section titled “Current Projects.” We anticipate being involved in multiple other oil
and gas projects moving forward, pending adequate funding. We anticipate acquiring exploration and development projects primarily as
a non-operating working interest partner, participating in drilling activities primarily on a basis proportionate to the working interest.
We intend to spread the risk associated with drilling programs by entering into a variety of programs in different fields with differing
economics.
Salient characteristics of the company include our industry relationships, leverage for prospect selection, anticipated diversity, both
geologically and geographically, cost control, partnering, and protection of capital exposure. Management believes opportunities exist
to identify and pursue relatively low risk projects at very attractive entry prices. These projects may be available from small operators in
financial distress, larger companies that need to share costs, and large producers who are consolidating their activities in other areas.
Management believes attractive entry prices and tight cost control will result in returns that are superior to those achieved by major
companies or small independents. An integral part of this strategy is the partnering of major activities. Such partnering will enable us
to acquire the talents of proven industry veterans, as needed, without affecting our long-term fixed overhead costs.
Key Business Attributes
Experienced People. We build on the expertise and experiences of our management team, including Thomas Lapinski, John Brda,
Willard McAndrew and Roger Wurtele. We will also receive guidance from outside advisors and will align with high quality
exploration and technical partners.
Project Focus. We are focusing on low risk exploitation projects by pursuing resources where commercial production has already been
established but where opportunity for additional and nearby development is indicated.
Lower Cost Structure. We will attempt to maintain the lowest possible cost structure, enabling the greatest margins and providing
opportunities for investment that would not be feasible for higher cost competitors for lower-risk, valuable projects.
Limit Capital Risks. Limited capital exposure is planned initially to add value to a project and determine its economic viability. Projects
are staged and have options before additional capital is invested. We will limit our exposure in any one project by participating at
reduced working interest levels, thereby being able to diversify with limited capital. Management has experience in successfully
managing risks of projects, finance, and value.
Partnering for Excellence. Partnering with highly select and experienced vendors provides ongoing access to external perspectives, new
project opportunities, specialization, networks, operations support, and the ability to test continuously for more effective and cost
efficient services.
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Project Focus
Generally, we will focus on lower risk exploitation projects (primarily for oil, although gas projects will be considered if the economics
are favorable). Projects are first identified, evaluated, and then we will secure a third party operating or financial partner. Subject to
overall availability of capital, our interest in large capital projects will be limited. Each opportunity will be investigated on a standalone
basis for both technical and financial merit. High risk exploration prospects are less favored than low risk exploitation. We will,
however, consider high risk-high reward exploration in connection with exploitation opportunities in a project that would reduce the
overall project economic risk. We will consider such projects on their individual merits, and we expect them to be a minor part of our
overall portfolio.
We will be actively seeking quality new investment opportunities to sustain our growth, and we believe we will have access to many
new projects. The sources of these opportunities will vary but all will be evaluated with the same criteria of technical and economic
factors. With a focus on development rather than higher risk exploration projects, it is expected that projects will come from the many
small producers who find themselves under-funded or over-extended and therefore vulnerable to price volatility. The financial ability to
respond quickly to opportunities will ensure a continuous stream of projects and will enable us to negotiate from a stronger position to
enhance value.
With emphasis on acquisitions and development strategies, the types of projects in which we will be involved vary from increased
production due to simple re-engineering of existing wellbores to step-out drilling, drilling horizontally, and extensions of known fields.
Recompletion of existing wellbores in new zones, development of deeper zones and detailing of structure and stratigraphic traps with
three-dimensional seismic and utilization of new technologies will all be part of our anticipated program. Our preferred type of projects
are in-fills to existing production with nearly immediate cash flow and/or adjacent or on trend to existing production. We will prefer
projects with moderate to low risk, unrecognized upside potential and geographic diversity.
Business Processes
We believe there are three principal business processes that we must follow to enable our operations to be profitable. Each major
business process offers the opportunity for a distinct partner or alliance as we grow. These processes are:
·
·
·
Investment Evaluation and Review;
Operations and Field Activities; and
Administrative and Finance Management.
Investment Evaluation and Review. This process is the key ingredient to our success. Recognition of quality investment opportunities
is the fuel that drives our engine. Broadly, this process includes the following activities: prospect acquisition, regional and local
geological and geophysical evaluations, data processing, economic analysis, lease acquisition and negotiations, permitting, and field
supervision. We expect these evaluation processes to be managed by our management. Expert or specific technical support will be
outsourced, as needed. Only if a project is taken to development, and only then, will additional staff be hired. New personnel will have
very specific responsibilities. We anticipate attractive investment opportunities to be presented from outside companies and from the
large informal community of geoscientists and engineers. Building a network of advisors is key to the pipeline of high quality
opportunities.
Operations and Field Activities. This process will begin following management approval of an investment. Well site supervision,
construction, drilling, logging, product marketing and transportation are examples of some activities. The present plan is that we will
prefer not to be the operator; we will farm-out sufficient interests to third parties that will be responsible for these operating activities.
We will provide personnel to monitor these activities and associated costs.
Administrative and Finance Management. This process will coordinate our initial structuring and capitalization, general operations and
accounting, reporting, audit, banking and cash management, regulatory agencies reporting and interaction, timely and accurate payment
of royalties, taxes, leases rentals, vendor accounts and performance management that includes budgeting and maintenance of financial
controls, and interface with legal counsel and tax and other financial and business advisors.
Current Projects
We currently have interests in five oil and gas projects, the Marcelina Creek Field Development in Wilson County, Texas, the Coulter
Field in Waller County, Texas, the Smokey Hills Prospect in McPherson County, Kansas, the Ring Energy Joint Venture in Southwest
Kansas and the Hunton play in partnership with Husky Ventures in Central Oklahoma.
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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 are presently producing a total of approximately 150
BOPD. The remaining well is to be a vertical development well at a location to be determined within the existing lease.
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.
Coulter Field
In January 2012, we entered into a farm-in agreement, titled the “Coulter Limited Partnership Agreement” (the “Coulter Agreement”),
with La Sal Energy, LLC (“La Sal”). La Sal owns a 100% working interest and a 75% net revenue interest in approximately 940 acres
of oil, gas and mineral leases in Waller County, Texas, on which the well known as “John Coulter #1-R” is located. This well is
adjacent to the Katy Field, located on its northwestern updip edge, which produces primarily from the Wilcox Sparks formation.
Pursuant to the Coulter Agreement, we acquired a 34% working interest and a 25.5% net revenue interest from La Sal’s interest in the
John Coulter #1-R for the purchase price of $350,000, which was to be applied to 100% of the costs of a fracture stimulation treatment
on the well. Under the agreement, we had options to purchase additional working interests up to a total of 45%. We exercised the first
option and purchased an additional 6% for $50,000, bringing our working interest to 40% and our net revenue interest to 30%. Our
option to purchase an additional 5% working interest can be exercised by the payment of $50,000 within 30 days of first commercial
production from the well. If commercial production is established, the net revenue split will be 80% to us and 20% to La Sal until net
revenue totals $437,500, after which the net revenue will be split according to the interests in the well. Expenses above the initial
$350,000 will be split according to the working interests in the well. Our total investment in the project, including fracture stimulation,
subsequent testing, purchase of additional interests and capitalized interest, amounted to $639,609 as of December 31, 2013.
The Coulter #1-R was a replacement well drilled by La Sal for the Coulter #1 which had mechanical problems caused by split casing.
In February 2012 the well was fracture stimulated. The results were encouraging and the well appears to be capable of commercial gas
production. However, the well is still recovering fluid and has not yet been hooked up to a nearby pipeline for production. The source
of the fluid has not been conclusively determined. It may be recovery of drilling and/or fracture stimulation fluid or may be entering the
wellbore from one or more downhole formations or an adjacent wellbore in the field. We are continuing to flow fluid from the well and
the well is periodically shut–in for pressure build up tests. We have cemented off the split casing in the Coulter #1 well and are
conducting tests to determine productivity. We have begun discussions with the gas gatherer in the area and are working on
completing the gas contract and the well. No activity has occurred in the fourth quarter as we continue to explore our options for this
property.
Smokey Hills Prospect, McPherson County, Kansas
In April 2013, we entered into an agreement to acquire certain assets of Xtreme Oil & Gas, Inc. of Plano, Texas (“Xtreme”). Included
in that agreement were the Smokey Hills Prospect in McPherson County, Kansas, the Cimarron Area Hunton Project in Logan County,
Oklahoma, and an interest in a salt water disposal facility in Seminole, Oklahoma. Total consideration for all the properties was $1.6
million.
The Smokey Hills acquisition included approximately 10,000 gross acres and a well, the Hoffman 1-H within the greater Lindsborg
Field area. Our working interest is nearly 18%. Wells had been drilled vertically in the 1960’s to present at depths of less than 4,000
feet looking for production from Mississippian carbonated fractured reservoirs. The Hoffman well was drilled laterally 4,200 feet and
fracking had not been completed at the time of our acquisition of the project. Core analysis and logs indicated good porosity at 14 to
22%. Following our acquisition, the well was hydraulically fractured, but the results were disappointing. We presently are evaluating
our next efforts to monetize the investment of nearly $940,000. Allocated costs are high due to the large acreage position. We are
planning to drill a ten well program late Q2 or early Q3 to evaluate the possibility of producing the formation in a traditional vertical
method. Of the 800 wells of interest in the area, all were produced vertically and in economic quantities.
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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 currently underway.
Hunton Play, Central Oklahoma
The Xtreme transaction also included the acquisition of three Hunton wells, the Hancock, Robinson and Lenhart. The Hancock and
Robinson are producing wells but have small working interests of 1% and ¼ of 1%, respectively. The Lenhart well is a 62% working
interest and was being prepared for a fracture stimulation when it was previously damaged, prior to our acquisition, by the service
contractor. The well bore at the Hunton level has an irretrievable pipe in the hole and cannot be used to produce from the Hunton.
Although Xtreme won the litigation against the contractor, he failed to pay for the replacement of the well bore, and Xtreme was
responsible for costs primarily to Baker-Hughes for work done on the well. We took responsibility for those charges and negotiated a
settlement of approximately $600,000.
Subsequent to the above, we have identified a shallow sandstone that could potentially be productive. As previously planned, we tested
this formation, and although there were hydrocarbons present, they are not in sufficient quantities to be economic. Therefore, we have
elected to plug and abandon this well bore.
While doing the due diligence for the above projects, we met with the operator of the Hancock and Robinson well, Husky Ventures of
Oklahoma City. At that time Husky had completed 17 successful wells in the Hunton formation and was expanding its acreage
position. We were able to negotiate a 15% working interest in approximately 3,700 acres in the Cimarron Area of Logan County in
May 2013. Within a week the Boeckman #1-H well was spud and was subsequently completed and fracture stimulated in July. At
present, the Boeckman well continues to produce at a rate of 85 barrels of oil per day and 450 thousand cubic feet of gas per day. We
acquired a working interest in the Boeckman #1-H well and subsequently sold part of our ownership in the Boeckman well for
$990,000. The purchaser executed a promissory note dated May 1, 2013 for the purchase. We have collected the balance in full as of the
date of these financial statements. We agreed to a preferential payout to the purchaser equal to 50% of his acquired interest. The
agreement was amended in the first quarter of 2014 to include our agreement to advance funds under a note receivable from the
purchaser to be repaid from the purchaser’s revenue preference subsequent to October, 2014. Revenue payable to the investor based on
revenue to December 31, 2013 has been accrued in the accompanying financial statements.
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. This acquisition will allow us to participate in 60+ gross wells in the coming two
years. This acquisition along with the previous acreage position in the Cimarron Trail will give us 80+ drilling locations in the entire
play. It is our intention to continue to increase this position through advanced leasing and forced pooling.
At the end of November 2013, in addition to the producing Boeckman well, our operator Husky Ventures Inc. was actively drilling four
wells in which we owned an interest. Two of these wells, we financed by a third party, whereby they paid 100% of the costs and we
retained a small ORRI and a small working interest. The second two, we paid our AFE directly and we are participating in these wells
based on our pro-rated working interest. In the fourth quarter of 2013 we entered into our 3rd Area of Mutual Interest (AMI) with
Husky Ventures, the Viking Prospect. This AMI covers four townships in size and currently there is over 5,000 acres under lease. We
own a 25% Working Interest in the project. Leasing is continuing monthly and recently, Husky has spud the first two wells in the
AMI. In January of 2014, we again elected to continue to expand in the Hunton Play with Husky Ventures. We again contracted for a
25% Working Interest in an AMI consisting of eight townships in South Central Oklahoma. There is an active leasing program in this
AMI as well with over 5,000 acres under lease. We expect to spud our first well in this AMI by July of 2014. Lastly, in February of
2014, we picked up a 10% Working Interest in a well in the Prairie Grove AMI that is currently drilling. We picked up this interest
from a non-consenting third party who elected not to participate in the well. Currently, we are actively producing, drilling, fracking, or
flowing back in twenty-two wells across all of our AMI’s with Husky Ventures.
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Salt Water Disposal Facility
As part of the Xtreme transaction we also acquired a 22.5% net royalty on a salt water disposal facility in Seminole, Oklahoma. No
value was placed on the facility due to operational uncertainty. The facility which was newly commissioned in January 2013 is a state
of the art disposal facility which can handle 20,000 barrels of produced and injected fluids per day. Oil and gas wells produce large
quantities of saltwater that must be trucked and disposed of at a cost to the producer. During the second quarter, the facility averaged
only approximately 2,000 barrels of fluids per day. But with increasing activity in the area, we anticipate that volume increasing in the
future. With only a royalty, we have no working interest and are therefore not responsible for any operating expenses. We do however
have the right to a working interest of 37.5% when the original investors in the facility receive a payout of their investment.
Project Prospects
We have an ongoing process to identify specific projects that we will consider investing in, pending our ability to obtain adequate
funding. We have not yet conducted thorough due diligence on any project prospect, nor had we made any significant commitments on
any new projects as of December 31, 2013, beyond the continued involvement and expansion of our current projects with our partners.
There is no assurance we will choose to invest in any of these projects, if and when adequate funding becomes available.
Industry and Business Environment
Our industry and its business environment have been altered during the last decade and in particular since Torchlight was founded in
early 2010. Population in the US has increased by nearly 40 million people in the last decade. Yet our demand for crude oil has
remained relatively constant at slightly less than 20 million barrels per day. When Torchlight was founded in 2010 over one-half of US
crude oil daily requirements were imported; with a significant amount from non-North American sources. The industry was also just
beginning to see production from shale resource plays make an impact and a “land rush” to acquire mineral leases was exploding. The
“Shale Gale”, as some in the industry call it was just starting to gain momentum. In particular resource plays in the Bakken formation
of North Dakota, the Eagle Ford formation in Texas and the Marcelius of the Eastern U.S. drew industry attention. Acreage costs
skyrocketed and huge deals such as the Marathon Oil-Hillcorp acquisition made headlines.
Since then, the industry has steadily increased the number of wells drilled and improved completion techniques, increasing production,
and lowered capital requirements. The Bakken formation and the Eagle Ford formation now each produce 1 million barrels of oil per
day to add to our domestic supply. With additional secure domestic supply this has allowed the US to significantly reduce its reliance
on non-North American crude sources, namely the Middle East.
Industry sources that look at long term planning forecast that the “Shale Gale” could provide secure domestic supplies well into the mid
21st century and further reduce our need to import non-North American crude. Added to this is the Keystone Pipeline Project from
Canada which is under construction in several states. It will bring crude oil extracted from tar sands in Alberta Province to US
refineries. Federal approval is needed however to make the international link between the US and Canada. This flood of activity in the
resource plays provides opportunities to Torchlight. The conventional plays, or exploitation plays such as our Hunton projects are
avoided by the resource players creating a vacuum into which we can selectively locate and exploit at reasonable costs. Projects in plays
where production has previously been proven, infrastucture exists and entry costs are modest will provide Torchlight a platform for
additional growth in the future. Our projects in the Hunton in Oklahoma, the Mississippian formations in Kansas, and the Marcelina
Creek block in Texas are examples of such opportunities. Additional opportunities come as leases that had not been drilled come
available. With the land rush by companies to acquire lease several years ago not all could be drilled and converted to production, they
will create an inventory of leases from which to select. As for natural gas, Torchlight’s focus has been on liquids-rich projects but
should the opportunity present itself for a gas project it will be considered. Natural gas resource plays such as the Marcelius in the
Eastern US provide huge resource potential in the densely populated area. Gas prices parallel weather and with the cold winter of 2013
and the subsequent very cold weather of early 2014 gas prices have escalated to unprecedented amounts. Longer-term gas production
will be increasing as the resource plays are drilled. There is now the opportunity for the industry to develop an export strategy for the
gas which would receive a short-term spike in prices since world gas prices are more than 50 percent greater than domestic gas prices.
However we believe that in the longer term prices will stabilize much as they are now with spikes in prices based on weather. In
summary, we believe that demand in the US will show only slight growth as more efficient auto engines and alternative fuels offset
population growth. Prices for crude oil will be reasonably stable but subject to external international incidents. Increased gas markets,
such as exports may create opportunites for small gas projects in which Torchlight could participate. As the larger plays keep their
focus on the resource plays the opportunities in conventional plays will remain, providing Torchlight with a pipeline of projects to
evaluate. Lastly should the opportunity to expand into the resource plays we will have the benefit, without the cost, of the experience
the industry has gained in the last years.
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Competition
The oil and natural gas industry is intensely competitive, and we will compete with numerous other companies engaged in the
exploration and production of oil and gas. Some of these companies have substantially greater resources than we have. Not only do
they explore for and produce oil and natural gas, but also many carry on midstream and refining operations and market petroleum and
other products on a regional, national or worldwide basis. The operations of other companies may be able to pay more for exploratory
prospects and productive oil and natural gas properties. They may also have more resources to define, evaluate, bid for and purchase a
greater number of properties and prospects than our financial or human resources permit.
Our larger or integrated competitors may have the resources to be better able to absorb the burden of current and future federal, state,
and local laws and regulations more easily than we can, which would adversely affect our competitive position. Our ability to locate
reserves and acquire interests in properties in the future will be dependent upon our ability and resources to evaluate and select suitable
properties and consummate transactions in this highly competitive environment. In addition, we may be at a disadvantage in producing
oil and natural gas properties and bidding for exploratory prospects because we have fewer financial and human resources than other
companies in our industry. Should a larger and better financed company decide to directly compete with us, and be successful in its
efforts, our business could be adversely affected.
Marketing and Customers
The market for oil and natural gas that we will produce depends on factors beyond our control, including the extent of domestic
production and imports of oil and natural gas, the proximity and capacity of natural gas pipelines and other transportation facilities,
demand for oil and natural gas, the marketing of competitive fuels and the effects of state and federal regulation. The oil and gas
industry also competes with other industries in supplying the energy and fuel requirements of industrial, commercial and individual
consumers.
Our oil production is expected to be sold at prices tied to the spot oil markets. Our natural gas production is expected to be sold under
short-term contracts and priced based on first of the month index prices or on daily spot market prices. We will rely on our operating
partners to market and sell our production.
Governmental Regulation and Environmental Matters
Our operations are subject to various rules, regulations and limitations impacting the oil and natural gas exploration and production
industry as a whole.
Regulation of Oil and Natural Gas Production
Our oil and natural gas exploration, production and related operations, when developed, will be subject to extensive rules and
regulations promulgated by federal, state, tribal and local authorities and agencies. Certain states may also have statutes or regulations
addressing conservation matters, including provisions for the unitization or pooling of oil and natural gas properties, the establishment
of maximum rates of production from wells, and the regulation of spacing, plugging and abandonment of such wells. Failure to comply
with any such rules and regulations can result in substantial penalties. The regulatory burden on the oil and gas industry will most
likely increase our cost of doing business and may affect our profitability. Although we believe we are currently in substantial
compliance with all applicable laws and regulations, because such rules and regulations are frequently amended or reinterpreted, we are
unable to predict the future cost or impact of complying with such laws. Significant expenditures may be required to comply with
governmental laws and regulations and may have a material adverse effect on our financial condition and results of operations.
Environmental Matters
Our operations and properties are and will be subject to extensive and changing federal, state and local laws and regulations relating to
environmental protection, including the generation, storage, handling, emission, transportation and discharge of materials into the
environment, and relating to safety and health. The recent trend in environmental legislation and regulation generally is toward stricter
standards, and this trend will likely continue. These laws and regulations may:
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require the acquisition of a permit or other authorization before construction or drilling commences and for certain other
activities;
limit or prohibit construction, drilling and other activities on certain lands lying within wilderness and other protected
areas; and
impose substantial liabilities for pollution resulting from operations;
restrict certain areas from fracking and other stimulation techniques
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The permits required for our operations may be subject to revocation, modification and renewal by issuing authorities. Governmental
authorities have the power to enforce their regulations, and violations are subject to fines or injunctions, or both. In the opinion of
management, we are and will be in substantial compliance with current applicable environmental laws and regulations, and have no
material commitments for capital expenditures to comply with existing environmental requirements. Nevertheless, changes in existing
environmental laws and regulations or in interpretations thereof could have a significant impact on our company, as well as the oil and
natural gas industry in general.
The Comprehensive Environmental, Response, Compensation, and Liability Act (“CERCLA”) and comparable state statutes impose
strict, joint and several liability on owners and operators of sites and on persons who disposed of or arranged for the disposal of
“hazardous substances” found at such sites. It is not uncommon for the neighboring landowners and other third parties to file claims
for personal injury and property damage allegedly caused by the hazardous substances released into the environment. The Federal
Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes govern the disposal of “solid waste” and “hazardous
waste” and authorize the imposition of substantial fines and penalties for noncompliance. Although CERCLA currently excludes
petroleum from its definition of “hazardous substance,” state laws affecting our operations may impose clean-up liability relating to
petroleum and petroleum related products. In addition, although RCRA classifies certain oil field wastes as “non-hazardous,” such
exploration and production wastes could be reclassified as hazardous wastes thereby making such wastes subject to more stringent
handling and disposal requirements.
The Endangered Species Act (“ESA”) seeks to ensure that activities do not jeopardize endangered or threatened animal, fish and plant
species, nor destroy or modify the critical habitat of such species. Under ESA, exploration and production operations, as well as
actions by federal agencies, may not significantly impair or jeopardize the species or its habitat. ESA provides for criminal penalties for
willful violations of the Act. Other statutes that provide protection to animal and plant species and that may apply to our operations
include, but are not necessarily limited to, the Fish and Wildlife Coordination Act, the Fishery Conservation and Management Act, the
Migratory Bird Treaty Act and the National Historic Preservation Act. Although we believe that our operations will be in substantial
compliance with such statutes, any change in these statutes or any reclassification of a species as endangered could subject our company
to significant expenses to modify our operations or could force our company to discontinue certain operations altogether.
Climate Change
Significant studies and research have been devoted to climate change and global warming, and climate change has developed into a
major political issue in the United States and globally. Certain research suggests that greenhouse gas emissions contribute to climate
change and pose a threat to the environment. Recent scientific research and political debate has focused in part on carbon dioxide and
methane incidental to oil and natural gas exploration and production. Many states and the federal government have enacted legislation
directed at controlling greenhouse gas emissions, and future legislation and regulation could impose additional restrictions or
requirements in connection with our drilling and production activities and favor use of alternative energy sources, which could affect
operating costs and demand for oil products. As such, our business could be materially adversely affected by domestic and
international legislation targeted at controlling climate change.
Employees
We currently have six full time employees and no part time employees. We anticipate adding additional employees, when adequate
funds are available, and using independent contractors, consultants, attorneys and accountants as necessary, to complement services
rendered by our employees. We presently have independent technical professionals under consulting agreements who are available to
us on an as needed basis.
Research and Development
We did not spend any funds on research and development activities during years ended December 31, 2013 and 2012.
ITEM 1A. RISK FACTORS
An investment in us involves a high degree of risk and is suitable only for prospective investors with substantial financial means who
have no need for liquidity and can afford the entire loss of their investment in us. Prospective investors should carefully consider the
following risk factors, in addition to the other information contained in this report.
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Risks Related to the Company and the Industry
We have a limited operating history, and may not be successful in developing profitable business operations.
We have a limited operating history. Our business operations must be considered in light of the risks, expenses and difficulties
frequently encountered in establishing a business in the oil and natural gas industries. As of the date of this report, we have generated
limited revenues and have limited assets. We have an insufficient history at this time on which to base an assumption that our business
operations will prove to be successful in the long-term. Our future operating results will depend on many factors, including:
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our ability to raise adequate working capital;
the success of our development and exploration;
the demand for natural gas and oil;
the level of our competition;
our ability to attract and maintain key management and employees; and
our ability to efficiently explore, develop, produce or acquire sufficient quantities of marketable natural gas or oil in a
highly competitive and speculative environment while maintaining quality and controlling costs.
To achieve profitable operations in the future, we must, alone or with others, successfully manage the factors stated above, as well as
continue to develop ways to enhance our production efforts, when commenced. Despite our best efforts, we may not be successful in
our exploration or development efforts, or obtain required regulatory approvals. There is a possibility that some, or all, of the wells in
which we obtain interests may never produce oil or natural gas.
We have limited capital and will need to raise additional capital in the future.
We do not currently have sufficient capital to fund both our continuing operations and our planned growth. We will require additional
capital to continue to grow our business via acquisitions and to further expand our exploration and development programs. We may be
unable to obtain additional capital when required. Future acquisitions and future exploration, development, production and marketing
activities, as well as our administrative requirements (such as salaries, insurance expenses and general overhead expenses, as well as
legal compliance costs and accounting expenses) will require a substantial amount of additional capital and cash flow.
We may pursue sources of additional capital through various financing transactions or arrangements, including joint venturing of
projects, debt financing, equity financing or other means. We may not be successful in identifying suitable financing transactions in the
time period required or at all, and we may not obtain the capital we require by other means. If we do not succeed in raising additional
capital, our resources may not be sufficient to fund our planned operations.
Our ability to obtain financing, if and when necessary, may be impaired by such factors as the capital markets (both generally and in the
oil and gas industry in particular), our limited operating history, the location of our oil and natural gas properties and prices of oil and
natural gas on the commodities markets (which will impact the amount of asset-based financing available to us, if any) and the departure
of key employees. Further, if oil or natural gas prices on the commodities markets decline, our future revenues, if any, will likely
decrease and such decreased revenues may increase our requirements for capital. If the amount of capital we are able to raise from
financing activities, together with our revenues from operations, is not sufficient to satisfy our capital needs (even to the extent that we
reduce our operations), we may be required to cease our operations, divest our assets at unattractive prices or obtain financing on
unattractive terms.
Any additional capital raised through the sale of equity may dilute the ownership percentage of our stockholders. Raising any such
capital could also result in a decrease in the fair market value of our equity securities because our assets would be owned by a larger
pool of outstanding equity. The terms of securities we issue in future capital transactions may be more favorable to our new investors,
and may include preferences, superior voting rights and the issuance of other derivative securities, and issuances of incentive awards
under equity employee incentive plans, which may have a further dilutive effect.
We may incur substantial costs in pursuing future capital financing, including investment banking fees, legal fees, accounting fees,
securities law compliance fees, printing and distribution expenses and other costs. We may also be required to recognize non-cash
expenses in connection with certain securities we may issue, which may adversely impact our financial condition.
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There is substantial doubt about our ability to continue as a going concern
At December 31, 2013, we had not yet achieved profitable operations, had accumulated losses of $15,840,959 since our inception, and
expect to incur further losses in the development of our business, all of which casts substantial doubt about our ability to continue as a
going concern. Our ability to continue as a going concern is dependent upon our ability to generate future profitable operations and/or
to obtain the necessary financing to meet our obligations and repay our liabilities arising from normal business operations when they
come due. Management's plan to address our ability to continue as a going concern includes: (1) obtaining debt or equity funding from
private placement or institutional sources; (2) obtaining loans from financial institutions, where possible, or (3) participating in joint
venture transactions with third parties. Although management believes that it will be able to obtain the necessary funding to allow us to
remain a going concern through the methods discussed above, there can be no assurances that such methods will prove successful. The
accompanying financial statements do not include any adjustments that might result from the outcome of this uncertainty.
As a non-operator, our development of successful operations relies extensively on third-parties who, if not successful, could
have a material adverse effect on our results of operation.
We expect to primarily participate in wells operated by third-parties. As a result, we will not control the timing of the development,
exploitation, production and exploration activities relating to leasehold interests we acquire. We do, however, have certain rights as
granted in our Joint Operating Agreements that allow us a certain degree of freedom such as, but not limited to, the ability to propose
the drilling of wells. If our drilling partners are not successful in such activities relating to our leasehold interests, or are unable or
unwilling to perform, our financial condition and results of operation could have an adverse material effect.
Further, financial risks are inherent in any operation where the cost of drilling, equipping, completing and operating wells is shared by
more than one person. We could be held liable for the joint activity obligations of the operator or other working interest owners such as
nonpayment of costs and liabilities arising from the actions of the working interest owners. In the event the operator or other working
interest owners do not pay their share of such costs, we would likely have to pay those costs. In such situations, if we were unable to
pay those costs, there could be a material adverse effect to our financial position.
Because of the speculative nature of oil and gas exploration, there is risk that we will not find commercially exploitable oil and
gas and that our business will fail.
The search for commercial quantities of oil and natural gas as a business is extremely risky. We cannot provide investors with any
assurance that any properties in which we obtain a mineral interest will contain commercially exploitable quantities of oil and/or gas.
The exploration expenditures to be made by us may not result in the discovery of commercial quantities of oil and/or gas. Problems
such as unusual or unexpected formations or pressures, premature declines of reservoirs, invasion of water into producing formations
and other conditions involved in oil and gas exploration often result in unsuccessful exploration efforts. If we are unable to find
commercially exploitable quantities of oil and gas, and/or we are unable to commercially extract such quantities, we may be forced to
abandon or curtail our business plan, and as a result, any investment in us may become worthless.
Strategic relationships upon which we may rely are subject to change, which may diminish our ability to conduct our
operations.
Our ability to successfully acquire oil and gas interests, to build our reserves, to participate in drilling opportunities and to identify and
enter into commercial arrangements with customers will depend on developing and maintaining close working relationships with
industry participants and our ability to select and evaluate suitable properties and to consummate transactions in a highly competitive
environment. These realities are subject to change and our inability to maintain close working relationships with industry participants or
continue to acquire suitable property may impair our ability to execute our business plan.
To continue to develop our business, we will endeavor to use the business relationships of our management to enter into strategic
relationships, which may take the form of joint ventures with other private parties and contractual arrangements with other oil and gas
companies, including those that supply equipment and other resources that we will use in our business. We may not be able to establish
these strategic relationships, or if established, we may not be able to maintain them. In addition, the dynamics of our relationships with
strategic partners may require us to incur expenses or undertake activities we would not otherwise be inclined to in order to fulfill our
obligations to these partners or maintain our relationships. If our strategic relationships are not established or maintained, our business
prospects may be limited, which could diminish our ability to conduct our operations.
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The price of oil and natural gas has historically been volatile. If it were to decrease substantially, our projections, budgets and revenues
would be adversely affected, potentially forcing us to make changes in our operations.
Our future financial condition, results of operations and the carrying value of any oil and natural gas interests we acquire will depend primarily
upon the prices paid for oil and natural gas production. Oil and natural gas prices historically have been volatile and likely will continue to be
volatile in the future, especially given current world geopolitical conditions. Our cash flows from operations are highly dependent on the prices that
we receive for oil and natural gas. This price volatility also affects the amount of our cash flows available for capital expenditures and our ability
to borrow money or raise additional capital. The prices for oil and natural gas are subject to a variety of additional factors that are beyond our
control. These factors include:
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the level of consumer demand for oil and natural gas;
the domestic and foreign supply of oil and natural gas;
the ability of the members of the Organization of Petroleum Exporting Countries ("OPEC") to agree to and maintain oil price and
production controls;
the price of foreign oil and natural gas;
domestic governmental regulations and taxes;
the price and availability of alternative fuel sources;
weather conditions;
market uncertainty due to political conditions in oil and natural gas producing regions, including the Middle East; and
worldwide economic conditions.
These factors as well as the volatility of the energy markets generally make it extremely difficult to predict future oil and natural gas price
movements with any certainty. Declines in oil and natural gas prices affect our revenues, and could reduce the amount of oil and natural gas that
we can produce economically. Accordingly, such declines could have a material adverse effect on our financial condition, results of operations, oil
and natural gas reserves and the carrying values of our oil and natural gas properties. If the oil and natural gas industry experiences significant price
declines, we may be unable to make planned expenditures, among other things. If this were to happen, we may be forced to abandon or curtail our
business operations, which would cause the value of an investment in us to decline in value, or become worthless.
Because of the inherent dangers involved in oil and gas operations, there is a risk that we may incur liability or damages as we conduct
our business operations, which could force us to expend a substantial amount of money in connection with litigation and/or a settlement.
The oil and natural gas business involves a variety of operating hazards and risks such as well blowouts, pipe failures, casing collapse, explosions,
uncontrollable flows of oil, natural gas or well fluids, fires, spills, pollution, releases of toxic gas and other environmental hazards and risks. These
hazards and risks could result in substantial losses to us from, among other things, injury or loss of life, severe damage to or destruction of property,
natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigation and penalties and
suspension of operations. In addition, we may be liable for environmental damages caused by previous owners of property purchased and leased by
us. As a result, substantial liabilities to third parties or governmental entities may be incurred, the payment of which could reduce or eliminate the
funds available for exploration, development or acquisitions or result in the loss of our properties and/or force us to expend substantial monies in
connection with litigation or settlements. We currently have no insurance to cover such losses and liabilities, and even if insurance is obtained, there
can be no assurance that it will be adequate to cover any losses or liabilities. We cannot predict the availability of insurance or the availability of
insurance at premium levels that justify our purchase. The occurrence of a significant event not fully insured or indemnified against could
materially and adversely affect our financial condition and operations. We may elect to self-insure if management believes that the cost of
insurance, although available, is excessive relative to the risks presented. In addition, pollution and environmental risks generally are not fully
insurable. The occurrence of an event not fully covered by insurance could have a material adverse effect on our financial condition and results of
operations, which could lead to any investment in us becoming worthless.
The market for oil and gas is intensely competitive, and competition pressures could force us to abandon or curtail our business plan.
The market for oil and gas exploration services is highly competitive, and we only expect competition to intensify in the future. Numerous well-
established companies are focusing significant resources on exploration and are currently competing with us for oil and gas opportunities. Other oil
and gas companies may seek to acquire oil and gas leases and properties that we have targeted. Additionally, other companies engaged in our line
of business may compete with us from time to time in obtaining capital from investors. Competitors include larger companies which, in particular,
may have access to greater resources, may be more successful in the recruitment and retention of qualified employees and may conduct their own
refining and petroleum marketing operations, which may give them a competitive advantage. Actual or potential competitors may be strengthened
through the acquisition of additional assets and interests. Additionally, there are numerous companies focusing their resources on creating fuels
and/or materials which serve the same purpose as oil and gas, but are manufactured from renewable resources.
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As a result, there can be no assurance that we will be able to compete successfully or that competitive pressures will not adversely affect
our business, results of operations and financial condition. If we are not able to successfully compete in the marketplace, we could be
forced to curtail or even abandon our current business plan, which could cause any investment in us to become worthless.
We may not be able to successfully manage our growth, which could lead to our inability to implement our business plan.
Our growth is expected to place a significant strain on our managerial, operational and financial resources, especially considering that
we currently only have a small number of executive officers, employees and advisors. Further, as we enter into additional contracts, we
will be required to manage multiple relationships with various consultants, businesses and other third parties. These requirements will
be exacerbated in the event of our further growth or in the event that the number of our drilling and/or extraction operations increases.
There can be no assurance that our systems, procedures and/or controls will be adequate to support our operations or that our
management will be able to achieve the rapid execution necessary to successfully implement our business plan. If we are unable to
manage our growth effectively, our business, results of operations and financial condition will be adversely affected, which could lead
to us being forced to abandon or curtail our business plan and operations.
Our operations are heavily dependent on current environmental regulation, changes in which we cannot predict.
Oil and natural gas activities that we will engage in, including production, processing, handling and disposal of hazardous materials,
such as hydrocarbons and naturally occurring radioactive materials (if any), are subject to stringent regulation. We could incur
significant costs, including cleanup costs resulting from a release of hazardous material, third-party claims for property damage and
personal injuries fines and sanctions, as a result of any violations or liabilities under environmental or other laws. Changes in or more
stringent enforcement of environmental laws could force us to expend additional operating costs and capital expenditures to stay in
compliance.
Various federal, state and local laws regulating the discharge of materials into the environment, or otherwise relating to the protection of
the environment, directly impact oil and gas exploration, development and production operations, and consequently may impact our
operations and costs. These regulations include, among others, (i) regulations by the Environmental Protection Agency and various state
agencies regarding approved methods of disposal for certain hazardous and non-hazardous wastes; (ii) the Comprehensive
Environmental Response, Compensation, and Liability Act, Federal Resource Conservation and Recovery Act and analogous state laws
which regulate the removal or remediation of previously disposed wastes (including wastes disposed of or released by prior owners or
operators), property contamination (including groundwater contamination), and remedial plugging operations to prevent future
contamination; (iii) the Clean Air Act and comparable state and local requirements which may result in the gradual imposition of certain
pollution control requirements with respect to air emissions from our operations; (iv) the Oil Pollution Act of 1990 which contains
numerous requirements relating to the prevention of and response to oil spills into waters of the United States; (v) the Resource
Conservation and Recovery Act which is the principal federal statute governing the treatment, storage and disposal of hazardous wastes;
and (vi) state regulations and statutes governing the handling, treatment, storage and disposal of naturally occurring radioactive material.
Management believes that we will be in substantial compliance with applicable environmental laws and regulations. To date, we have
not expended any amounts to comply with such regulations, and management does not currently anticipate that future compliance will
have a materially adverse effect on our consolidated financial position, results of operations or cash flows. However, if we are deemed
to not be in compliance with applicable environmental laws, we could be forced to expend substantial amounts to be in compliance,
which would have a materially adverse effect on our financial condition. If this were to happen, any investment in us could be lost.
Our estimates of the volume of reserves could have flaws, or such reserves could turn out not to be commercially extractable.
As a result, our future revenues and projections could be incorrect.
Estimates of reserves and of future net revenues prepared by different petroleum engineers may vary substantially depending, in part, on
the assumptions made and may be subject to adjustment either up or down in the future. Our actual amounts of production, revenue,
taxes, development expenditures, operating expenses, and quantities of recoverable oil and gas reserves may vary substantially from the
estimates. Oil and gas reserve estimates are necessarily inexact and involve matters of subjective engineering judgment. In addition, any
estimates of our future net revenues and the present value thereof are based on assumptions derived in part from historical price and cost
information, which may not reflect current and future values, and/or other assumptions made by us that only represent our best
estimates. If these estimates of quantities, prices and costs prove inaccurate, we may be unsuccessful in expanding our oil and gas
reserves base with our acquisitions. Additionally, if declines in and instability of oil and gas prices occur, then write downs in the
capitalized costs associated with any oil and gas assets we obtain may be required. Because of the nature of the estimates of our reserves
and estimates in general, we can provide no assurance that reductions to our estimated proved oil and gas reserves and estimated future
net revenues will not be required in the future, and/or that our estimated reserves will be present and/or commercially extractable. If our
reserve estimates are incorrect, the value of our common stock could decrease and we may be forced to write down the capitalized costs
of our oil and gas properties.
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Decommissioning costs are unknown and may be substantial. Unplanned costs could divert resources from other projects.
We may become responsible for costs associated with abandoning and reclaiming wells, facilities and pipelines which we use for
production of oil and natural gas reserves. Abandonment and reclamation of these facilities and the costs associated therewith is often
referred to as “decommissioning.” We accrue a liability for decommissioning costs associated with our wells, but have not established
any cash reserve account for these potential costs in respect of any of our properties. If decommissioning is required before economic
depletion of our properties or if our estimates of the costs of decommissioning exceed the value of the reserves remaining at any
particular time to cover such decommissioning costs, we may have to draw on funds from other sources to satisfy such costs. The use
of other funds to satisfy such decommissioning costs could impair our ability to focus capital investment in other areas of our business.
We may have difficulty distributing production, which could harm our financial condition.
In order to sell the oil and natural gas that we are able to produce, if any, the operators of the wells we obtain interests in may have to
make arrangements for storage and distribution to the market. We will rely on local infrastructure and the availability of transportation
for storage and shipment of our products, but infrastructure development and storage and transportation facilities may be insufficient for
our needs at commercially acceptable terms in the localities in which we operate. This situation could be particularly problematic to the
extent that our operations are conducted in remote areas that are difficult to access, such as areas that are distant from shipping and/or
pipeline facilities. These factors may affect our and potential partners’ ability to explore and develop properties and to store and
transport oil and natural gas production, increasing our expenses.
Furthermore, weather conditions or natural disasters, actions by companies doing business in one or more of the areas in which we will
operate, or labor disputes may impair the distribution of oil and/or natural gas and in turn diminish our financial condition or ability to
maintain our operations.
Our business will suffer if we cannot obtain or maintain necessary licenses.
Our operations will require licenses, permits and in some cases renewals of licenses and permits from various governmental authorities.
Our ability to obtain, sustain or renew such licenses and permits on acceptable terms is subject to change in regulations and policies and
to the discretion of the applicable governments, among other factors. Our inability to obtain, or our loss of or denial of extension of,
any of these licenses or permits could hamper our ability to produce revenues from our operations.
Challenges to our properties may impact our financial condition.
Title to oil and gas interests is often not capable of conclusive determination without incurring substantial expense. While we intend to
make appropriate inquiries into the title of properties and other development rights we acquire, title defects may exist. In addition, we
may be unable to obtain adequate insurance for title defects, on a commercially reasonable basis or at all. If title defects do exist, it is
possible that we may lose all or a portion of our right, title and interests in and to the properties to which the title defects relate. If our
property rights are reduced, our ability to conduct our exploration, development and production activities may be impaired. To mitigate
title problems, common industry practice is to obtain a title opinion from a qualified oil and gas attorney prior to the drilling operations
of a well.
We rely on technology to conduct our business, and our technology could become ineffective or obsolete.
We rely on technology, including geographic and seismic analysis techniques and economic models, to develop our reserve estimates
and to guide our exploration, development and production activities. We and our operator partners will be required to continually
enhance and update our technology to maintain its efficacy and to avoid obsolescence. The costs of doing so may be substantial and
may be higher than the costs that we anticipate for technology maintenance and development. If we are unable to maintain the efficacy
of our technology, our ability to manage our business and to compete may be impaired. Further, even if we are able to maintain
technical effectiveness, our technology may not be the most efficient means of reaching our objectives, in which case we may incur
higher operating costs than we would were our technology more efficient.
The loss of key personnel would directly affect our efficiency and profitability.
Our future success is dependent, in a large part, on retaining the services of our current management team. Our executive officers
possess a unique and comprehensive knowledge of our industry and related matters that are vital to our success within the industry.
The knowledge, leadership and technical expertise of these individuals would be difficult to replace. The loss of one or more of our
officers could have a material adverse effect on our operating and financial performance, including our ability to develop and execute
our long term business strategy. We do not maintain key-man life insurance with respect to any employees. We do have employment
agreements with each of our executive officers. There can be no assurance, however, that any of our officers will continue to be
employed by us.
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Our officers and directors control a significant percentage of our current outstanding common stock and their interests may
conflict with those of our stockholders.
As of the date of this report our executive officers and directors collectively and beneficially own approximately 38% of our outstanding
common stock. This concentration of voting control gives these affiliates substantial influence over any matters which require a
stockholder vote, including without limitation the election of directors and approval of merger and/or acquisition transactions, even if
their interests may conflict with those of other stockholders. It could have the effect of delaying or preventing a change in control or
otherwise discouraging a potential acquirer from attempting to obtain control of us. This could have a material adverse effect on the
market price of our common stock or prevent our stockholders from realizing a premium over the then prevailing market prices for their
shares of common stock.
In the future, we may incur significant increased costs as a result of operating as a public company, and our management
may be required to devote substantial time to new compliance initiatives.
In the future, we may incur significant legal, accounting and other expenses as a result of operating as a public company. The Sarbanes-
Oxley Act of 2002 (the “Sarbanes-Oxley Act”), as well as new rules subsequently implemented by the SEC, have imposed various
requirements on public companies, including requiring changes in corporate governance practices. Our management and other personnel
will need to devote a substantial amount of time to these new compliance initiatives. Moreover, these rules and regulations will increase
our legal and financial compliance costs and will make some activities more time-consuming and costly. For example, we expect these
new rules and regulations to make it more difficult and more expensive for us to obtain director and officer liability insurance, and we
may be required to incur substantial costs to maintain the same or similar coverage.
In addition, the Sarbanes-Oxley Act requires, among other things, that we maintain effective internal controls for financial reporting and
disclosure controls and procedures. In particular, we are required to perform system and process evaluation and testing on the
effectiveness of our internal controls over financial reporting, as required by Section 404 of the Sarbanes-Oxley Act. Our testing may
reveal deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses. Our compliance with
Section 404 will require that we incur substantial accounting expense and expend significant management efforts. We currently do not
have an internal audit group, and we will need to hire additional accounting and financial staff with appropriate public company
experience and technical accounting knowledge. Moreover, if we are not able to comply with the requirements of Section 404 in a
timely manner, or if we or our independent registered public accounting firm identifies deficiencies in our internal controls over financial
reporting that are deemed to be material weaknesses, the market price of our stock could decline, and we could be subject to sanctions or
investigations by the SEC or other regulatory authorities, which would require additional financial and management resources.
Certain Factors Related to Our Common Stock
There presently is a limited market for our common stock, and the price of our common stock may be volatile.
Our common stock is currently quoted on The NASDAQ Stock Market LLC. Our shares, however, are very thinly traded, and we
have a very limited trading history. There could be volatility in the volume and market price of our common stock moving forward.
This volatility may be caused by a variety of factors, including the lack of readily available quotations, the absence of consistent
administrative supervision of “bid” and “ask” quotations and generally lower trading volume. In addition, factors such as quarterly
variations in our operating results, changes in financial estimates by securities analysts or our failure to meet our or their projected
financial and operating results, litigation involving us, factors relating to the oil and gas industry, actions by governmental agencies,
national economic and stock market considerations as well as other events and circumstances beyond our control could have a
significant impact on the future market price of our common stock and the relative volatility of such market price.
Offers or availability for sale of a substantial number of shares of our common stock may cause the price of our common
stock to decline.
Our stockholders could sell substantial amounts of common stock in the public market, including shares sold upon the filing of a
registration statement that registers such shares and/or upon the expiration of any statutory holding period under Rule 144 of the
Securities Act of 1933 (the “Securities Act”), if available, or upon trading limitation periods. Such volume could create a circumstance
commonly referred to as an “overhang” and in anticipation of which the market price of our common stock could fall. The existence of
an overhang, whether or not sales have occurred or are occurring, also could make it more difficult for us to secure additional financing
through the sale of equity or equity-related securities in the future at a time and price that we deem reasonable or appropriate.
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Our directors and officers have rights to indemnification.
Our Bylaws provide, as permitted by governing Nevada law, that we will indemnify our directors, officers and employees whether or
not then in service as such, against all reasonable expenses actually and necessarily incurred by him or her in connection with the
defense of any litigation to which the individual may have been made a party because he or she is or was a director, officer or employee
of the company. The inclusion of these provisions in the Bylaws may have the effect of reducing the likelihood of derivative litigation
against directors and officers, and may discourage or deter stockholders or management from bringing a lawsuit against directors and
officers for breach of their duty of care, even though such an action, if successful, might otherwise have benefited us and our
stockholders.
We do not anticipate paying any cash dividends.
We do not anticipate paying cash dividends on our common stock for the foreseeable future. The payment of dividends, if any, would
be contingent upon our revenues and earnings, if any, capital requirements, and general financial condition. The payment of any
dividends will be within the discretion of our Board of Directors. We presently intend to retain all earnings, if any, to implement our
business strategy; accordingly, we do not anticipate the declaration of any dividends in the foreseeable future.
ITEM 1B. UNRESOLVED STAFF COMMENTS
Not Applicable.
ITEM 2. PROPERTIES
Our principal executive offices are located at 5700 W. Plano Parkway, Suite 3600, Plano, Texas 75093. We currently lease this office
space which totals approximately 3,181 square feet. We believe that the condition and size of our offices are adequate for our current
needs.
Investment in oil and gas properties for 2013 is detailed as follows:
Property acquisition costs
Development costs
Exploratory costs
$
$
2013
6,274,154
3,885,730
-0-
$
$
2012
529,184
323,955
-0-
Oil and Natural Gas Reserves
Reserve Estimates
SEC Case. The following tables sets forth, as of December 31, 2013, our estimated net proved oil and natural gas reserves, the
estimated present value (discounted at an annual rate of 10%) of estimated future net revenues before future income taxes (PV-10) and
after future income taxes (Standardized Measure) of our proved reserves and our estimated net probable oil and natural gas reserves,
each prepared using standard geological and engineering methods generally accepted by the petroleum industry and in accordance with
assumptions prescribed by the Securities and Exchange Commission (“SEC”). All of our reserves are located in the United States.
The PV-10 value is a widely used measure of value of oil and natural gas assets and represents a pre-tax present value of estimated cash
flows discounted at ten percent. PV-10 is considered a non-GAAP financial measure as defined by the SEC. We believe that our PV-10
presentation is relevant and useful to our investors because it presents the estimated discounted future net cash flows attributable to our
proved reserves before taking into account the related future income taxes, as such taxes may differ among various companies. We
believe investors and creditors use PV-10 as a basis for comparison of the relative size and value of our proved reserves to the reserve
estimates of other companies. PV-10 is not a measure of financial or operating performance under GAAP and neither it nor the
Standardized Measure is intended to represent the current market value of our estimated oil and natural gas reserves. PV-10 should not
be considered in isolation or as a substitute for the standardized measure of discounted future net cash flows as defined under GAAP.
18
The estimates of our proved reserves and the PV-10 set forth herein reflect estimated future gross revenue to be generated from the
production of proved reserves, net of estimated production and future development costs, using prices and costs under existing
economic conditions at December 31, 2013. For purposes of determining prices, we used the average of prices received for each month
within the 12-month period ended December 31, 2013, adjusted for quality and location differences, which was $97.08 per barrel of oil
and $5.85 per MCF of gas. This average historical price is not a prediction of future prices. The amounts shown do not give effect to
non-property related expenses, such as corporate general administrative expenses and debt service, future income taxes or to
depreciation, depletion and amortization.
Category
Proved Developed Producing
Proved Undeveloped
Total Proved
Standardized Measure of Future Net
Cash Flows Related to Proved Oil and
Gas Properties
Probable Undeveloped
Category
Proved Developed Producing
Proved Undeveloped
Total Proved
Standardized Measure of Future Net
Cash Flows Related to Proved Oil and
Gas Properties
Probable Undeveloped
Proved Reserves
Balance, beginning
Purchases of minerals in place
Productions
December 31, 2013
Net Reserves (BOE)
Net
Gross
(BOE)
(BOE)
December 31, 2013
Future Net Revenue (M$)
Total
Present Worth
at 10%
2,466,556
12,642,271
15,108,827
82,884 $
1,483,561
1,566,445 $
4,407 $
49,153
53,560 $
3,215
23,310
26,525
1,364,567
657,773 $
$
33,571 $
19,691
16,253
December 31, 2012
Net Reserves (BBL)
Net
Gross
(BBL)
(BBL)
December 31, 2012
Future Net Revenue (M$)
Total
Present Worth
at 10%
55,800
751,000
806,000
24,800 $
392,700
417,500 $
1,397 $
8,538
9,935 $
1,169
2,131
3,300
1,875,300
937,100 $
$
30,986 $
2,909
12,237
2013
Oil (BBL)
Gas (MCF)
2012
(BBL)
417,549
638,898
(13,286)
-
-
3,143,435
(3,540)
428,204
(10,655)
Balance, ending
1,043,161
3,139,595
417,549
Proved developed reserves
64,858
108,001
24,804
19
Standardized Measure of Oil & Gas Quantities
Year Ended December 31, 2013 & 2012
The standardized measure of discounted future net cash flows relating
to proved oil and natural gas reserves is as follows :
2013
2012
Future cash inflows
Future production costs
Future development costs
Future income tax expense
Future net cash flows
10% annual discount for estimated
timing of cash flows
Standardized measure of discounted future
net cash flows related to proved reserves
A summary of the changes in the standardized measure of discounted
future net cash flows applicable to proved oil and natural gas reserves
is as follows :
Balance, beginning of year
Sales and transfers of oil and gas produced during the period
Net change in sales and transfer prices and in production (lifting) costs
related to future production
Net change due to purchases of minerals in place
Net change due to extensions and discoveries
Changes in estimated future development costs
Previously estimated development costs incurred during the period
Net change due to revisions in quantity estimates
Other
Accretion of discount
Net change in income taxes
Balance, end of year
$
$
$
$
$
119,629,906
(31,656,853)
(34,152,898)
(11,264,101)
42,556,054
41,103,000
(12,413,000)
(18,755,000)
(1,012,000)
8,923,000
(22,865,456)
(6,014,000)
19,690,598
$
2,909,000
2,909,000
(905,125)
$
(1,647,568)
30,474,988
22,411,372
(17,355,723)
(3,181,356)
(4,633,853)
(1,468,500)
(318,085)
(6,594,552)
19,690,598
$
-
-
-
-
-
-
-
-
-
-
-
-
Due to the inherent uncertainties and the limited nature of reservoir data, both proved and probable reserves are subject to change as
additional information becomes available. The estimates of reserves, future cash flows and present value are based on various
assumptions, including those prescribed by the SEC, and are inherently imprecise. Although we believe these estimates are reasonable,
actual future production, cash flows, taxes, development expenditures, operating expenses and quantities of recoverable oil and natural
gas reserves may vary substantially from these estimates.
In estimating probable reserves, it should be noted that those reserve estimates inherently involve greater risk and uncertainty than
estimates of proved reserves. While analysis of geoscience and engineering data provides reasonable certainty that proved reserves can
be economically producible from known formations under existing conditions and within a reasonable time, probable reserves involve
less certainty with reserves supporting a probable classification from a probabilistic analysis where those reserves are “as likely as not
to be recovered.” Probable reserves have not been discounted for the additional risk associated with future recovery.
Reserve Estimation Process, Controls and Technologies
The reserve estimates, including PV-10 estimates, set forth above were prepared by Netherland, Sewell & Associates, Inc. and Wright
& Company, Inc. A copy of their full report with regard to our reserves is attached as Exhibit 99.1 to this annual report on Form 10-K.
These calculations were prepared using standard geological and engineering methods generally accepted by the petroleum industry and
in accordance with SEC financial accounting and reporting standards.
20
Our Chief Executive Officer is an experienced and qualified geoscience professional with a degree in geophysical science, but we do
not have any employees with specific reservoir engineering qualifications in the company. Our Chief Executive Officer worked closely
with Netherland, Sewell & Associates, Inc. and Wright & Company Inc. in connection with their preparation of our reserve estimates,
including assessing the integrity, accuracy and timeliness of the methods and assumptions used in this process.
Netherland, Sewell & Associates, Inc. is a large Texas-based professional engineering firm specializing in technical and financial
evaluation of oil and gas assets. They used a combination of production and pressure performance, simulation studies, offset analogies,
seismic data and interpretation, geophysical logs and other relevant field data to calculate our reserves estimates.
Wright & Company Inc. is a Tennessee based professional engineering firm made up of petroleum engineers, geologists, geophysicists
and petro physicists that specialize in technical and financial evaluation of oil and gas assets. They used a combination of production
and pressure performance, simulation studies, offset analogies, seismic data and interpretation, geophysical logs and other relevant field
data to calculate our reserves estimates.
Proved Undeveloped Reserves
As of December 31, 2013, our proved undeveloped reserves totaled 1.483 MM barrels of oil equivalents. These proved undeveloped
reserves at December 31, 2013 were associated with our Marcelina Creek Field property and our Hunton projects. These numbers are
taken from the third party reserves studies by Netherland, Sewell and Associates and Wright & Company.
Our current drilling plans, subject to sufficient capital resources and the periodic evaluation of interim drilling results and other potential
investment opportunities, include drilling substantially all of the Buda wells in our proved undeveloped reserves during 2014 and 2015.
We do not currently have plans to drill the Eagle Ford shale wells in the next year. The area of the Marcelina Creek Field is an active
area of Eagle Ford shale development, and we intend to actively explore our options with regard to these proved undeveloped locations
and other potential Eagle Ford drilling locations on our acreage. Further we will maintain our continuos drilling program in the Hunton
projects for the foreseeable future.
Production, Price and Production Cost History
During the year ended December 31, 2013, we produced and sold 13,286 barrels of oil net to our interest at an average sale price of
$100.67 per bbl. We produced and sold 3,540 MCF of gas net to our interest at an average sales price of $5.68 per MCF. Our
average production cost including lease operating expenses and direct production taxes was $31.29 per bbl. Our depreciation, depletion
and amortization expense was $49.09 per bbl.
During the year ended December 31, 2012, we produced and sold 10,655 barrels of oil net to our interest at an average sale price of
$97.35 per bbl. We had no gas production. Our average production cost including lease operating expenses and direct production taxes
was $46.93 per bbl. Our depreciation, depletion and amortization expense was $51.80 per bbl.
Drilling Activity and Productive Wells
During the year ended December 31, 2010, the Company participated in drilling operations of one re-entry and horizontal extension to
an existing well bore (50% working interest). This well was recompleted in 2012 as a successful producing oil well.
During the year ended December 31, 2011, the Company drilled one well (75% working interest). This well was successfully
completed as an oil well.
During the year ended December 31, 2012, the Company participated in another re-entry and horizontal extension to the same well
drilled in 2010 (50% working interest). This operation was successful and the well is currently a producing oil well. We also
participated in a re-entry and horizontal extension of another well (40% working interest), the Coulter #1. This well is currently testing
as described above.
As of December 31, 2013, we had three productive wells in the Marcelina Creek Field (1.75 net wells) and one well which was in the
process of being tested in the Coulter Field (.40 net wells). Net wells consist of the sum of our fractional working interests in these
wells.
21
ITEM 3. LEGAL PROCEEDINGS
On February 16, 2012, we filed a lawsuit against Hockley Energy, Inc. and Frank O. Snortheim in the District Court of Harris County,
Texas in connection with farmout agreements we entered into with Hockley Energy in November 2011 for the Marcelina Creek
prospect and the East Stockdale prospect. We allege that Hockley Energy did not perform its obligations under the agreements, which
obligations included providing the agreed upon funding, and we seek damages against both Hockley and Mr. Snortheim (who is a
shareholder of Hockley Energy) for breach of contract, fraudulent inducement and promissory estoppel. Each defendant has answered
our original petition with a general denial, and we have filed a motion for default judgment. A trial date has been set for April 28, 2014.
We have also had discussions with the defendants regarding resolving this matter out of court, but we have not reached an agreement to
date.
ITEM 4. MINE SAFETY DISCLOSURES
Not Applicable.
PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS AND
ISSUER PURCHASES OF EQUITY SECURITIES
Our common stock is quoted on The NASDAQ Stock Market LLC under the symbol, “TRCH.” Trading in our common stock in the
over-the-counter market has historically been limited and occasionally sporadic and the quotations set forth below are not necessarily
indicative of actual market conditions. The high and low sales prices for the common stock for each quarter of the fiscal years ended
December 31, 2013 and 2012, according to NASDAQ, were as follows:
Quarter Ended
December 31, 2013
September 30, 2013
June 30, 2013
March 31, 2013
December 31, 2012
September 30, 2012
June 30, 2012
March 31, 2012
High
6.75
3.50
2.34
2.31
2.66
2.45
1.60
2.05
$
$
$
$
$
$
$
$
Low
2.65
1.85
1.70
1.75
1.60
1.14
0.73
0.79
$
$
$
$
$
$
$
$
Record Holders
As of March 20, 2014, there were approximately 238 stockholders of record holding a total of 18,270,408 shares of common stock.
Because many of our shares of common stock are held by brokers and other institutions on behalf of stockholders, we are unable to
estimate the total number of stockholders represented by these record holders.
The holders of the common stock are entitled to one vote for each share held of record on all matters submitted to a vote of
stockholders. Holders of the common stock have no preemptive rights and no right to convert their common stock into any other
securities. There are no redemption or sinking fund provisions applicable to the common stock.
Dividends
We have not declared any cash dividends since inception and do not anticipate paying any dividends in the foreseeable future. The
payment of dividends is within the discretion of the Board of Directors and will depend on our earnings, capital requirements, financial
condition, and other relevant factors. There are no restrictions that currently limit our ability to pay dividends on our common stock
other than those generally imposed by applicable state law.
Equity Compensation Plan Information
As of December 31, 2013, we did not have any compensation plans (including individual compensation arrangements) under which our
equity securities are authorized for issuance.
Sales of Unregistered Securities
Other than the sale below, all equity securities that we have sold during the period covered by this report that were not registered under
the Securities Act have previously been included in a Quarterly Report on Form 10-Q or in a Current Report on Form 8-K.
22
In December 2013, investors exercised warrant agreements, whereby they purchased from us a total of 101,714 shares of common
stock at a price of $2.00 per share. The securities were issued under the exemption from registration provided by Section 4(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 the securities were isolated private transactions; (ii) a limited number of
securities were issued to a single purchaser; (iii) there were no public solicitations; (iv) the purchaser previously represented that he was
an “accredited investors”; (v) the investment intent of the purchaser; and (vi) the restriction on transferability of the securities issued.
ITEM 6. SELECTED FINANCIAL DATA
Not Applicable.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
The information set forth and discussed in this Management’s Discussion and Analysis and Results of Operations is derived from our
historical financial statements and the related notes thereto which are included in this Form 10-Q. The following information and
discussion should be read in conjunction with such financial statements and notes. Additionally, this Management’s Discussion and
Analysis and Plan of Operations contain certain statements that are not strictly historical and are “forward-looking” statements within
the meaning of the Private Securities Litigation Reform Act of 1995 and involve a high degree of risk and uncertainty. Actual results
may differ materially from those projected in the forward-looking statements due to other risks and uncertainties that exist in our
operations, development efforts and business environment, and due to other risks and uncertainties relating to our ability to obtain
additional capital in the future to fund our planned expansion, the demand for oil and natural gas, and other general economic factors.
All forward-looking statements included herein are based on information available to us as of the date hereof, and we assume no
obligation to update any such forward-looking statements.
Basis of Presentation of Financial Information
On November 23, 2010, the Share Exchange Agreement (the “Exchange Agreement” or “Transaction”) between Pole Perfect Studios,
Inc. (“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.
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 audited financial
statements included herewith for the year ended December 31, 2013. This discussion should not be construed to imply that the results
discussed herein will necessarily continue into the future, or that any conclusion reached herein will necessarily be indicative of actual
operating results in the future. Such discussion represents only the best present assessment by our management.
We had no active operations prior to the inception of TEI on June 25, 2010 and had limited revenues prior to the year ended December
31, 2012.
Historical Results for the Years Ended December 31, 2013 and 2012
Revenues and Cost of Revenues
For the year ended December 31, 2013, we had production revenue of $1,243,998 compared to $1,037,247 of production revenue for
the year ended December 31, 2012. During the first half of 2013, production began a natural decline in both the Johnson #1-BH and
the Johnson #4 wells. Refer to the table of production and revenue for 2013 included below. Our cost of revenue, consisting of lease
operating expenses and production taxes, was $434,119, and $500,053 for the years ended December 31, 2013 and 2012, respectively.
23
Property
Marcelina
Oklahoma
Total Q1
Marcelina
Oklahoma
Total Q2
Marcelina
Oklahoma
Total Q3
Marcelina
Oklahoma
Total Q4
Quarter
Q1 - 2013
Q1 - 2013
Q2 - 2013
Q2 - 2013
Q3 - 2013
Q3 - 2013
Q4 - 2013
Q4 - 2013
Oil Production
{BBLS}
2,255
0
2,255
1,673
0
1,673
3,896
316
4,212
4,626
519
5,145
Gas Production
{MCF}
0
0
0
0
0
0
0
1,321
1,321
0
2,220
2,220
Oil Revenue
($)
229,204
-
229,204
160,823
-
160,823
387,872
7,064
394,936
401,956
47,793
449,749
Gas
Revenue
($)
-
-
-
-
-
-
-
-
-
-
9,286
9,286
Total
Revenue
($)
229,204
-
229,204
160,823
-
160,823
387,872
7,064
394,936
401,956
57,079
459,035
Year ended 12/31/13
13,286
3,541
1,234,712
9,286
1,243,998
We recorded depreciation, depletion and amortization expense of $652,179 for the year ended December 31, 2013.
General and Administrative Expenses
Our general and administrative expenses for the years ended December 31, 2013 and 2012 were $6,682,377 and $2,430,884,
respectively. Our general and administrative expenses consisted of compensation expense, substantially all of which was non-cash or
deferred, accounting and administrative costs, professional consulting fees and other general corporate expenses. The increase in
general and administrative expenses for the years ended December 31, 2013 compared to 2012 is primarily related to higher consulting
costs and compensation incurred during the latter period as we have grown and increased operations.
Liquidity and Capital Resources
As December 31, 2013, we had working capital of $(468,453), current assets of $2,250,556 consisting of cash, accounts receivable and
prepaid expenses and total assets of $16,743,321 consisting of current assets, investments in oil and gas properties and goodwill. As of
December 31, 2013, we had current liabilities of $2,719,009, consisting of, accounts payable, payables to related parties, notes payable
and accrued interest and stockholders’ equity was $9,197,219.
Cash flow used in operating activities for the years ended December 31 2013, was $2,262,636 compared to $130,274 for the year
ended December 31, 2012. Cash flow used in operating activities during 2013 can be primarily attributed to net losses from operations,
which consists primarily of general and administrative expenses, a substantial portion of which are non-cash in nature, offset by
increases in accounts and note receivable and increases in accounts payable. 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 year ended December 31, 2013 was $8,587,104 compared to $830,755 for the year ended
December 31, 2012. Cash flow used in investing activities consists primarily of oil and gas investments in the Johnson wells in the
Marcelina Creek Field and the Oklahoma properties acquired during the year ended December 31, 2013.
Cash flow provided by financing activities for the year ended December 31, 2013 was $12,598,201 as compared to $506,000 for the
year ended December 31, 2012. Cash flow provided by financing activities in 2013 consists of convertible promissory notes issued for
cash, net of repayments of debt, and proceeds from common stock issues 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. Subsequent to December 31, 2013, we received net proceeds of approximately $6.15
million from the offering of units of equity consisting of our common stock and warrants, but these proceeds will not be sufficient to
fund all of our proposed drilling operations and operating needs during 2014. We will seek additional financing to meet these plans and
needs. We face obstacles in continuing to attract new financing due to our history and current record of net losses and working capital
deficits. Therefore, 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.
24
We do not expect to pay cash dividends 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 December 31, 2013 and December 31, 2012, 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.
We currently have interests in five oil and gas projects, the Marcelina Creek Field Development in Wilson County, Texas, the Coulter
Field in Waller County, Texas, projects in Logan and Kingfisher counties, Oklahoma and projects in McPherson and Gray and Finney
counties in Kansas. See the description under “Current Projects” above under “Item 1. Business” for more information and disclosure
regarding commitments and contingencies relating to these projects.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Not Applicable.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Our comparative financial statements for the fiscal year ended December 31, 2013 are attached hereto.
25
F-1
TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED BALANCE SHEETS
ASSETS
Current assets:
Cash
Accounts receivable
Prepaid expenses
Total current assets
Investment in oil and gas properties, net
Office equipment
Debt issuance costs, net
Goodwill
Other Assets
TOTAL ASSETS
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable
Accrued liabilities
Related party payables
Notes payable
Due to working interest owners
Interest payable
Total current liabilities
Convertible promissory notes, net of discount of $5,500,462 and
$521,864 at December 31, 2013 and December 31, 2012, respectively
Asset retirement obligation
Commitments and contingencies
Stockholders’ equity:
Preferred stock, no par value, 5,000,000 shares authorized; no shares
issued or outstanding
Common stock, par value $0.001 per share; 70,000,000 shares
authorized;
16,141,765 issued and outstanding at December 30, 2013
13,564,815 issued and outstanding at December 31, 2012
Additional paid-in capital
Warrants outstanding
Accumulated deficit
Total stockholders' equity
$
$
$
December 31,
2013
December 31,
2012
$
$
$
1,811,713
429,699
9,144
2,250,556
13,038,751
11,604
920,947
447,084
74,379
16,743,321
985,123
-
90,000
753,904
580,484
309,498
2,719,009
4,802,711
24,382
-
63,252
92,897
8,346
164,495
3,461,686
473,785
447,084
-
4,547,050
89,247
62,055
768,648
51,000
-
10,581
981,531
580,636
12,614
-
-
-
16,142
21,978,616
3,043,420
(15,840,959)
9,197,219
13,565
8,381,001
-
(5,422,297)
2,972,269
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
$
16,743,321
$
4,547,050
F-2
TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
Revenue
Oil and gas sales
Royalties
Cost of revenue
Gross income
Operating expenses:
General and administrative
Depreciation, depletion and amortization
Total operating expenses
Other income (expense)
Forgiveness of debt income
Interest income
Interest and accretion expense
Total other income (expense)
Net loss before taxes
Provision for income taxes
Net (loss)
Loss per share:
Basic and Diluted
Weighted average shares outstanding:
Basic and Diluted
YEAR
ENDED
DECEMBER 31,
2013
YEAR
ENDED
DECEMBER 31,
2012
$
1,243,998
51,501
$
(434,119)
861,380
6,682,377
652,179
7,334,556
660,000
59
(4,605,545)
(3,945,486)
1,037,247
-
(500,053)
537,194
2,430,884
551,890
2,982,774
-
12
(363,235)
(363,223)
(10,418,662)
(2,808,803)
-
-
$
$
(10,418,662)
(0.74)
$
$
(2,808,803)
(0.21)
14,016,240
13,564,815
F-3
TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
FOR THE PERIOD FROM JANUARY 1, 2012 TO DECEMBER 31, 2013
Preferred
stock
Common stock
shares
Common
stock
Amount
($)
Additional
paid-in
Capital
($)
Accumulated
Deficit
($)
Warrants
Outstanding
($)
Total
($)
Balance, January 1, 2012
Issuance of common stock for services
Shares issued in connection with
promissory notes
Warrants issued in connection with
promissory notes
Beneficial conversion feature on
convertible notes
Warrants issued for services
Common stock retired
Net loss
Balance, December 31, 2012
Issuance of common stock for services
Shares issued in connection with
promissory notes
Warrants issued re: convertible
promissory notes
Beneficial conversion feature on
convertible notes
Warrants exercised
Warrants issued for services
Warrants issued in connection with
stock issuance
Common stock issued
Common stock issued for mineral
leases
Net loss
Balance, December 31, 2013
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
14,664,815
14,665
5,861,985
(2,613,494)
425,000
425
329,450
75,000
-
75
-
-
-
(1,600,000)
-
-
-
(1,600)
-
67,650
791,376
390,600
938,340
1,600
-
-
-
-
-
-
-
(2,808,803)
13,564,815
13,565
8,381,001
(5,422,297)
735,752
735
1,438,245
968,628
969
1,694,123
-
-
2,531,321
5,770,654
203,326
-
(123,250)
849,787
-
101,714
-
-
212,500
558,356
-
-
102
-
-
213
558
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
2,920,170
123,250
-
3,263,156
329,875
67,725
791,376
390,600
938,340
-
(2,808,803)
2,972,269
1,438,980
1,695,092
2,531,321
5,770,654
203,428
2,920,170
-
850,000
-
-
-
-
-
-
-
-
1,233,409
-
-
(10,418,662)
-
-
1,233,967
(10,418,662)
16,141,765
16,142 21,978,616
(15,840,959)
3,043,420
9,197,219
F-4
TORCHLIGHT ENERGY RESOURCES, INC.
CONSOLIDATED STATEMENTS OF CASH FLOW
Cash Flows From Operating Activities
Net (loss)
Adjustments to reconcile net loss to net cash
from operating activities:
Stock based compensation
Accretion of convertible note discounts
Depreciation, depletion and amortization
Forgiveness of debt income
Change in:
Accounts receivable
Prepaid expenses
Debt issuance costs
Increase in other assets
Accounts payable and accrued liabilities
Related party payable
Due to working interest owners
ARO accretion
Interest payable
Net cash used in operating activities
Cash Flows From Investing Activities
Investment in oil and gas properties
Proceeds from the sale of oil and gas properties
Proceeds from sale of leases
Net cash used in investing activities
Cash Flows From Financing Activities
Proceeds from promissory notes
Repayment of promissory notes
Proceeds from promissory notes
Proceeds from warrant exercise
Issuance of common stock
Net cash provided by financing activities
Net increase (decrease) in cash
Cash - beginning of period
Cash - end of period
Supplemental disclosure of cash flow information:
Cash paid for interest expense
Cash paid for income taxes
Non cash transactions:
Common stock issued for leases
Common stock issued in connection with promissory notes
Warrants issued in connection with promissory notes
Warrants issued in connection with common stock issuance
Beneficial conversion feature on promissory notes
Exchange of promissory notes
Retirement of common stock
Asset retirement obligation
Convertible Note issued for debt issuance costs
Liabilities assumed in purchase of oil and gas properties
Sale of oil and gas properties in exchange for note receivable
Capitalized interest cost
F-5
YEAR ENDED
December 31, 2013
YEAR ENDED
December 31, 2012
$
(10,418,662)
$
(2,808,803)
4,331,143
3,894,389
652,179
(660,000)
(336,803)
(798)
(967,020)
(74,379)
833,820
(18,648)
255,484
1,360
245,299
(2,262,636)
(9,663,504)
-
1,076,400
(8,587,104)
10,855,773
(61,000)
750,000
203,428
850,000
12,598,201
1,748,461
63,252
1,811,713
468,841
-
1,233,967
1,695,100
2,531,321
123,250
5,770,654
-
-
10,407
40,000
1,809,572
990,000
56,347
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
1,268,216
313,963
551,890
-
(75,623)
7,921
-
-
106,291
509,898
-
-
(4,027)
(130,274)
(905,326)
74,571
-
(830,755)
1,049,000
(543,000)
506,000
(455,029)
518,281
63,252
105,488
-
-
67,725
791,376
-
390,600
412,500
1,600
693
-
-
-
-
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
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 is an
exploration stage energy company, incorporated under the laws of the State of Nevada in June 2010. We are engaged in the acquisition,
exploration, exploitation and/or development of oil and natural gas properties in the United States. In addition to TEI, we also operate
our business through Torchlight Energy Operating, LLC, a Texas limited liability company and wholly-owned subsidiary.
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 December 31, 2013, the Company had not yet achieved profitable operations, had accumulated losses of $15,840,959 since its
inception and expects to incur further losses in the development of its business, which casts substantial doubt about the Company’s
ability to generate future profitable operations and/or to obtain the necessary financing to meet its obligations and repay its liabilities
arising from normal business operations when they come due. Management’s plan to address the Company’s ability to continue as a
going concern includes: (1) obtaining debt or equity funding from private placement or institutional sources; (2) obtain loans from
financial institutions, where possible, or (3) participating in joint venture transactions with third parties. Although management believes
that it will be able to obtain the necessary funding to allow the Company to remain a going concern through the methods discussed
above, there can be no assurances that such methods will prove successful. The accompanying consolidated financial statements do not
include any adjustments that might result from the outcome of this uncertainty.
3. SIGNIFICANT ACCOUNTING POLICIES
The Company maintains its accounts on the accrual method of accounting in accordance with accounting principles generally accepted in
the United States of America. Accounting principles followed and the methods of applying those principles, which materially affect the
determination of financial position, results of operations and cash flows are summarized below:
Use of estimates – The preparation of financial statements in conformity with accounting principles generally accepted in the United
States of America requires management to make estimates and certain assumptions that affect the amounts reported in these consolidated
financial statements and accompanying notes. Actual results could differ from these estimates.
Basis of presentation—The financial statements are presented on a consolidated basis and include all of the accounts of Torchlight
Energy Resources Inc. and its wholly owned subsidiary, Torchlight Energy, Inc. All significant intercompany balances and transactions
have been eliminated.
Risks and uncertainties – The Company’s operations are subject to significant risks and uncertainties, including financial, operational,
technological and other risks associated with operating an emerging business, including the potential risk of business failure.
F-6
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 December 31, 2013 and December 31, 2012 no valuation
allowance was considered necessary.
Investment in oil and gas properties – The Company uses the full cost method of accounting for exploration and development
activities as defined by the Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs of unsuccessful,
as well as successful, exploration and development activities are capitalized as properties and equipment. This includes any internal
costs that are directly related to property acquisition, exploration and development activities but does not include any costs related to
production, general corporate overhead or similar activities. Gain or loss on the sale or other disposition of oil and gas properties is not
recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves.
Oil and gas properties include costs that are excluded from costs being depleted or amortized. Oil and natural gas property costs
excluded represent investments in unevaluated properties and include non-producing leasehold, geological and geophysical costs
associated with leasehold or drilling interests and exploration drilling costs. The Company allocates a portion of its acquisition costs to
unevaluated properties based on relative value. Costs are transferred to the full cost pool as the properties are evaluated over the life of
the reservoir.
Capitalized interest - The Company capitalizes interest on unevaluated properties during the periods in which they are excluded from
costs being depleted or amortized. During years ended December 31, 2013 and 2012, the Company capitalized $104,821 and $48,474,
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 did not recognize impairment on its oil and gas properties
during the years ended December 31, 2013 and 2012. 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.
F-7
Proved reserves are estimated quantities of crude oil, natural gas, and natural gas liquids, which geological and engineering data
demonstrate with reasonable certainty to be recoverable from known reservoirs under existing economic and operating conditions. The
independent engineering estimates include only those amounts considered to be proved reserves and do not include additional amounts
which may result from new discoveries in the future, or from application of secondary and tertiary recovery processes where facilities
are not in place or for which transportation and/or marketing contracts are not in place. Estimated reserves to be developed through
secondary or tertiary recovery processes are classified as unevaluated properties.
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. 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.
Goodwill - Goodwill represents the excess of the purchase price over the fair value of the net identifiable tangible and intangible assets
of acquired companies. Goodwill is not amortized; instead, it is tested for impairment annually or more frequently if indicators of
impairment exist.
Goodwill was $447,084 as of December 31, 2013 and December 31, 2012, and was acquired on November 23, 2010 in connection
with the Company’s reverse acquisition (Note 1).
Asset retirement obligations – Accounting principles require that the fair value of a liability for an asset’s retirement obligation
(“ARO”) be recorded in the period in which it is incurred if a reasonable estimate of fair value can be made, and that the corresponding
cost be capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then-present value each
subsequent period, and the capitalized cost is depleted over the useful life of the related asset. Abandonment cost incurred is recorded as
a reduction to the ARO liability.
Inherent in the fair value calculation of an ARO are numerous assumptions and judgments including the ultimate settlement amounts,
inflation factors, credit adjusted discount rates, timing of settlement, and changes in the legal, regulatory, environmental and political
environments. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding
adjustment is made to the oil and gas property balance. Settlements greater than or less than amounts accrued as ARO are recorded as a
gain or loss upon settlement.
Asset retirement obligation activity is disclosed in Note 10.
Share-based compensation– Compensation cost for equity awards is based on the fair value of the equity instrument on the date of
grant and is recognized over the period during which an employee is required to provide service in exchange for the award.
Compensation cost for liability awards is based on the fair value of the vested award at the end of each period.
Revenue recognition – The Company recognizes oil and gas revenues when production is sold at a fixed or determinable price,
persuasive evidence of an arrangement exists, delivery has occurred and title has transferred, and collectability is reasonably assured.
Basic and diluted earnings (loss) per share - Basic earnings (loss) per common share is computed by dividing net income (loss)
available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings
(loss) per common share is computed in the same way as basic earnings (loss) per common share except that the denominator is
increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued
and if the additional common shares were dilutive. 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.
F-8
Recent accounting pronouncements – In September 2011, the FASB issued guidance that amends and simplifies the rules related to
testing goodwill for impairment. The revised guidance allows an entity to first assess qualitative factors to determine whether the
existence of events or circumstances leads to a determination whether it is more likely than not that the fair value of reporting unit is less
than its carrying amount. The results of this assessment will determine whether it is necessary to perform the currently required two-
step impairment test. Under this update, an entity also has the option to bypass the qualitative assessment for any reporting unit in any
period and proceed directly to performing the two-step goodwill impairment test. This guidance is effective for annual periods
beginning after December 15, 2011. The adoption of this guidance did not have a material effect 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 March 31, 2014, the date of issuance of the financial
statements. Subsequent events are disclosed in Note 11.
4. RELATED PARTY PAYABLES
As of December 31, 2013, related party payables consisted of accrued and unpaid compensation to two of our executive officers
totaling $90,000. The related party payables at December 31, 2012 included $660,000 of accrued compensation due to our executive
officers and directors. The officers forgave the $660,000 of related party debt during third quarter, 2013.
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 December 31, 2013 and 2012, no amounts had been recorded because no
specific liability has been identified that is reasonably probable of requiring the Company to fund any future material amounts.
6. STOCKHOLDERS’ EQUITY
The Board of Directors has the authority to issue up to 5,000,000 shares of preferred stock in one or more series, to fix the number of
shares constituting any such series, and to fix the rights and preferences of the shares constituting any series, without any further vote
or action by the stockholders. As of December 31, 2013 and 2012 there were no issued and outstanding shares of preferred stock and
there were no agreements or understandings for the issuance of preferred stock.
During the years ended December 31, 2013 and 2012, the Company issued 735,752 and 425,000 shares of common stock,
respectively, as compensation for services, with total values of $1,438,977 and $329,875.
During the years ended December 31, 2013 and 2012, the Company issued 2,403,174 and -0- warrants, respectively, as compensation
for services, with a total values of $2,920,170 and $-0-.
During the year ended December 31, 2013 and 2012, the Company issued 1,308,124 and 126,000 warrants, respectively, in connection
with financing transactions discussed in Note 9, including 552,057 and -0- warrants issued to the placement agent.
During the year ended December 31, 2013, the Company issued 558,356 shares of Common Stock as acquisition of lease interests
valued at $1,233,967.
During the year ended December 31, 2013 the Company issued 969,000 shares of Common Stock in conversions of 12% Convertible
Notes Payable valued at $1,695,100.
During the year ended December 31, 2013 the Company issued 101,714 shares of Common Stock resulting from Warrant exercises for
cash totaling $203,428.
During December 2013 and early January 2014, we sold to investors in a private offering an aggregate of 350,000 shares of restricted
common stock and 87,500 warrants to purchase shares of restricted common stock. Each warrant has an exercise price of $6.00 per
share and expires on December 31, 2018. We received aggregate consideration of $1,400,000 for the securities, $850,000 in December
and $550,000 in January, 2014. Warrants were issued in connection with the $850,000 in notes issued in December – 53,125 valued at
$123,250.
F-9
A summary of stock options and warrants outstanding as of December 31, 2013 by exercise price and year of expiration is presented
below:
Exercise
Price
2014
2015
2016
Expiration Date in
2017
2018
Total
$
$
$
$
$
$
$
$
$
1.75
2.00
2.09
2.50
2.75
2.82
3.00
5.00
6.00
80,000
-
-
225,000
-
-
-
778,356
-
1,083,356
855,000
-
-
50,000
-
-
-
-
-
905,000
1,235,714
1,050,264
-
100,000
250,000
-
100,000
25,000
-
2,760,978
-
126,000
-
-
-
-
-
-
-
126,000
-
1,696,380
1,100,000
-
-
38,174
-
-
53,125
2,887,679
2,170,714
2,872,644
1,100,000
375,000
250,000
38,174
100,000
803,356
53,125
7,763,013
At December 31, 2013 the Company had reserved 7,763,013 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
Expected volatility of common stock
Dividend yield
Discount due to lack of marketability
Expected life of warrant
0.78%
191% - 253%
0.00%
30.00%
3 years - 5 years
7. CAPITALIZED COSTS
The following table presents the capitalized costs of the Company as of December 31, 2013 and December 31, 2012:
2013
2012
Evaluated costs subject to amortization
Unevaluated costs
Total capitalized costs
Less accumulated depreciation, depletion
and amortization
Net capitalized costs
$
$
9,484,014
4,758,806
14,242,820
(1,204,069)
13,038,751
$
$
3,435,918
577,658
4,013,576
(551,890)
3,461,686
Unevaluated costs as of December 31, 2013 consisted of $639,590 associated with the Company’s interest in the Coulter #1 well. The
Coulter #1 wells is undergoing production and test operations with the goal of removing sufficient water from the wellbore to allow
production of natural gas. The unevaluated costs as of December 31, 2013 consisted entirely of the Company’s interest in the Coulter
#1 well.
In April 2013, we entered into an agreement to acquire certain assets of Xtreme Oil & Gas, Inc. of Plano, Texas (“Xtreme”). Included
in that agreement were the Smokey Hills Prospect in McPherson County, Kansas, the Cimarron Area Hunton Project in Logan County,
Oklahoma, and an interest in a salt water disposal facility in Seminole, Oklahoma. Total consideration for all the properties was $1.6
million allocated to $940,820 to the Smokey Hills Project and $659,180 to the Cimarron Area.
F-10
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 following is a reconciliation between the federal income tax benefit computed at the statutory federal income tax rate of 34% and
actual income tax provision for the years ended December 31, 2013 and December 31, 2012:
Federal income tax benefit at statutory rate
Permanent Differences
Other
Change in valuation allowance
Provision for income taxes
Year ended
Dec. 31, 2013
Year ended
Dec. 31, 2012
(3,542,345)
696,631
(470,413)
3,316,127
0
(954,993)
84,574
(22,185)
892,604
0
The tax effects of temporary differences that gave rise to significant portions of deferred tax assets and liabilities at December 31, 2013
and December 31, 2012 are as follows:
Deferred tax assets:
Net operating loss carryforward
Accruals
Reserves
Deferred tax liabilities:
Intangible drilling and other costs for oil and gas properties
Net deferred tax assets and liabilities
Less valuation allowance
Total deferred tax assets and liabilities
Dec. 31, 2013
Dec. 31, 2012
$
$
4,229,034
30,600
1,132,778
(318,039)
5,074,373
(5,074,373)
-
$
$
1,988,631
163,200
372
(393,958)
1,758,245
(1,758,245)
-
The Company had a net deferred tax asset related to federal net operating loss carry forwards of $12,620,377 and $5,616,449 at
December 31, 2013 and December 31, 2012, respectively. 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.
F-11
9. PROMISSORY NOTES
On December 18, 2012, the Company exchanged $412,500 of outstanding convertible promissory notes for new 12% Series A
Secured Convertible Promissory Notes (12% Notes) described below. The 12% Notes were issued as part of a larger offering with
senior liens on the Company’s oil and gas properties. In order to induce the holders of the previously outstanding convertible
promissory notes to exchange such promissory notes and to relinquish their priority liens on the Company’s oil and gas properties in
favor of all 12% Convertible Promissory Note Holders, the Company agreed to grant the note holders a total of 235,714 four year
warrants to purchase common stock at $1.75 per share, valued at $240,428, and 235,714 four year warrants to purchase common stock
at $2.00 per share, valued at $233,357. The total of these warrants, $473,785, is reflected as debt issuance costs on the balance sheet as
of December 31, 2012, as these costs relate to the larger offering of 12% Convertible Promissory Notes.
On December 18, 2012, the Company issued $690,000 of 12% Notes to new investors. Together with the conversion described above,
there was $1,102,500 of principal amount outstanding as of December 31, 2012. The 12% Notes are due and payable on March 31,
2015 and provide for conversion into common stock at a price of $1.75 per share and include the issuance of 8,000 warrants for each
$70,000 of principal amount purchase. The warrants carry a five year term and have an exercise price of $2.00 per share. They were
valued at $137,340, which is reflected as a discount on the 12% Notes, to be amortized over the life of the debt under the effective
interest method. Since the conversion price on the 12% Notes was below the market price of the Company’s common stock on the date
of issuance, this constitutes a beneficial conversion feature. The amount is calculated as the difference between the market price of the
common stock on the date of closing and the effective conversion price as adjusted by the discount for the warrants issued. The amount
of the beneficial conversion feature was $390,600, and is also reflected as a discount on the 12% Notes. The fair value of the
Convertible Promissory Notes is determined utilizing Level 2 measurements in the fair value hierarchy.
During the year ended December 31, 2013, the Company issued an additional $10,895,773 in principal value of 12% Notes. Such
notes carry the same terms as described above. In connection therewith, the Company also issued a total of 1,308,082 five-year
warrants to purchase common stock at an exercise price of $2.00 per share. The value of the warrant shares was $1,917,158 and the
amount recorded for the beneficial conversion feature was $5,770,654. These amounts were recorded as a discount on the 12% Notes.
In addition, the Company engaged a placement agent to source investors for the majority of these additional notes. This placement
agent was paid a fee of 10% of the principal amount of the notes plus a non-accountable expense reimbursement of up to 2% of the
principal raised by the agent. The placement agent also received 552,057 warrants to purchase common shares at $2.00 per share for a
period of three years, valued at $614,163. All the amounts paid to the placement agent have been included in debt issuance costs and
will be amortized into interest expense over the life of the 12% Notes.
The 12% Notes have a first priority lien on all of the assets of the Company. The Company was previously required to set aside in a
separate account, an amount of funds equal to the (x) outstanding principal amount of each 12% Note divided by the total number of full
calendar months after the date of issuance of that 12% Note until the maturity date, plus (y) the annual amount of simple interest to
accrue on the outstanding principal amount of that 12% Note divided by 12. The sinking fund requirement was waived by the note
holders during the quarter that ended September 30, 2013.
The Company is obligated on a short term note payable for $750,000 which is due June 12, 2014 with 10% interest at maturity.
10. ASSET RETIREMENT OBLIGATIONS
The following is a reconciliation of the asset retirement obligation liability through December 31, 2013:
Asset retirement obligation – January 1, 2012
Adjustment to estimated liability
Accretion expense
Asset retirement obligation – December 31, 2012
Estimated liabilities recorded
Accretion Expense
Asset retirement obligation – December 31, 2013
$
$
$
$
11,369
693
552
12,614
10,407
1,361
24,382
F-12
11. SUBSEQUENT EVENTS
During December 2013 and early January 2014, we sold to investors in a private offering an aggregate of 350,000 shares of restricted
common stock and 87,500 warrants to purchase shares of restricted common stock. Each warrant has an exercise price of $6.00 per
share and expires on December 31, 2018. We received aggregate consideration of $1,400,000 for the securities, $850,000 in December
and $550,000 in January, 2014.
On January 31, 2014, we sold to investors in a private offering an aggregate of 1,400,000 shares of restricted common stock and
350,041 warrants to purchase shares of restricted common stock. Each warrant has an exercise price of $6.00 per share and expires on
December 31, 2018. The securities were sold in units, each of which consisted of one share of common stock and ¼ of a warrant to
purchase a share of common stock (the “Units”). We received aggregate consideration of $5,600,000 for the securities. In connection
with the sale of these securities, we paid National Securities Corporation, the placement agent, a fee of $560,000 and paid additional
transaction expenses of approximately $25,000 plus issued the placement agent warrants to purchase a total of 140,000 Units at an
exercise price of $6.00 per Unit until December 31, 2018.
We also granted registration rights to the purchasers in both offerings, whereby, under certain terms and conditions, we agreed to use
our best efforts to file a registration statement with the Securities and Exchange Commission covering the resale of the common stock
purchased in the offerings and the shares of common stock underlying the warrants purchased in the offerings.
F-13
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
Not Applicable.
ITEM 9A. CONTROLS AND PROCEDURES
Evaluation of 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 December 31, 2013. 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 and adequately designed to ensure that the information required to be disclosed by us in the reports we submit under the
Exchange Act is recorded, processed, summarized and reported within the time periods specified in the applicable rules and forms and
that such information was accumulated and communicated to our principal executive officer and principal financial officer, in a manner
that allowed for timely decisions regarding disclosure.
Changes in internal control over financial reporting
On November 14, 2013, the Board of Directors established an Audit Committee and appointed the four independent members of the
Board to the committee, including Wayne Turner, Jerry Barney, Edward Devereaux and Eunis L. Shockey. The Board appointed Mr.
Devereaux as Chairman of the Audit Committee. Also on November 14, 2013, the Board adopted a charter for the Audit Committee.
The appointment of the Audit Committee and adoption of a written charter of the Audit Committee may be deemed a change in our
internal control over financial reporting that has materially affected, or is reasonably likely to materially affect, our internal control over
financial reporting. These changes should provide oversight of our financial affairs and accounting and provide oversight in the
establishment and monitoring of required internal controls and procedures. The Committee will assist the Board of Directors in
fulfilling its responsibility to oversee: (i) management’s conduct of the financial reporting process; (ii) the integrity of the financial
statements and other financial information we provide to the SEC and the public; (iii) our system of internal accounting and financial
controls; (iv) our compliance with legal and regulatory requirements; (v) the performance of our internal audit function; (vi) the
independent auditors’ qualifications, performance, and independence; and (vii) the annual independent audit of our financial statements.
Management’s Annual Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule
13a-15(f) of the Exchange Act). Our management conducted an evaluation of the effectiveness of our internal control over financial
reporting based on the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in
Internal Control – Integrated Framework and Internal Control over Financial Reporting – Guidance for Smaller Public Companies.
Based on this evaluation, management concluded that, our internal control over financial reporting is not effective. This determination is
based on management’s belief that there is currently not an adequate level of review and approvals to ensure all information is gathered
and recorded in a timely manner. We are, however, addressing the issue and performing a final update of our policies and procedures.
Upon finalizing these policies and procedures and ensuring they are effectively applied, we believe our internal control will be deemed
effective.
In light of the results of the evaluation above, we performed additional analysis and other post-closing procedures to ensure our
financial statements were prepared in accordance with generally accepted accounting principles. Accordingly, we believe that the
financial statements included in this report fairly present, in all material respects, our financial condition, results of operations and cash
flows for the periods presented. Further, although we determined our internal control is not effective, there have been no material
misstatements in our financial statements.
Limitations on Effectiveness of Controls and Procedures
Our management, including our principal executive officer and principal financial officer, does not expect that disclosure controls or
internal controls will prevent all error and all fraud. A control system, no matter how well conceived and operated, can provide only
reasonable, not absolute, assurance that the objectives of the control system are met. In addition, the design of a control system must
reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the
inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances
of fraud, if any, within a company have been detected. These inherent limitations include the realities that judgments in decision-making
can be faulty, and that breakdowns can occur because of simple error or mistake.
26
Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people or by
management’s override of the control. The design of any systems of controls is based in part upon certain assumptions about the
likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential
future conditions. Over time, control may become inadequate because of changes in conditions, or the degree of compliance with the
policies or procedures may deteriorate. Because of these inherent limitations in a cost-effective control system, misstatements due to
error or fraud may occur and not be detected. Individual persons may perform multiple tasks which normally would be allocated to
separate persons and therefore extra diligence must be exercised during the period these tasks are combined.
ITEM 9B. OTHER INFORMATION
Not applicable.
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Our executive officers and directors are as follows:
PART III
Name
Thomas Lapinski
John A. Brda
Willard G. McAndrew III
Roger N. Wurtele
Wayne Turner
Jerry D. Barney
Edward J. Devereaux
Eunis L. Shockey
Age Position(s) and Office(s)
69
49
59
67
65
67
71
77
Chief Executive Officer and Director
President, Secretary and Director
Chief Operating Officer and Director
Chief Financial Officer
Director
Director
Director
Director
Below is certain biographical information of our executive officers and directors:
Thomas Lapinski – Mr. Lapinski has served as our Chief Executive Officer, Interim Principal Financial Officer and director since
November 2010. He also previously served as our President from November 2010 to January 2012. He is the founder of
Torchlight Energy, Inc., our wholly owned subsidiary, and has served as its Chief Executive Officer, President and director since its
incorporation in June 2010. From 2002 to the present, he has engaged in consulting work on evaluating exploration, acquisition and
re-development opportunities in the Rocky Mountain Region, Texas Gulf Coast, Mid-Continent, the Middle East, and South
America. From September 1996 to June 2002, Mr. Lapinski served as President of Stephens Energy International of The Stephens
Group, LLC. While there, he was involved in oil and gas exploration and production project development. Prior to that, he spent over
30 years in senior positions with Amoco Corporation before retiring. His expertise is in project evaluations, operations management
and strategic planning with experience throughout the Rocky Mountain region, Alaska, U.S. mid-continent, the U.S. Gulf Coast and
international arenas. With Amoco, he has held numerous positions, including Division Geophysicist for Rocky Mountain Area,
Regional Geophysicist for Africa and the Middle East, Exploration Manager for North and West Africa, President-Amoco Morocco,
President-Amoco Turkey, General Manager-Amoco Kenya, Exploration Manager Gulf Coast, Regional Exploration Manager for
Southern and Eastern U.S. and Manager for Resource and Business Development in Southern Rocky Mountain Area. He also spent
time on a special project for the Chairman of Amoco on key strategic planning issues where he was responsible for long-term
monetization of Amoco’s North American asset base. Mr. Lapinski received a degree in Geophysical Engineering from the Colorado
School of Mines in 1966.
We appointed Mr. Lapinski as an executive officer and a member of the Board of Directors based on his knowledge and experience
in the oil and gas industry. His ability to identify and evaluate opportunities is an important part of our continued success.
John A. Brda – Mr. Brda has been our President and Secretary and a member of the Board of Director since January 2012. He has
been the Managing Member of Brda & Company, LLC since 2002, which provides consulting services to public companies—with a
focus in the oil and gas sector—on investor relations, equity and debt financings, strategic business development and securities
regulation matters.
We believe Mr. Brda is an excellent fit to our Board of Directors and management team based on his extensive experience in
transaction negotiation and business development, particularly in the oil and gas sector as well as other non-related industries. He
has consulted with many public companies in the last ten years, and we believe that his extensive network of industry professionals
and finance firms will contribute to our success.
27
Willard G. McAndrew III – Mr. McAndrew has served as our Chief Operating Officer since September 2013 and as a member of
the Board since October 2013. He has forty three years of experience in the energy industry, from field operations to refining. From
December 2006 to September 2013, Mr. McAndrew served as the Chairman of the Board, CEO and President of Xtreme Oil & Gas,
Inc., a company engaged in the acquisition, operation and development of oil and natural gas properties located in Texas and the
southeast region of the United States. He began his career in 1969, gaining experience working for Hercules Drilling Company as a
roustabout in South Louisiana. Mr. McAndrew attended Louisiana State University and then spent two years in the United States
Marine Corps. Later, he joined Exxon Corporation Refinery’s Distillation and Specialties division in Baton Rouge, Louisiana,
becoming the fourth generation in his family to work for Exxon. Mr. McAndrew has served as President and owner of several small
companies that were involved in all phases of the oil and gas business from drilling, reworking, completion, leases, etc. He has also
been a consultant since 1990 to companies and is responsible for the structure, formation and marketing of partnerships and energy
financing.
We believe that Mr. McAndrew’s many years in the oil and gas industry and his vast network of contacts in the investment banking
and broker-dealer communities compliments the Board of Directors.
Involvement in certain legal proceedings. From 2001 through May 2006, Mr. McAndrew served as the CEO, President and
Director of Energy & Engine Technology, Inc. After he left the company, it filed for bankruptcy protection in December 2006.
Roger N. Wurtele – Mr. Wurtele has served as our Chief Financial Officer since September 2013. He is a versatile, experienced
finance executive that has served as Chief Financial Officer for several public and private companies. He has a broad range of
experience in public accounting, corporate finance and executive management. Mr. Wurtele previously served as CFO of Xtreme Oil
& Gas, Inc. from February 2010 to September 2013. Since May 2013 he has worked as a financial consultant for us. From
November 2007 to January 2010, Mr. Wurtele served as CFO of Lang and Company LLC, a developer of commercial real estate
projects. He graduated from the University of Nebraska and has been a Certified Public Accountant for 40 years.
Involvement in certain legal proceedings. From 2001 through May 2006, Mr. Wurtele served as the CFO of Energy & Engine
Technology, Inc. After he left the company, it filed for bankruptcy protection in December 2006.
Wayne Turner – Mr. Turner has served as one of our directors since March 2011. He is presently the Managing Partner of
JEBCO Seismic, LP, a position he has held since 1989, and is the Managing Partner of Big Thicket Oil & Gas, L.P., a position he
has held since 2001. Mr. Turner took over management of JEBCO in 1989, when he acquired an ownership interest in the
company. JEBCO is an independent international geophysical data acquisition contractor. Jebco’s non-exclusive surveys and third
party datasets represent a unique and readily available source of information for both mature and frontier regions. JEBCO has
operated both offshore and onshore in Canada and the U.S. JEBCO has also conducted surveys in the North Sea, Africa, Asia, and
South America. One of JEBCO’s most significant accomplishments was signing an agreement with the Ministry of Geology in the
USSR in 1989. The company was active in Russia, Kazakhstan, Uzbekistan, and Azerbaijan before and after the break-up of the
USSR. The company has provided oil and gas exploration information to the industry, assisted in license rounds, and assisted in
direct negotiations for oil and gas properties in these countries. Mr. Turner spent significant time in these countries and personally
negotiated the major contract agreements involved.
Mr. Turner started Big Thicket Oil & Gas, L.P. in 2001. This company is active in oil and gas exploration in Texas, Louisiana,
Oklahoma, and New Mexico. Most of the activity is through partnerships, which allows the company to remain small in staff, but
have access to expertise in different areas. Big Thicket does not operate wells, but is involved in generating and evaluating prospects.
Mr. Turner graduated in 1971 from the University of Houston with a degree in Electrical Engineering. He is active in various
charitable organizations including the Houston Livestock Show and Rodeo and Houston Children’s Charities.
Wayne Turner’s expertise in the oil and gas industry makes him an excellent fit to the Board of Directors. In particular, we believe
his experience in geophysical data acquisition is a valuable asset to the company.
Jerry Barney – Dr. Barney has served as member of the Board of Directors since October 2013. He has over 30 years of
experience in various management and consulting positions with technology, oil services and government entities. Dr. Barney was a
director of Barney Family Companies, a successful investment firm with holdings in oil and gas properties, office buildings and
financial assets. Dr. Barney has a Bachelor of Science from the University of Kansas; a MA and EdD in Education from Columbia
University; and a MBA from Rensselaer University.
We believe that Dr. Barney’s broad range of business experience and skills, punctuated by noteworthy higher education credentials,
compliments the Board of Directors.
28
Edward Devereaux – Mr. Devereaux has served as member of the Board of Directors since October 2013. He is a seasoned
investment executive with over three decades of experience in investment management, investment banking and securities sales and
marketing. From 2010 to the present, he has served as a consultant to companies wishing to raise capital within the independent
broker dealer and registered investment advisors communities. From 2006 to 2010, he served as President and CEO of Advanced
Marketing Services, a marketing consulting and investment banking firm. Mr. Devereaux has participated in raising more than $10
billion of investment capital in his career. He has worked for various investment firms, including Prudential Securities and
Lightstone Securities. Mr. Devereaux has a B.A. from Hofstra University.
Edward Devereaux expertise in the securities industry makes him an excellent fit to the Board of Directors. In particular, we believe
his oversight of our capital raising strategies is a valuable asset to the company.
Eunis L. Shockey – Mr. Shockey has served as member of the Board of Directors since October 2013. He is a successful and
experienced entrepreneur and executive. Mr. Shockey retired in 2000, but since then he has acted as a mentor for many of the
companies in his investment portfolio. After completing his service in the U.S. Navy, Mr. Shockey entered the software industry and
gained broad knowledge of military software and telephony applications while at GE, RCA, Raytheon, and Northern Telecom. He
founded Computerware in 1978 and successfully developed and marketed a telephone company management system for shared
tenant services. Computerware was bought by a venture capital fund in 1986. Mr. Shockey then founded Telecommunications
Support Systems (TSS) to dispatch substitute teachers for schools. Its customers included 600 of the largest school districts in the
U.S. and Canada. TSS was sold in 2000 and currently operates as eSchools Solutions, Inc.
We believe Mr. Shockey is an excellent fit to our Board of Directors based on his extensive experience in successfully owning and
operating multiple successful companies over the years.
Section 16(a) Beneficial Ownership Reporting Compliance
Section 16(a) of the Securities Exchange Act of 1934 requires our directors and executive officers, and persons who own beneficially
more than ten percent of our common stock, to file reports of ownership and changes of ownership with the Securities and Exchange
Commission. Based solely upon a review of Forms 3, 4 and 5 furnished to us during the fiscal year ended December 31, 2013, we
believe that the directors, executive officers, and greater than ten percent beneficial owners have complied with all applicable filing
requirements during the fiscal year ended December 31, 2013, with the exception of (i) a Form 4 that Edward Devereaux, a member of
the Board, filed late, (ii) a Form 3 and a Form 4 that Willard McAndrew, our Chief Operating Officer, filed late, (iii) a Form 4 that
Thomas Lapinski, our Chief Executive Officer, filed late, and (iv) a Form 3 and two Form 4’s that Robert Kenneth Dulin, significant
beneficial shareholder, filed late.
Code of Ethics
We have adopted a code of ethics that applies to our principal executive officer, principal financial officer, principal accounting officer or
controller, or persons performing similar functions. The Code of Ethics is available at our website at torchlightenergy.com. Further, we
undertake to provide by mail to any person without charge, upon request, a copy of such code of ethics if we receive the request in
writing by mail to: Torchlight Energy Resources, Inc., 5700 W. Plano Parkway, Suite 3600, Plano, Texas 75093.
Procedures for Stockholders to Recommend Nominees to the Board
There have been no material changes to the procedures by which stockholders may recommend nominees to our Board of Directors
since we last provided disclosure regarding this process.
Audit Committee
We have established a separately-designated standing audit committee. The Audit Committee consists of our four independent members
of the Board of Directors, Wayne Turner, Jerry Barney, Edward Devereaux and Eunis L. Shockey. Mr. Devereaux is the Chairman of
the Audit Committee, and the Board of Directors has determined that he is an audit committee financial expert as defined in Item 5(d)(5)
of Regulation S-K. The Audit Committee reviews, acts on and reports to the Board of Directors with respect to various auditing and
accounting matters, including the recommendations and performance of independent auditors, the scope of the annual audits, fees to be
paid to the independent auditors, and internal accounting and financial control policies and procedures.
ITEM 11. EXECUTIVE COMPENSATION
The following table provides summary information for the years 2013 and 2012 concerning cash and non-cash compensation paid or
accrued to or on behalf of certain executive officers.
29
Summary Executive Compensation Table
Year
Salary
($)
Bonus
($)
Stock
Awards
($)
Option
Awards
($)
Change in
Pension
Value
and
Nonqualified
Deferred
Compensation
($)
Non-Equity
Incentive
Plan
Compensation
($)
All Other
Compensation
($)
Name and
Principal
Position
Thomas Lapinski
CEO/Director
John A. Brda
President/Director
Willard G.
McAndrew III
COO/Director
Roger Wurtele
CFO
2013
2012
180,000
240,000 (2)
2013
2012
205,000
240,000 (4)
2013
2012
60,000
-
2013
2012
40,000
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
355,250 (1)
-
355,250 (3)
-
890,000 (5)
-
180,000 (7)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Total
($)
535,250
240,000
560,250
240,000
-
-
-
-
75,000 (6)
-
1,025,000
-
52,500 (6)
-
272,500
-
(1)
(2)
(3)
(4)
(5)
(6)
(7)
On September 4, 2013, we granted Mr. Lapinski a fully vested option to purchase 245,000 shares of stock at an exercise price
of $2.00 per share. The value of these options was determined using the Black Scholes Method.
In September 2013, Mr. Lapinski forgave a total of $489,000 in outstanding indebtedness in connection with his then accrued
and unpaid compensation, which included this unpaid salary for 2012.
On September 4, 2013, we granted Mr. Brda a fully vested option to purchase 245,000 shares of stock at an exercise price of
$2.00 per share. The value of these options was determined using the Black Scholes Method.
In September 2013, Mr. Brda forgave a total of $240,000 in outstanding indebtedness in connection with his then accrued and
unpaid compensation, which included this unpaid salary for 2012.
Prior to his appointment as COO in September, 2013, during 2013 we granted him a fully vested warrant to purchase 1,000,000
shares of stock at an exercise price of $2.09 per share as consideration for consulting services, which this value represents. The
value of these options was determined using the Black Scholes Method. In September 2013, we granted Mr. McAndrew an
option to purchase 1,500,000 shares of stock at an exercise price of $2.09 per share, which was to vest over upon certain
performance thresholds. The September 2013 options are not included in this table because they had not vested as December
31, 2013.
This amount represents consulting fees paid prior to the effective date of employment with the Company.
In October 2013, we granted Mr. Wurtele an option to purchase 300,000 shares of stock at an exercise price of $2.09 per share.
100,000 of the options vested immediately, with the remaining options to vest on the first and second anniversaries of his
employment. The value of these options was determined using the Black Scholes Method.
Employment Agreements
We have an employment agreement with Thomas Lapinski, our Chief Executive Officer, through Opal Marketing and Consulting, Inc. (“Opal”).
Mr. Lapinski owns and is the President of Opal. The agreement has an effective date as of July 1, 2013 and states that Opal will provide the
services of Mr. Lapinski to serve as our Chief Executive Officer. The agreement has a term that expires on June 30, 2014 and provides that we
will pay Opal a base fee equal to $15,000 per month. The agreement also provides for an increase in Opal’s base fee of (i) $5,000 per month when
we achieve 500 barrels of oil or gas equivalent per day (“BOEPD”) in net production (ii) an additional $5,000 per month when we achieve 750
BOEPD in net production, and (iii) an additional $5,000 per month when we achieve 1,000 BOEPD in net production. Opal is also eligible for a
discretionary annual bonus based on factors to be considered by the Board of Directors. The employment agreement includes a confidentiality
provision and a non-compete provision.
30
We entered into an employment agreement with John A. Brda, our president, in January 2012. The agreement, as amended in October 2013, has a
term that expires in December 2016 and provided for a base salary of $15,000 per month. The agreement was amended in January 2014 so that
effective the first of that month, his annual base salary increased to $300,000. He is also eligible for a discretionary annual bonus based on factors
to be considered by the Board of Directors. The employment agreement includes a confidentiality provision and a non-compete provision.
We entered into an employment agreement with Willard G. McAndrew III, our Chief Operating Officer, in September 2013. The agreement has
a term of three years and provided for a base salary of $15,000 per month. Additionally, the agreement granted Mr. McAndrew 1,500,000 stock
options in September 2013 that were to vest upon certain production thresholds being met by the company. The agreement was amended in January
2014 so that effective the first of that month, his annual base salary increased to $300,000 and all of the 1,500,000 options became fully vested.
These options are currently held by WMDM Family, Ltd. Mr. McAndrew is also eligible for a discretionary annual bonus based on factors to be
considered by the Board of Directors. The employment agreement includes a confidentiality provision and a non-compete provision.
We entered into an employment agreement with Roger Wurtele, our Chief Financial Officer, in October 2013 that has a term that ends in
September 2016 and provides for a base salary of $10,000 per month. Additionally, the agreement granted Mr. Wurtele 300,000 stock options in
October 2013, with 100,000 options vesting immediately and the remaining 200,000 options to vest upon the second and third anniversaries of his
employment. The agreement was amended in January 2014 so that effective the first of that month, his annual base salary increased to $180,000
and the remaining 200,000 options became fully vested. These options are currently held by Birch Glen Investments Ltd. Mr. Wurtele is also
eligible for a discretionary annual bonus based on factors to be considered by the Board of Directors. The employment agreement includes a
confidentiality provision and a non-compete provision.
Outstanding Equity Awards at Fiscal Year End
The following table details all outstanding equity awards held by our named executive officers at December 31, 2013:
Number of
Securities
Underlying
Unexercised
Options
(#)
Exercisable
Number of
Securities
Underlying
Unexercised
Options
(#)
Unexercisable
245,000
245,000
900,000(1)
-
100,000(3)
-
-
-
1,500,000(1)(2)
200,000(3)(4)
Option Awards
Equity bIncentive
Plan Awards: Number
of
Securities
Underlying
Unexercised
Unearned Options
(#)
-
-
-
-
-
Option
Exercise
Price
($)
2.00
2.00
2.09
2.09
2.09
Option
Expiration
Date
09/04/2018
09/04/2018
04/15/2018
09/09/2018
10/10/2018
Name
Thomas Lapinski
John A. Brda
Willard G. McAndrew III
Roger Wurtele
Mr. McAndrew gifted these options to WMDM Family, Ltd. The general partner and 1% owner of WMDM Family, Ltd. is a limited liability
These options were awarded to Mr. McAndrew in September 2013, and as of December 31, 2013 had not yet vested, and were to vest based on
(1)
company which is owned by a trust of which Mr. McAndrew is a beneficiary.
(2)
certain production thresholds being met by the Company. In January 2014, however, all of these options became vested.
(3)
of Birch Glen Investments Ltd.
(4)
second anniversaries of his employment with the Company. In January 2014, however, all of these options became vested.
Mr. Wurtele gifted these options to Birch Glen Investments Ltd. Mr. Wurtele and his wife together hold a 98% interest in the general partner
These options were awarded to Mr. Wurtele in October 2013, and as of December 31, 2013 had not yet vested, and were to vest on the first and
Compensation of Directors
At present, we do not pay our directors for attending meetings of the Board of Directors, although we may adopt a director
compensation policy in the future. We have no standard arrangement pursuant to which directors are compensated for any services they
provide or for committee participation or special assignments. We did, however, provide compensation to certain directors in the form
of restricted common stock during the year ended December 31, 2013 as follows:
31
Summary Director Compensation Table
Name
Wayne Turner
Jerry Barney
Edward Devereaux
Eunis L. Shockey
Fees Earned of
Paid in Cash
($)
-
-
-
-
Stock
Awards
($) (A)
102,250
72,750
72,750
72,750
Option
Awards
($)
Non-Equity
Incentive Plan
Compensation
($)
Nonqualified
Deferred
Compensation
Earnings
($)
All Other
Compensation
($)
-
-
-
-
-
-
-
-
-
-
-
-
Total
($)
102,250
72,750
72,750
72,750
-
-
-
-
(A)
(1)
(2)
Stock Value was determined using the Black Scholes Method.
Includes 50,000 restricted shares of common stock issued on November 1, 2013.
Includes 25,000 restricted shares of common stock issued on November 14, 2013.
Compensation Policies and Practices as they Relate to Risk Management
We attempt to make our compensation programs discretionary, balanced and focused on the long term. We believe goals and objectives
of our compensation programs reflect a balanced mix of quantitative and qualitative performance measures to avoid excessive weight on
a single performance measure. Our approach to compensation practices and policies applicable to employees and consultants is
consistent with that followed for its executives. Based on these factors, we believe that our compensation policies and practices do not
create risks that are reasonably likely to have a material adverse effect on us.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following table sets forth information, as of March 20, 2014, concerning, except as indicated by the footnotes below, (i) each
person whom we know beneficially owns more than 5% of our common stock, (ii) each of our directors, (iii) each of our named
executive officers and (iv) all of our directors and executive officers as a group. Unless otherwise noted below, the address of each
beneficial owner listed in the table is c/o Torchlight Energy Resources, Inc., 5700 W. Plano Parkway, Suite 3600, Plano, Texas 75093.
We have determined beneficial ownership in accordance with the rules of the SEC. Except as indicated by the footnotes below, we
believe, based on the information furnished to us, that the persons and entities named in the table below have sole voting and investment
power with respect to all shares of common stock that they beneficially own, subject to applicable community property laws. Applicable
percentage ownership is based on 18,270,408 shares of common stock outstanding at March 20, 2014. In computing the number of
shares of common stock beneficially owned by a person and the percentage ownership of that person, we deemed outstanding shares of
common stock subject to stock options or warrants held by that person that are currently exercisable or exercisable within 60 days of
March 20, 2014. We did not deem these shares outstanding, however, for the purpose of computing the percentage ownership of any
other person. Unless otherwise noted, stock options and warrants referenced in the footnotes below are currently fully vested and
exercisable. Beneficial ownership representing less than 1% is denoted with an asterisk (*).
32
Name and address of beneficial owner
Amount of beneficial
ownership
Percent of class
Thomas Lapinski
Chief Executive Officer and Director
John A. Brda
President, Secretary and Director
Willard G. McAndrew III
COO and Director
3,245,000 shares (1)
17.53%
2,757,500 shares (2)
14.89%
2,400,000 shares (3)
11.61%
Roger N. Wurtele
Chief Financial Officer
Jerry D. Barney
Director
Edward J. Devereaux
Director
Eunis L. Shockey
Director
Wayne Turner
Director
All directors and executive officers as a
group (eight persons)
Robert Kenneth Dulin
8449 Greenwood Drive
Niwot, Colorado, 80503
Sawtooth Properties, LLLP
8449 Greenwood Drive
Niwot, Colorado, 80503
300,000 shares (4)
330,715 shares (5)
35,000 shares
134,000 shares (6)
75,000 shares
1.62%
1.79%
*
*
*
9,277,215 shares
2,486,718 shares (7)
42.62%
12.62%
1,131,216 shares (8)
6.00%
(1)
Includes 3,000,000 shares of common stock and stock options that are exercisable into 245,000 shares of common stock.
(2)
(3)
(4)
Includes 182,500 shares of common stock and stock options that are exercisable into 245,000 shares of common stock,
both held individually by John A. Brda. Also includes 2,330,000 shares of common stock held by Brda & Company LLC.
Mr. Brda is the sole owner and Managing Director of this entity and has voting and investment authority over the shares
held by it.
Includes securities held by WMDM Family, Ltd., including warrants that are exercisable into 900,000 shares of common
stock and stock options that are exercisable into 1,500,000 shares of common stock. The general partner and 1% owner of
WMDM Family, Ltd. is a limited liability company of which Mr. McAndrew is the manager. He has voting and investment
authority over the shares held by WMDM Family, Ltd..
Includes stock options held by Birch Glen Investments Ltd. that are exercisable into 300,000 shares of common stock. Mr.
Wurtele and his wife together hold a 98% interest in the general partner of Birch Glen Investments Ltd., and Mr. Wurtele
shares voting and investment authority over the shares held by Birch Glen Investments Ltd. Additionally, the general
partner and 1% owner of WMDM Family, Ltd. (see footnote “(3)” above) is a limited liability company which is owned by
a trust of which Mr. Wurtele is the trustee. Securities held by WMDM Family, Ltd. are not included, however, because
Mr. Wurtele is not deemed to have voting or investment authority over the shares held by WMDM Family, Ltd.
33
(5)
Includes (a) 25,000 shares of common stock held individually by Dr. Barney; (b) securities held by an investment club,
including 50,000 shares of common stock, a 12% Series A Convertible Promissory Note that is convertible into 71,429
shares of common stock, and a Series A Warrant that is exercisable into 14,286 shares of common stock; and (c) securities
held by an entity that is wholly-owned by the Barney 2012 Children’s Trust, including 50,000 shares of common stock, a
12% Series A Convertible Promissory Note that is convertible into 100,000 shares of common stock, and a Series A
Warrant that is exercisable into 20,000 shares of common stock. Dr. Barney is a member of the investment club and shares
the voting and investment authority over the shares held by the club. Dr. Barney is a beneficiary of the Barney 2012
Children’s Trust and historically has had influence over decisions made by the trustee who has voting and investment
authority over the shares held by the trust.
(6)
Includes 34,000 shares of common stock and warrants that are exercisable into 100,000 shares of common stock.
(7)
Includes (a) 66,860 shares of common stock held individually by Robert Kenneth Dulin; (b) 209,500 shares of common
stock held in trust for the benefit of immediate family members of Mr. Dulin; (c) securities held by Sawtooth Properties,
LLLP (“Sawtooth”), including (i) 535,074 shares of common stock, (ii) warrants that are exercisable into 433,285 shares of
common stock and (iii) promissory notes that are convertible into up to 162,857 shares of common stock; (d) securities held
by another limited liability limited partnership (“LLLP2”), including (i) 125,000 shares of common stock, (ii) warrants that
are exercisable into 133,000 shares of common stock and (iii) promissory notes that are convertible into up to 90,000 shares
of common stock; and (e) securities held by a limited liability company (“LLC1”), including (i) 120,000 shares of common
stock, (ii) warrants that are exercisable into 448,285 shares of common stock and (iii) promissory notes that are convertible
into up to 162,857 shares of common stock. Mr. Dulin is trustee/custodian of each of the trusts and/or accounts referenced
in “(b)” above and has voting and investment authority over the shares held by them. Mr. Dulin is the Managing Partner of
Sawtooth Properties, LLLP, the Managing Partner of LLLP2 and the Managing Member of LLC1, and he has voting and
investment authority over the shares held by each entity.
(8)
Includes (i) 535,074 shares of common stock, (ii) warrants that are exercisable into 433,285 shares of common stock and
(iii) a promissory note that, as of June 18, 2013, is convertible into up to 162,857 shares of common stock. Robert
Kenneth Dulin is the Managing Partner of Sawtooth Properties, LLLP.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Director Independence
We currently have four independent directors on our Board, Wayne Turner, Jerry Barney, Edward Devereaux and Eunis L. Shockey.
The definition of “independent” used herein is based on the independence standards of The NASDAQ Stock Market LLC. The Board
performed a review to determine the independence of Wayne Turner, Jerry Barney, Edward Devereaux and Eunis L. Shockey and made
a subjective determination as to each of these directors that no transactions, relationships or arrangements exist that, in the opinion of the
Board, would interfere with the exercise of independent judgment in carrying out the responsibilities of a director of Torchlight Energy
Resources, Inc. In making these determinations, the Board reviewed information provided by these directors with regard to each
Director’s business and personal activities as they may relate to us and our management.
34
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The following table sets forth the fees paid or accrued by us for the audit and other services provided or to be provided by Calvetti
Ferguson, our independent registered public accountants, during the years ended December 31, 2013 and 2012.
2013
2012
$
Audit Fees(1)
Audit Related Fees(2)
Tax Fees(3)
All Other Fees
73,830 $
0
3,298
7,560
Total Fees
$
84,688 $
68,640
1,000
4,491
-
74,131
(1)
Audit Fees: This category represents the aggregate fees billed for professional services rendered by the principal independent
accountant for the audit of our annual financial statements and review of financial statements included in our Form 10-K and services
that are normally provided by the accountant in connection with statutory and regulatory filings or engagements for the fiscal years.
(2)
Audit Related Fees: This category consists of the aggregate fees billed for assurance and related services by the principal
independent accountant that are reasonably related to the performance of the audit or review of our financial statements and are not
reported under “Audit Fees.”
(3)
Tax Fees: This category consists of the aggregate fees billed for professional services rendered by the principal independent
accountant for tax compliance, tax advice, and tax planning.
Pre-Approval of Audit and Non-Audit Services
We did not have a standing audit committee of the board of directors until November, 2013. Therefore, for the fiscal years ended
December 31, 2013 and 2012, all audit services, audit-related services and tax services for 2012, as described above, were provided to
us by Calvetti Ferguson based upon prior approval of the Board of Directors. Whitley Penn has been engaged for tax services for the
year 2014 including preparation of 2013 tax returns.
35
ITEM 15. EXHIBITS
Exhibit No. Description
PART IV
2.1
3.1
3.2
10.1
Share Exchange Agreement dated November 23, 2010. (Incorporated by reference from Form 8-K filed with the SEC
on November 24, 2010.) *
Articles of Incorporation. (Incorporated by reference from Form S-1 filed with the SEC on May 2, 2008.) *
Amended and Restated Bylaws (Incorporated by reference from Form 8-K filed with the SEC on January 12, 2011.) *
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
Employment Agreement with Thomas Lapinski (Incorporated by reference from Form 8-K filed with the SEC on
October 15, 2013.) *
10.4
Employment Agreement with John A. Brda (Incorporated by reference from Form 8-K filed with the SEC on October
10.5
10.6
10.7
10.8
15, 2013.) *
Amendment to Employment Agreement with John A. Brda
Employment Agreement with Roger Wurtele (Incorporated by reference from Form 8-K filed with the SEC on October
15, 2013.) *
Amendment to Employment Agreement with Roger Wurtele
Employment Agreement with Willard McAndrew III (Incorporated by reference from Form 8-K filed with the SEC on
October 15, 2013.) *
10.9
Amendment to Employment Agreement with Willard McAndrew III (Incorporated by reference from Form 8-K filed
with the SEC on October 15, 2013.) *
10.10
10.11
14.1
21.1
31.1
Second Amendment to Employment Agreement with Willard McAndrew III
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.) *
Code of Ethics (Incorporated by reference from Form S-1 filed with the SEC on May 2, 2008.) *
Subsidiaries.
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.
99.1
Report of Netherland, Sewell & Associates, Inc. and Wright & Company, Inc.
36
101.INS
101.SCH
101.CAL
101.DEF
101.LAB
101.PRE
XBRL Instance Document
XBRL Taxonomy Extension Schema
XBRL Taxonomy Extension Calculation Linkbase
XBRL Taxonomy Extension Definitions Linkbase
XBRL Taxonomy Extension Label Linkbase
XBRL Taxonomy Extension Presentation Linkbase
* Incorporated by reference from our previous filings with the SEC
37
Pursuant to the requirements of Section 13 or 15(d) 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.
SIGNATURES
Torchlight Energy Resources, Inc.
/s/ Thomas Lapinski
By: Thomas Lapinski
Chief Executive Officer
Date:
March 31, 2014
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on
behalf of the registrant and in the capacities and on the dates indicated:
Signature
Title
Date
/s/ Thomas Lapinski
Thomas Lapinski
/s/ John A. Brda
John A. Brda
/s/ Willard G. McAndrew III
Willard G. McAndrew III
/s/ Roger N. Wurtele
Roger N. Wurtele
/s/ Wayne Turner
Wayne Turner
/s/ Jerry D. Barney
Jerry D. Barney
/s/ Edward J. Devereaux
Edward J. Devereaux
/s/ Eunis L. Shockey
Eunis L. Shockey
Director and Chief Executive Officer
March 31, 2014
Director, President and Secretary
March 31, 2014
Director and Chief Operating Officer
March 31, 2014
Chief Financial Officer
March 31, 2014
Director
Director
Director
Director
38
March 31, 2014
March 31, 2014
March 31, 2014
March 31, 2014
AMENDMENT TO EMPLOYMENT AGREEMENT
THIS AMENDMENT TO EMPLOYMENT AGREEMENT (“Amendment Agreement”) is executed on March 24,
2014 with an effective date of January 1, 2014, by and among John A. Brda, an individual (“Employee”), and Torchlight
Energy Resources, Inc., a Nevada corporation (the “Company”). The Employee and the Company are sometimes hereinafter
collectively referred to as the “Parties”.
A.
Employee and the Company entered into an Employment Agreement on October 10, 2013 with an effective
date of July 1, 2013 (the “Contract”).
Recitals
B.
C.
Reference is here made to the Contract as if such Contract were written herein verbatim.
The Parties now wish to amend the Contract to change certain terms of the Contract.
Agreements
NOW, THEREFORE, in consideration of the foregoing, and other good and valuable consideration, the receipt and
sufficiency of which are hereby acknowledged, the Parties agree as follows:
1.
All capitalized terms used herein shall have the meanings assigned to them in the Contract, unless expressly
defined otherwise in this Amendment Agreement.
2.
Except as otherwise specifically provided herein, all terms and conditions of the Contract shall apply to the
interpretation and enforcement of this Amendment Agreement as if explicitly set forth herein.
3.
Amendment to Subsection (a), “Base Fees” of Section 4, “Compensation”:
Subsection (a) of Section 4 of the Contract is amended and replaced in its entirety to read as follows:
“(a)
Base Fees. The Company shall pay Employee Base Fees (the “Base Fees”) equal to $300,000 per
year, effective January 1, 2014. Payment shall be made monthly, on the last day of each calendar month.
4.
This Amendment Agreement will be of no force and effect until receipt and execution of this Amendment
Agreement by all the undersigned parties hereto. This Amendment Agreement may be executed in counterparts, each of which
shall be deemed an original, but all of which shall be deemed one instrument, by signature delivered by facsimile transmission or
by e-mail delivery of a “.pdf” format data file, each of which shall be deemed an original for all purposes.
5.
Except as expressly amended hereby, the Contract remains in full force and effect. Any references to the
Contract shall refer to the Contract as amended hereby.
Amendment to Employment Agreement - Page 1
IN WITNESS WHEREOF, the undersigned have executed this Amendment Agreement on the date set forth above.
TORCHLIGHT ENERGY RESOURCES, INC.
/s/ Thomas Lapinski
By: Thomas Lapinski, Chief Executive Officer
/s/ John A. Brda
John A. Brda
Amendment to Employment Agreement - Page 2
AMENDMENT TO EMPLOYMENT AGREEMENT
THIS AMENDMENT TO EMPLOYMENT AGREEMENT (“Amendment Agreement”) is executed on March 24,
2014 with an effective date of January 1, 2014, by and among Roger Wurtele, an individual (“Employee”), and Torchlight
Energy Resources, Inc., a Nevada corporation (the “Company”). The Employee and the Company are sometimes hereinafter
collectively referred to as the “Parties”.
A.
Employee and the Company entered into an Employment Agreement on October 10, 2013 with an effective
date of September 9, 2013 (the “Contract”).
Recitals
B.
C.
Reference is here made to the Contract as if such Contract were written herein verbatim.
The Parties now wish to amend the Contract to change certain terms of the Contract.
Agreements
NOW, THEREFORE, in consideration of the foregoing, and other good and valuable consideration, the receipt and
sufficiency of which are hereby acknowledged, the Parties agree as follows:
1.
All capitalized terms used herein shall have the meanings assigned to them in the Contract, unless expressly
defined otherwise in this Amendment Agreement.
2.
Except as otherwise specifically provided herein, all terms and conditions of the Contract shall apply to the
interpretation and enforcement of this Amendment Agreement as if explicitly set forth herein.
3.
Amendment to Subsection (a), “Base Fees” of Section 4, “Compensation”:
Subsection (a) of Section 4 of the Contract is amended and replaced in its entirety to read as follows:
“(a)
Base Fees. The Company shall pay Employee Base Fees (the “Base Fees”) equal to $180,000 per
year, effective January 1, 2014. Payment shall be made monthly, on the last day of each calendar month. The Employee
will be entitled to increases in Base Fees subject to the following provisions.
4.
Amendment to Subsection (d), “Stock Options” of Section 4, “Compensation”:
Subsection (d) of Section 4 of the Contract is amended to accelerate the date of vesting only and shall be amended and
replaced in its entirety to read as follows:
“(d)
Stock Options. As additional compensation for the services to be rendered by Employee pursuant to
this Agreement, the Company shall grant to Employee stock options to purchase a total of 300,000 shares of Common
Stock of the Company for five years at a price equal to $2.09 per share (the “Stock Options”). At signing, the Company
shall issue Employee the 300,000 Stock Options. 100,000 of the Stock Options will vest immediately with the balance of
the Stock Options vesting on January 1, 2014.
The Stock Options will be in addition to and not in lieu of any stock issued pursuant to an ESOP, 401K, or other
retirement plan as the Company may make generally available to senior executives or other employees.”
5.
This Amendment Agreement will be of no force and effect until receipt and execution of this Amendment
Agreement by all the undersigned parties hereto. This Amendment Agreement may be executed in counterparts, each of which
shall be deemed an original, but all of which shall be deemed one instrument, by signature delivered by facsimile transmission or
by e-mail delivery of a “.pdf” format data file, each of which shall be deemed an original for all purposes.
6.
Except as expressly amended hereby, the Contract remains in full force and effect. Any references to the
Contract shall refer to the Contract as amended hereby.
Amendment to Employment Agreement - Page 1
IN WITNESS WHEREOF, the undersigned have executed this Amendment Agreement on the date set forth above.
TORCHLIGHT ENERGY RESOURCES, INC.
/s/ Thomas Lapinski
By: Thomas Lapinski, Chief Executive Officer
/s/ Roger Wurtele
Roger Wurtele
Amendment to Employment Agreement - Page 2
SECOND AMENDMENT TO EMPLOYMENT AGREEMENT
THIS SECOND AMENDMENT TO EMPLOYMENT AGREEMENT (“Amendment Agreement”) is executed on
March 24, 2014 with an effective date of January 1, 2014, by and among Willard G. McAndrew III, an individual
(“Employee”), and Torchlight Energy Resources, Inc., a Nevada corporation (the “Company”). The Employee and the
Company are sometimes hereinafter collectively referred to as the “Parties”.
Recitals
A.
Employee and Torchlight Energy, Inc., a subsidiary of the Company, entered into an Employment Agreement
on April 13, 2013, which agreement became effective on September 9, 2013 (the “Contract”).
B.
Effective October 10, 2013, the Contract was amended, whereby, among other amendments, the sole parties to
the Contract became Employee and the Company.
C.
verbatim.
Reference is here made to the Contract, as amended, as if such Contract, as amended, were written herein
D.
The Parties now wish to amend the Contract, as amended, to change certain terms therein.
Agreements
NOW, THEREFORE, in consideration of the foregoing, and other good and valuable consideration, the receipt and
sufficiency of which are hereby acknowledged, the Parties agree as follows:
1.
All capitalized terms used herein shall have the meanings assigned to them in the Contract, as amended, unless
expressly defined otherwise in this Amendment Agreement.
2.
Except as otherwise specifically provided herein, all terms and conditions of the Contract, as amended, shall
apply to the interpretation and enforcement of this Amendment Agreement as if explicitly set forth herein.
3.
Amendment to Subsection (a), “Base Fees” of Section 4, “Compensation”:
Subsection (a) of Section 4 of the Contract, as amended, is amended and replaced in its entirety to read as follows:
“(a)
Base Fees. The Company shall pay Employee Base Fees (the “Base Fees”) equal to $300,000 per
year, effective January 1, 2014. Payment shall be made monthly, on the last day of each calendar month.
4.
Amendment to Subsection (d), “Stock Options” of Section 4, “Compensation”:
Subsection (d) of Section 4 of the Contract is amended to accelerate the date of vesting only and shall be amended and
replaced in its entirety to read as follows:
“(d)
Stock Options. As additional compensation for the services to be rendered by Employee pursuant to
this Agreement, the Company shall grant to Employee stock options to purchase a total of 1,500,000 shares of Common
Stock of the Company (the “Stock Options”) at a price equal to $2.09 per share. All of the Stock Options will vest to
Employee on January 1, 2014.
The Stock Options will be in addition to and not in lieu of any stock issued pursuant to an ESOP, 401K, or other
retirement plan as the Company may make generally available to senior executives or other employees. The Stock
Options are also in addition to the 1,000,000 warrants to purchase Common Stock of the Company that the Company
issued to Mr. McAndrew on or about April 15, 2013 as consideration for consulting services he performed.”
Second Amendment to Employment Agreement - Page 1
5.
This Amendment Agreement will be of no force and effect until receipt and execution of this Amendment
Agreement by all the undersigned parties hereto. This Amendment Agreement may be executed in counterparts, each of which
shall be deemed an original, but all of which shall be deemed one instrument, by signature delivered by facsimile transmission or
by e-mail delivery of a “.pdf” format data file, each of which shall be deemed an original for all purposes.
6.
Except as expressly amended hereby, the Contract, as amended in October 2013, remains in full force and
effect. Any references to the Contract shall refer to the Contract as amended in October 2013 and as amended hereby.
IN WITNESS WHEREOF, the undersigned have executed this Amendment Agreement on the date set forth above.
TORCHLIGHT ENERGY RESOURCES, INC.
/s/ Thomas Lapinski
By: Thomas Lapinski, Chief Executive Officer
/s/ Willard G. McAndrew III
Willard G. McAndrew III
Second Amendment to Employment Agreement - Page 2
Exhibit 21.1
Subsidiaries of the Registrant
Torchlight Energy, Inc.
Torchlight Energy Operating, LLC
Name
State of Organization
Nevada
Texas
Exhibit 31.1
CERTIFICATION PURSUANT TO SECTION 302 OF THE
SARBANES-OXLEY ACT OF 2002
I, Thomas Lapinski, Chief Executive Officer of Torchlight Energy Resources, Inc., certify that:
1. I have reviewed this annual report on Form 10-K of Torchlight Energy Resources, Inc. for the year ended December 31,
2013;
2. Based on my knowledge, this annual 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 annual report;
3. Based on my knowledge, the financial statements, and other financial information included in this annual 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 annual 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 annual 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 annual
report based on such evaluation; and
d) Disclosed in this annual 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/ Thomas Lapinski
By: Thomas Lapinski,
Chief Executive Officer (Principal Financial Officer)
Date: March 31, 2014
Exhibit 31.2
CERTIFICATION PURSUANT TO SECTION 302 OF THE
SARBANES-OXLEY ACT OF 2002
I, Roger Wurtele, Chief Financial Officer of Torchlight Energy Resources, Inc., certify that:
1. I have reviewed this annual report on Form 10-K of Torchlight Energy Resources, Inc. for the year ended December 31,
2013;
2. Based on my knowledge, this annual 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 annual report;
3. Based on my knowledge, the financial statements, and other financial information included in this annual 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 annual 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 annual 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 annual
report based on such evaluation; and
d) Disclosed in this annual 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: March 31, 2014
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, Thomas Lapinski, Chief Executive Officer, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002, that the Annual Report on Form 10-K of Torchlight Energy Resources, Inc. for the fiscal year
ended December 31, 2013, 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 Annual Report on Form 10-K fairly presents, in all material respects, the financial
condition and results of operations of Torchlight Energy Resources, Inc.
/s/ Thomas Lapinski
Thomas Lapinski,
Chief Executive Officer (Principal Executive Officer)
Date: March 31, 2014
I, Roger Wurtele, Chief Financial Officer, certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002, that the Annual Report on Form 10-K of Torchlight Energy Resources, Inc. for the fiscal year
ended December 31, 2013, 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 Annual Report on Form 10-K 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: March 31, 2014
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.