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, 2011.
. 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.)
2007 Enterprise Avenue
League City, Texas 77573
(Address of principal executive offices)
(281) 538-5938
(Registrant’s telephone number, including area code)
Securities registered under Section 12(g) of the Exchange Act:
Common Stock ($0.001 Par Value)
(Title of Each Class)
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, 2011, the aggregate market value of shares held by non-affiliates of the registrant (based upon 6,622,161 shares held by non-affiliates on
June 30, 2011) was approximately $23,177,563.
At March 20, 2012, there were 14,789,815 shares of the registrant’s common stock outstanding (the only class of common stock).
None.
DOCUMENTS INCORPORATED BY REFERENCE
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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. Originally, our primary
business objective was to develop and market fitness dance studios that offered an alternative to traditional gyms. From our
incorporation to November 2010, we was primarily engaged in business planning activities, including researching dance studio design
trends, developing economic models and financial forecasts, performing due diligence regarding potential store front locations,
investigating and analyzing income and age demographics for areas surrounding potential locations, evaluating the community’s attitude
toward our business and searching for providers of additional capital to finance the build-out of our first location.
On November 23, 2010, we entered into and closed a Share Exchange Agreement (the “Exchange Agreement”) with Tammy Skalko, an
executive officer, director and major stockholder, James Beshara, a director and major stockholder, Harry Stone II, a major stockholder,
Torchlight Energy, Inc. ("TEI"), and the persons owning 100% of the outstanding capital stock of TEI (the “TEI Stockholders”). At
closing, the TEI Stockholders transferred all of their shares of TEI common stock to us in exchange for an aggregate of 9,444,500
newly issued shares of our common stock. Also at closing of the Exchange Agreement, Ms. Skalko, Mr. Beshara and Mr. Stone
transferred to us an aggregate of 14,400,000 shares of our common stock for cancellation in exchange for aggregate consideration of
$270,000. Upon closing of these transactions, we had 12,251,420 shares of common stock issued and outstanding. The 9,444,500
shares issued to the TEI Stockholders at closing represented 77.1% of our voting securities.
As a result of the transactions effected by the Exchange Agreement, at closing (i) TEI became our wholly-owned subsidiary, (ii) we
abandoned all of our previous business plans within the health and fitness industries, including opening and operating dance studios,
and (iii) 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. It is engaged in the acquisition, exploration, exploitation and/or development of oil and natural gas
properties in the United States. Descriptions of our business hereinafter refer to the business of TEI.
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. The share
amounts reflected throughout this report take into account the 4-for-1 forward split.
Effective February 8, 2011, we changed our name from “Pole Perfect Studios, Inc.” to “Torchlight Energy Resources, Inc.” In
connection with the name change, our ticker symbol changed from “PPFT” to “TRCH,” effective February 10, 2011.
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 two oil and gas projects, the
Marcelina Creek Field Development and the Coulter Field, as is 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 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 executive officers, Thomas Lapinski and John Brda. We will
also receive guidance from outside advisors and will align with high quality vendor partners.
Project Focus. We are focusing on exploitation and low risk exploration projects to reduce risk by pursuing resources where
commercial production has already been established but where opportunity for additional and nearby development is indicated.
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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. Only enough 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.
Project Focus
Generally, we will focus on low 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. Initially, a large percentage of our assets will be being
allocated to the Marcelina Creek Field Development and the Coulter Field. After we have raised or generated sufficient capital, we will
attempt to diversify our portfolio so that not greater than 25-30% of our capital is allocated in a particular project, of which there can be
no assurance. An exception for a higher percentage would be an acquisition of a producing property with positive cash flow or smaller
investment opportunities. Each opportunity will be investigated on a stand alone basis for both technical and financial merit. High risk
exploration prospects are less favored than low risk exploration. 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 exploitation 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, such as Jebco,
and from the large informal community of geoscientists and engineers. Building a network of advisors is key to the pipeline of high
quality opportunities. We believe the company will be well represented and networked.
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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
rarely 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. A single outsourced vendor that provides
all or a majority of these services has not yet been located. Collectively, however, these services are available from a variety of
experienced sources.
Current Projects
We currently have only two interests in oil and gas projects, the Marcelina Creek Field Development and the Coulter Field.
Marcelina Creek Field Development.
On July 6, 2010, TEI entered into an Agreement to Participate in Oil and Gas Development Joint Venture (the “Participation
Agreement”) with Bayshore Operating Corporation, LLC (“Bayshore”). Bayshore is currently the holder of an oil, gas and mineral
lease covering approximately 1,045 acres in Wilson County, Texas, known as the Marcelina Creek Field Development. The
Participation Agreement provides for the drilling of four wells, one of which is a horizontal re-entry well within the 280 Johnson Unit
(the Johnson #1 well). The remaining three are to be vertical development wells at locations to be determined within the existing lease.
TEI paid Bayshore an initial $50,000 deposit in July 2010, which amount was credited to the initial $50,000 payment due at the rig
move in for the first well, the Johnson #1-BH. TEI is responsible for 100% of total drilling and completion costs for this re-entry well,
in return for a 50% working interest. In August 2010, drilling on the first well commenced, with the drilling of a lateral section of the
Buda Formation of approximately 1840 feet. The Johnson #1-BH encountered good oil and gas shows and a completion was
attempted. The well, however, produced large volumes of water, some introduced by Bayshore during drilling and some from another
source, either a deeper formation or from a nearby well. In July 2011 a workover crew was brought in to service the well, replace a
broken rod and re-work the downhole pump. On July 27, 2011, the crew dropped two joints of pipe in the hole and on July 28 another
six joints. The well was damaged sufficiently to be “shut-in” (meaning the valves at the wellhead have been closed so that the well
stops pumping). The service company, Mercer Well Services, was notified of the damage and a meeting was to be arranged to settle the
claim Bayshore and Torchlight would file against Mercer. After conducting interviews and preparing documents and displays, a
meeting with Mercer representatives was ultimately held on February 1, 2012. We anticipate continuing discussions with Mercer to
resolve this matter.
On December 31, 2010 TEI executed an agreement with Bayshore for an extension of our drilling obligation deadline under the
Participation Agreement. As a condition for the extension we paid to Bayshore $50,000 and issued it 10,000 shares of our common
stock. As additional consideration, Bayshore is no longer obligated to pay its proportionate share of completion costs on the third well
(the second vertical well) under the Participation Agreement.
On April 15, 2011, TEI exercised its option to continue with the development program in Marcelina Creek by committing to the second
well in the program (the first vertical development location well), the Johnson #4 well. We paid to Bayshore the $50,000 rig move in
and paid drilling and completion costs of approximately $1.6 million for a 75% working interest in the well. We are also obligated to
pay $200,000 when the well is completed or plugged and abandoned. A rig was contracted and moved in to drill the well and drilling
operations began in July 2011. The well encountered several pay zones and an attempt to complete in the Buda Formation was made.
We have encountered several mechanical and pump problems with the well which has delayed completion. After correcting the
mechanical problems, in February 2012 the well was acidized (a technique involving pumping hydrochloric acid into the well under
high pressure to reopen and enlarge the pores in the oil-bearing formations), and subsequently we have seen more stabilized flow in the
well. We are currently performing various tests on the well to estimate its daily deliverability, payout, and reserves.
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No further action is being done in the field at this time. If we opt to continue with the third and fourth wells contemplated by the
Participation Agreement, TEI is obligated to pay Bayshore $50,000 at rig move in and $150,000 when the well is completed or plugged
and abandoned for each well. For the third well, we will be responsible for 100% of the total drilling costs and 100% of the completion
costs, for a 75% working interest in the well. For the fourth well, we will be responsible for 100% of the total drilling costs and 75%
of the completion costs (with Bayshore to pay 25% of the completion costs), for a 75% working interest in the well. TEI will also
receive a 75% working interest on any subsequent wells drilled outside of the Johnson unit, with work to be done, as and when
proposed, on a pro rata basis.
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. Based on the work Bayshore has already performed, we believe
the Johnson unit re-entry is one of these opportunities. The original lateral well was drilled out to about 500 feet. The well encountered
a fracture zone and test-at rates of approximately 300 barrels per day. The operator attempted to drill out further when they experienced
a casing collapse, causing the well to fail. We believe sub-paralleling the original well bore will yield a high probability of similar
results, of which there can be no assurance. The negative side is the uncertainty of encountering fractures in the vertical wells.
Horizontal wells will, almost with certainty, encounter some fractures, but the number, and thereby production rates, are difficult to
predict.
Coulter Field
On January 10, 2012, we entered into a farm-in agreement, titled the “Coulter Limited Partnership Agreement” (the “Coulter
Agreement”), with La Sal Energy, LLC (“La Sal”). La Sal owns a 100% working interest and a 75% net revenue interest in certain oil,
gas and mineral leases in Waller County, Texas, upon which the well known as “John Coulter #1-R” is located. Pursuant to the Coulter
Agreement, we acquired a 34% working interest and a 34% net revenue interest in La Sal’s interest in the John Coulter #1-R for the
purchase price of $350,000. It is anticipated this amount will fund the fracing of the well. Upon production, the net revenue split will
be 80% to us and 20% to La Sal until net revenue is an accumulated $437,500. During this period, expenses above the $350,000
initially paid in will be split according to actual percentage interests in the well. After net revenue is an accumulated $437,500, net
revenue will be split according to the actual percentage interests in the well. The Coulter Agreement also provides us with multiple
options under which we can acquire additional interests in La Sal’s interest in the well. The well was stimulated on February 22, 2012,
and we are awaiting completion.
Project Prospects
We are in the process of indentifying 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. Below are some of the projects that we are currently
evaluating. There is no assurance we will choose to invest in any of these projects, if and when adequate funding becomes available.
Southwest Nebraska - Denver-Julesberg Basin
The Denver-Julesberg Basin is one of the largest sedimentary basins in the United States. It has been an oil and gas producer for most
of the previous century. We have located a prospective project in the northeastern portion of the basin, primarily within Nebraska. The
potential reservoirs are well known and well established through the basin and in this area. We believe the likelihood of finding
commercial oil production is the area is high, as there are numerous producing wells in the area. Most of the reservoirs in the area are at
a modest depth which should equate to low drilling costs and a short drilling and completion time.
Fossil Energy, Inc. (“Fossil Energy”), an operator, had been looking for an investor to fund a drilling program for up to 50 wells. The
locations are based on relatively inexpensive technologies incorporated in the oil industry, including magnetic impulse, radiometric and
geo-chemical surveys. In September 2010, TEI and Fossil Energy entered into a Technical Services Contract and Working Interest
Agreement. The agreement provides for Fossil Energy to develop prospects for oil and gas development. Following a geo-chemical
survey a detailed subsurface geological study on the area was finalized in late 2011. That study showed a prospective area for the
Cretaceous aged Muddy channel sands. We are presently seeking a farm-in partner to drill two wells this summer.
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Business Environment
Over half of United States’ crude oil is now imported because growth in demand exceeds domestic production, and this ratio is
projected to increase into the foreseeable future. Although crude oil prices have been variable in recent years, longer-term global
demand, especially from Asia and the Asian sub-continent is expected to offset growth in global supply, thus creating a continuous,
although at times volatile, upward pressure on price. Further, new sources of international oil and gas reserves are located either far
inland to existing port facilities or in very deep water. These new discoveries demand large capital investments for pipeline
transportation and facilities. In the case of inland discoveries, agreements among sovereign governments may be required. Long
negotiations result in long lead times from discovery to markets. Similarly for very deep water discoveries, both confirmation drilling
and facilities construction require long lead times.
To complicate the environment even further, the recent BP oil spill in the Gulf of Mexico caused the United States government to place
a moratorium on deep water drilling from May to October 2010. The moratorium’s long-term effect on price is still speculative. We
believe the short-term effect on activity is that companies that had budgeted for capital projects in the offshore area for 2011 and 2012
have needed to invest in other exploration and production activities. Management envisions the companies that were operating offshore
to focus some attention to onshore activities.
For United States natural gas, depressed prices resulted from the past two warm winter that reduced heating demand, the ability of the
industry to increase production from shales with horizontal drilling, and increased production from the Gulf of Mexico. Prices will be
volatile and subject to market emotions of early cold winters and other climatic conditions. This situation may offer an opportunity to
acquire producing properties from numerous small producers who are impaired with high fixed overhead and sizable debt loads from
earlier years. We, however, will favor oil projects but will investigate any opportunity on a stand alone basis.
With timely, accessible project finance arrangements, management believes we can profit from the opportunities provided by small
producers that are virtually ignored by the major producers and large independents.
Industry Overview
The oil and gas industry has undergone a renaissance in both the balance of supply and demand and in technological advances. In
recent years, large petroleum companies have migrated their spending toward exploration and production projects overseas and
offshore, particularly deep water, as well as into downstream ventures. Such companies have consolidated their United States onshore
investments into core geographic areas. The majors and large independents follow the rule that “90% of our revenue comes from 10%
of our properties.”
The majors and large independents are, in varying degrees, burdened with high infrastructure overhead that when allocated to these
properties make the properties unattractive for additional investment. The infrastructure for large companies includes services for
human resources, information technology, accounting, land and division orders, and legal departments. Divesting of these non-core
properties was made to independents and start-up companies. Independents also acquired large areas of leases particularly in the
Haynesville, Marcelius, Bakken and now the Eagleford shale. This required the companies to drill quickly or lose the leases. That
focus may have left some other on-going fields to be without re-investment. We believe this gradual migration of spending has
possibly left onshore opportunities for nimble and experienced, lower cost oil and gas producers.
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.
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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:
·
·
·
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.
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.
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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 two 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 five independent technical professionals under consulting agreements, all of whom are
available to us on an as needed basis.
Research and Development
During the fiscal years ended December 31, 2011 and 2010, respectively, we did not spend any funds on research and development
activities.
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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.
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. There is nothing 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 we
obtain interests in, if any, 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.
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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.
There is substantial doubt about our ability to continue as a going concern
At December 31, 2011, we had not yet achieved profitable operations, had accumulated losses of $2,613,494 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.
To date we have not implemented various corporate governance measures, in the absence of which, stockholders may have
more limited protections against interested director transactions, conflicts of interest and similar matters.
As of the date of this report we have not adopted certain corporate governance measures. Although not required by rules or regulations
applicable to us, corporate governance measures such as the establishment of an audit committee and other independent committees of
our Board of Directors, would be beneficial to our stockholders. We do not presently maintain any of these protections for our
stockholders. It is possible that if we were to adopt corporate governance measures, stockholders would benefit from greater assurance
that decisions were being made with impartiality by directors and that policies had been implemented to define conduct of our
management and board members.
As a non-operator, our development of successful operations relies extensively on third-parties who, if not successful, could
have a material adverse affect on our results of operation.
We anticipate only participating in wells operated by third-parties. Our ability to develop successful business operations depends on the
success of our consultants and drilling partners. As a result, we will not control the timing or success of the development, exploitation,
production and exploration activities relating to leasehold interests we acquire. If our consultants and drilling partners are not successful
in such activities relating to such leasehold interests, or are unable or unwilling to perform, our financial condition and results of
operation would be materially adversely affected.
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, we could become insolvent.
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.
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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.
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.
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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.
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.
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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 future estimates of the volume of reserves we obtain 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.
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.
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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 will 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 Chief Executive Officer, Thomas Lapinski, and our
President, John Brda. Mr. Lapinski and Mr. Brda each 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 Mr. Lapinski and Mr.
Brda would be difficult to replace. While neither have plans to leave or retire in the near future, the loss of either 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 Mr. Lapinski or Mr. Brda. We have an employment agreement with Mr.
Brda, and there is an employment agreement between Mr. Lapinski and TEI, our wholly owned subsidiary. There can be no assurance,
however, that Mr. Lapinski or Mr. Brda will continue to be employed by us.
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Our affiliates 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, Thomas Lapinski and John Brda, collectively and beneficially own approximately
48.09% of our outstanding common stock. Further, the five members of our Board of Directors, of which Messrs. Lapinski and Brda
are members, collectively and beneficially own approximately 51.13% 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 new
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 OTC Bulletin Board. However, our shares 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.
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The issuance of preferred stock could adversely affect the rights of the holders of common stock.
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. The issuance of preferred stock by the Board of Directors could adversely affect the rights of the holders
of common stock. For example, such issuance could result in a class of securities outstanding that would have preferences with respect
to voting rights and dividends and in liquidation over the common stock, and could (upon conversion or otherwise) enjoy all of the
rights appurtenant to common stock. The Board's authority to issue preferred stock could discourage potential takeover attempts and
could delay or prevent a change in control of the company through merger, tender offer, proxy contest or otherwise by making such
attempts more difficult to achieve or more costly. There are no issued and outstanding shares of preferred stock; there are no agreements
or understandings for the issuance of preferred stock, and the Board of Directors has no present intention to issue preferred stock.
We may be subject to penny stock regulations and restrictions, and you may have difficulty selling shares of our common
stock.
The SEC has adopted regulations which generally define a “penny stock” as an equity security that has a market price less than $5.00
per share or an exercise price of less than $5.00 per share, subject to certain exemptions. Our common stock is a “penny stock” and is
subject to Rule 15g-9 under the Exchange Act, or the “Penny Stock Rule.” This rule imposes additional sales practice requirements on
broker-dealers that sell such securities to persons other than established customers and “accredited investors” (generally, individuals
with a net worth in excess of $1,000,000, excluding the value of the primary residence of such individuals, or annual incomes
exceeding $200,000, or $300,000 together with their spouses). For transactions covered by Rule 15g-9, a broker-dealer must make a
special suitability determination for the purchaser and have received the purchaser's written consent to the transaction prior to sale. As a
result, this rule may affect the ability of broker-dealers to sell our securities and may affect the ability of purchasers to sell any of our
securities in the secondary market, thus possibly making it more difficult for us to raise additional capital.
For any transaction involving a penny stock, unless exempt, the rules require delivery, prior to any transaction in penny stock, of a
disclosure schedule required by the SEC relating to the penny stock market. Disclosure is also required to be made about sales
commissions payable to both the broker-dealer and the registered representative and current quotations for the securities. Finally,
monthly statements are required to be sent disclosing recent price information for the penny stock held in the account and information
on the limited market of penny stocks.
There can be no assurance that our common stock will qualify for exemption from the Penny Stock Rule. In any event, even if our
common stock were exempt from the Penny Stock Rule, we would remain subject to Section 15(b)(6) of the Exchange Act, which
gives the SEC the authority to restrict persons from participating in a distribution of a penny stock, under certain circumstances, if the
SEC finds that such a restriction would be in the public interest.
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.
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.
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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 officers are located at 2007 Enterprise Avenue, League City, Texas 77573. We do not own any real property.
The office space for our executive offices is currently being provided to us at no charge by our Chief Executive Officer. We believe that
the condition and size of our executive offices are satisfactory, suitable and adequate for our current needs.
We currently have only two interests in oil and gas projects, the Marcelina Creek Field Development and the Coulter Field Well. See
the description under “Current Projects” above for more information. To date, we have produced very limited oil and gas and have no
proved or probable oil and gas reserves.
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. The lawsuit is in connection with farmout agreements we entered into with Hockley Energy in November 2011 for the
Marcelina Creek prospect and the East Stockdale prospect. We allege that Hockley Energy did not perform its obligations under the
agreements, which obligations included providing the agreed upon funding, and we seek damages against both Hockley and Mr.
Snortheim (who is a shareholder of Hockley Energy) for breach of contract, fraudulent inducement and promissory estoppel. The
defendants have not yet filed an answer to our original petition.
ITEM 4. MINE SAFETY DISCLOSURES
Not Applicable.
18
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 Over-the-Counter Bulletin Board under the symbol, “TRCH.” Trading in our common stock in the
over-the-counter market has been limited and 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, 2011 and
2010, according to OTC Markets Inc., were as follows:
Quarter Ended
December 31, 2011
September 30, 2011
June 30, 2011
March 31, 2011
December 31, 2010
September 30, 2010
June 30, 2010
March 31, 2010
High (1) Low (1)
$
$
$
$
$
$
$
3.55 $
3.58 $
4.00 $
3.70 $
3.05 $
0.05 $
0.05 $
N/A
0.80
3.05
2.00
2.00
0.04
0.04
0.05
N/A
(1) On December 10, 2010, we effected a 4-for-1 forward split of our shares of common stock outstanding. All prices
reflected take into account the 4-for-1 forward split.
Record Holders
As of March 20, 2012, there were approximately 125 stockholders of record holding a total of 14,789,815 shares of common stock.
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, 2011, we do 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 issuances described 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:
From October 2011 to November 2011, we sold to certain investors (i) a total of 127,874 restricted shares of common stock and (ii)
warrants to purchase a total of 63,937 shares of common stock. We received aggregate consideration of $223,781 from the investors
for the securities. The securities were sold through a private placement offering. The warrants expire on June 30, 2014 and have an
exercise price of $5.00 per share. The securities were issued under the exemption from registration provided by Rule 506 of Regulation
D promulgated under Section 4(2) of the Securities Act of 1933. The sale of securities did not involve a “public offering” based upon
the following factors: (i) the sale of the securities was an isolated private transaction; (ii) a limited number of securities were sold to a
limited number of offerees; (iii) there was no public solicitation; (iv) the offerees were all “accredited investors”; (v) the investment
intent of the offerees; and (vi) the restriction on transferability of the securities issued.
19
In December 2011, we issued 125,000 restricted shares of common stock to an entity as payment for consulting services. 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 issuance of securities did not involve a “public offering” based upon the following factors: (i)
the issuance of the securities was an isolated private transaction; (ii) a limited number of securities were issued to a single offeree; (iii)
there was no public solicitation; (iv) the investment intent of the offeree; and (v) the restriction on transferability of the securities issued.
In December 2011, we sold to an investor (i) a 10% Promissory Note in the principal amount of $385,000 with a maturity date of
September 21, 2012 and (ii) a four-year warrant to purchase 385,000 shares of common stock at an exercise price of $1.75 per share.
We received aggregate consideration of $385,000 for the note and warrant. The securities were sold under the exemption from
registration provided by Section 4(2) of the Securities Act of 1933 and the rules and regulations promulgated thereunder. The sale of
securities did not involve a “public offering” based upon the following factors: (i) the sale of the securities was an isolated private
transaction; (ii) a limited number of securities were sold to a single offeree; (iii) there was no public solicitation; (iv) the offeree was an
“accredited investor”; (v) the investment intent of the offeree; and (vi) the restriction on transferability of the securities sold.
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 Plan of Operations is derived from the
historical financial statements and the related notes thereto of Torchlight Energy, Inc. which are included in this Form 10-K. 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 contains 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 the other risks and uncertainties described
in the “Risk Factors” section herein. 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 statement.
Basis of Presentation of Financial Information
On November 23, 2010, the Share Exchange Agreement (the “Exchange Agreement” or “Transaction”) between Pole Perfect Studios,
Inc. (“Pole Perfect”) and Torchlight Energy, Inc. (“TEI”) was entered into and closed, through which the former shareholders of TEI
became shareholders of Pole Perfect. At closing, Pole Perfect abandoned its previous business. Consequently, as a result of the
Transaction, the business of TEI became our sole business. Because TEI became the successor business to Pole Perfect and because
the operations and assets of TEI represent our entire business and operations from the closing date of the Exchange Agreement, the
Management’s Discussion and Analysis and audited and unaudited financial statements are based on the consolidated financial results
of Pole Perfect and its wholly owned subsidiary TEI for the relevant periods. Effective February 8, 2011, we changed our name from
“Pole Perfect Studios, Inc.” to “Torchlight Energy Resources, Inc.”
Overview
Summary of Key Results
Our sole business is that of Torchlight Energy, Inc., an exploration stage company formed as a corporation in the state of Nevada on
June 25, 2010. TEI is engaged in the acquisition, exploration, exploitation and/or development of oil and natural gas properties in the
United States.
Results of Operations
The following discussion of our financial condition and results of operations should be read in conjunction with our financial
statements, included herewith. This discussion should not be construed to imply that the results discussed herein will necessarily
continue into the future, or that any conclusion reached herein will necessarily be indicative of actual operating results in the future.
Such discussion represents only the best present assessment by our management.
20
Historical Results for the Period from January 1, 2011 through December 31, 2011
The discussion below does not use year-to-year comparisons as we do not believe year-to-year comparisons would enhance a reader’s
understanding of our financial condition, changes in financial condition and results of operations. This determination is based on the
fact that we did not commence operations until July 8, 2010. Accordingly, we had operations for less than half of the year ended
December 31, 2010, versus a full year of operations for the year ended December 31, 2011.
Revenues and Cost of Revenues
We had revenue of $24,152 during the above referenced period.
General and Administrative Expenses
Our general and administrative expenses consisted of accounting and administrative costs, professional fees and other general corporate
expenses. General and administrative expenses for the above referenced period were $1,872,659.
Liquidity and Capital Resources
As of December 31, 2011, our cash balance was $518,281. Our working capital as of December 31, 2011, was negative $354,687.
We entered into an extension agreement, effective January 1, 2012, with Sawtooth Properties, LLLP, Black Hills Properties, LLLP and
Pine River Ranch, LLC (collectively the “Note Holders”). Previously on June 24, 2011, we issued a total of three 10% Convertible
Promissory Notes with an aggregate principal amount of $262,500 to the Note Holders who paid $262,500 in aggregate consideration
for the notes. Each of the notes bears interest at the rate of 10% per annum and was due on December 31, 2011. Under the terms of the
extension agreement, the Note Holders agreed to extend the maturity date of each of the notes to December 31, 2012 in consideration of
the following: (i) the pro-rata issuance of a total of 75,000 shares of common stock to the Note Holders, (ii) the continued right to
convert any of the outstanding principal and interest of the notes into Units of our securities at the conversion price of $3.50 per Unit,
which Units each consist of two shares of common stock and one three-year warrant to purchase a share of common stock at the price
of $5.00 per share, and (iii) for each Unit the Note Holder receives upon such conversion set forth in “(ii)” above, the Note Holder will
receive two additional three-year warrants to purchase a share of common stock at the exercise price of $1.75 per share and one
additional three-year warrant to purchase a share of common stock at the exercise price of $5.00 per share. All other terms and
conditions of the notes remain unchanged.
Commitments and Contingencies
We are subject to contingencies as a result of environmental laws and regulations. Present and future environmental laws and
regulations applicable to our operations could require substantial capital expenditures or could adversely affect its operations in other
ways that cannot be predicted at this time. As of December 31, 2010, no amounts have been recorded because no specific liability has
been identified that is reasonably probable of requiring us to fund any future material amounts.
In July 2010, TEI entered into an Agreement to participate in an Oil and Gas Development Joint Venture (the “Participation
Agreement”) with Bayshore Operating Corporation, LLC (“Bayshore”). Bayshore is currently the holder of an oil, gas and mineral
lease covering approximately 1,045 acres in Wilson County, Texas, known as the Marcelina Creek Field Development. The
Participation Agreement provides for the drilling of four (4) wells. Upon execution of the agreement, TEI paid Bayshore an initial
deposit of $50,000, which amount was credited to the initial $50,000 payment due for the first well, in exchange for a 50% working
interest in the first well. TEI will pay 100% of total drilling and completion costs.
The first well, the Johnson #1-BH, was a re-entry and drilled a lateral section of the Buda Formation of approximately 1840 feet in
August 2010. After mutual agreement as to the location, the second well was drilled beginning July 2011. For the second well, TEI
paid Bayshore $50,000 at rig move-in and will pay $200,000 when the well is completed or plugged and abandoned, whichever comes
first. Further, TEI will pay 100% of the total drilling and completion costs for a 75% working interest.
For the third and fourth wells, TEI will pay Bayshore $50,000 at rig move-in and $150,000 when the well is completed or plugged and
abandoned, whichever comes first. Further, TEI will pay 100% of the total drilling costs and 75% of the completion costs for a 75%
working interest with Bayshore to pay 25% of the completion costs.
21
On December 31, 2011 the company executed an agreement with Bayshore for an extension of its drilling obligation deadline from
January 6, 2011 to April 15, 2011. As a condition for the extension the company paid to Bayshore $50,000, on January 6, 2011 and
issued 25,000 shares of the company’s stock in January 2011. Further a $25,000 cash payment was made concurrent with the approval
of the Authority for Expenditure (AFE) for the Johnson #4 well. As additional consideration Bayshore is no longer obligated to pay its
proportionate share of completion costs on the second vertical well.
The Johnson #1-BH encountered good shows and a completion was attempted. The well however produced large volumes of water,
some introduced by Bayshore during drilling and some from another source, either a deeper formation or from a nearby well. In July
2011 a workover crew was brought in to service the well, replace a broken rod and re-work the downhole pump. On 27 July 2011 the
crew dropped 2 joints of pipe in the hole and on 28 July another 6 joints. The well was damaged sufficiently to be shut-in. The service
company, Mercer Well Services, was notified of the damage and a meeting was to be arranged to settle the claim Bayshore and TEI
would file against Mercer. After conducting interviews and preparing documents and displays, a meeting was scheduled for mid-
December which was moved by Mercer to February 2012. We anticipate continuing discussions with Mercer to resolve this matter.
The Johnson #4, the first vertical well, began drilling operations on July 2011. The well encountered several pay zones and an attempt
to complete in the Buda Formation was made. The well has experienced several mechanical problems which had delayed its
completion. Following correcting the mechanical problems the well acted as if the Buda was tight and a subsequent acid job was done
in February 2012 to stimulate the well.
In late August 2011, Torchlight entered into discussions with Hockley Energy on a farm-in to TEI’s position in Marcelina Creek and
nearby acreage in the Stockdale, Texas area. After numerous meetings a Letter of Intent was executed in October 2011 which included
the terms of Hockley’s farm-in to TEI’s position. On November 4, 2011, TEI and Hockley Energy executed two farm-in agreements,
one for Marcelina Creek and one for the East Stockdale acreage. Under the terms, Hockley was to fund a deposit of $1.5 million by
November 6, 2011. To date no funds have been deposited and a petition to sue has been served to Hockley Energy charging “Breach of
Contract”, “Fraudulent Inducement” and “Promissory Estoppel”. We are presently within the answer period.
On September 27, 2011, we entered into an agreement with Wexco to acquire leases in Wilson County, Texas. Under the terms of the
agreement, we provided Wexco’s attorney to hold in escrow 1,672,375 shares of our common stock to secure the option to acquire the
leases. Our financial partner, Hockley Oil and Gas, failed to fund and the shares have been requested to be returned to us. At this time
we are awaiting receipt of the shares.
In November 2011, we entered into discussions and an evaluation of a possible farm-in to La Sal Oil & Gas on a prospect in Waller
County, Texas. A subsequent farm-in agreement was reached and executed in January 2012. Under the terms of the farm-in, we are to
pay $350,000 for the fracture stimulation of the Coulter #1-R for a 30% working interest. The agreement also provides us with multiple
options under which we can acquire additional interests in La Sal’s interest in the well. The well was stimulated in February 2012, and
we are awaiting completion.
Going Concern
Our financial statements have been prepared in accordance with generally accepted accounting principles applicable to a going concern,
which assumes that we will be able to meet our obligations and continue our operations for its next fiscal year. Realization values may
be substantially different from carrying values as shown, and these financial statements do not give effect to adjustments that would be
necessary to the carrying values and classification of assets and liabilities should we be unable to continue as a going concern.
At December 31, 2011, we had not yet achieved profitable operations, have accumulated losses of $2,613,494 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 we will be able to obtain the necessary funding to allow us
to remain a going concern through the methods discussed above, there can be no assurances that such methods will prove successful.
The accompanying financial statements do not include any adjustments that might result from the outcome of this uncertainty.
22
Significant Accounting Policies
Our discussion and analysis of our financial condition and results of operations are based upon our financial statements, which have
been prepared in accordance with accounting principles generally accepted in the United States of America. The preparation of these
financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and
expenses, and related disclosure of contingent assets and liabilities.
We believe that the estimates, assumptions, and judgments involved in the accounting policies described below have the greatest
potential impact on our financial statements, so we consider these to be our critical accounting policies. Because of the uncertainty
inherent in these matters, actual results could differ from the estimates we use in applying the critical accounting policies. Certain of
these critical accounting policies affect working capital account balances, including the policies for revenue recognition, oil and gas
properties, asset retirement obligations and income taxes. These policies require that we make estimates in the preparation of our
financial statements as of a given date.
Reclassifications – Certain amounts from the prior year have been reclassified to conform to the current year presentation. The
reclassifications had no impact on total assets or the net loss.
Within the context of these critical accounting policies, we are not currently aware of any reasonably likely events or circumstances that
would result in materially different amounts being reported.
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 financial statements and
accompanying notes. Actual results could differ from these estimates.
Risks and Uncertainties
Our operations are subject to significant risks and uncertainties, including financial, operational, technological and other risks associated
with operating an emerging business, including the potential risk of business failure.
Concentration of Risks
Our cash is placed with a highly rated financial institution and we conduct ongoing evaluations of the credit worthiness of the financial
institutions with which it does business. At times during the twelve months ended December 31, 2011 and the period from June 25,
2010 (inception) to December 31, 2010, cash balances were in excess of amounts guaranteed by the Federal Deposit Insurance
Corporation (“FDIC”). As of December 31, 2011, we had cash of $518,281, which is greater than the FDIC limit.
Unevaluated Oil and Gas Properties
Unevaluated oil and gas properties consist principally of our acquisition costs in undeveloped leases. When leases are developed, expire
or are abandoned, the related costs are transferred from unevaluated oil and gas properties to depletable oil and gas properties.
Additionally, we review the carrying costs of unevaluated oil and gas properties for the purpose of determining probable future lease
expirations and abandonments, and prospective discounted future economic benefit attributable to the leases. We records an allowance
for impairment based on the review with the corresponding charge being made to depletable oil and gas properties.
Investment in Oil and Gas Properties
We follow 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 development costs. We exclude these costs until the property has been
evaluated. We allocate 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.
23
Depreciation, Depletion and Amortization
The depreciable base for oil and natural gas properties includes the sum of all capitalized costs net of accumulated depreciation,
depletion and amortization (“DD&A”), estimated future development costs and asset retirement costs not included in oil and natural gas
properties, less costs excluded from amortization. The depreciable base of oil and natural gas properties is amortized on a unit-of-
production method. During the twelve months ended December 31, 2011and the period from June 25, 2010 (inception) to December
31, 2010, the investment in oil and gas properties included only unevaluated oil and gas properties and other costs excluded from
amortization; therefore, no depreciation, depletion or amortization has been recognized.
Ceiling Test
Future production volumes from oil and gas properties are a significant factor in determining the full cost ceiling limitation of capitalized
costs. Under the full cost method of accounting, we are 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, plus the cost of unproved oil and gas
properties, exceeds the present value of estimated future net cash flows discounted at 10 percent, plus the cost of unproved oil and gas
properties, the excess is charged to expense and reflected as additional accumulated DD&A. The ceiling test calculation uses a
commodity price assumption which is based on the un-weighted 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. We did not
recognize an impairment on our oil and gas properties during the period from June 25, 2010 (inception) to December 31, 2011. Due to
the volatility of commodity prices, should oil and natural gas prices decline in the future, it is possible that a write-down could occur.
Proved reserves are estimated quantities of crude oil, natural gas, and natural gas liquids, which geological and engineering data
demonstrate with reasonable certainty to be recoverable from known reservoirs under existing economic and operating conditions. The
independent engineering estimates include only those amounts considered to be proved reserves and do not include additional amounts
which may result from new discoveries in the future, or from application of secondary and tertiary recovery processes where facilities
are not in place or for which transportation and/or marketing contracts are not in place. Estimated reserves to be developed through
secondary or tertiary recovery processes are classified as unevaluated properties. As of December 31, 2011, we did not have any
proved oil or gas reserves.
The determination of oil and gas reserves is a subjective process, and the accuracy of any reserve estimate depends on the quality of
available data and the application of engineering and geological interpretation and judgment. Estimates of economically recoverable
reserves and future net cash flows depend on a number of variable factors and assumptions that are difficult to predict and may vary
considerably from actual results. In particular, reserve estimates for wells with limited or no production history are less reliable than
those based on actual production. Subsequent evaluation of the same reserves as well as cost estimates related to future development
costs of proved oil and gas reserves could result in significant revisions due to changes in regulatory requirements, technological
advances and other factors which are difficult to predict.
Gains and losses on the sale of oil and gas properties are generally reflected in income. Sales of less than 100% of our interest in the oil
and gas property are treated as a reduction of the capital cost of the field, with no gain or loss recognized, as long as doing so does not
significantly affect the unit-of-production depletion rate. Costs of retired equipment, net of salvage value, are usually charged to
accumulated depreciation. During the period from June 25, 2010 (inception) to December 31, 2011, there were no gains or losses
recognized from the sale of oil and gas properties.
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.
We record an abandonment liability associated with its oil and gas wells when those assets are placed in service. 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.
24
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
We recognize 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.
Federal and State 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 basis and operating loss and tax credit 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 and a change in tax rates is recognized in income in the period that includes the enactment
date. A valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be
realized.
Authoritative guidance for uncertainty in income taxes requires that we 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 our tax positions and determined there were no uncertain tax positions requiring recognition in the financial statements.
Our 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 operations. We have not recorded any interest or penalties associated with unrecognized tax benefits during
the period from June 25, 2010 (inception) to December 31, 2011.
Environmental Laws and Regulations
We are subject to extensive federal, state and local environmental laws and regulations. Environmental expenditures are expensed or
capitalized depending on their future economic benefit. We believe that we are in compliance with existing laws and regulations.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Not Applicable.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
Our financial statements for the fiscal year ended December 31, 2011 are attached hereto.
25
TABLE OF CONTENTS
Report of Independent Registered Public Accounting Firm
Consolidated Balance Sheet as of December 31, 2011
Consolidated Statement of Operations for the year ended December 31, 2011, the period from June 25, 2010 (inception)
to December 31, 2010 and the period from June 25, 2010 (inception) to December 31, 2011
Consolidated Statement of Stockholders’ Equity for the year ended December 31, 2011 and the period from June 25,
2010 (inception) to December 31, 2010
Consolidated Statement of Cash Flows for the year ended December 31, 2011, the period from June 25, 2010
(inception) to December 31, 2010 and the period from June 25, 2010 (inception) to December 31, 2011
Notes to Consolidated Financial Statements
Page
F-2
F-3
F-4
F-5
F-6
F-7
F-1
F-2
TORCHLIGHT ENERGY RESOURCES, INC.
(AN EXPLORATION STAGE COMPANY)
CONSOLIDATED BALANCE SHEETS
ASSETS
DECEMBER 31,
2011
DECEMBER 31,
2010
Current assets:
Cash
Accounts receivable
Prepaid costs
Total current assets
Investment in oil and gas properties
Goodwill
TOTAL ASSETS
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable
Related party payable
Convertible promissory notes
Promissory notes, net of discount of $59,360 and $34,000 at December 31, 2011
and December 31, 2010, respectively
Interest payable
Total current liabilities
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;
14,664,815 issued and outstanding at December 31, 2011
12,701,420 issued and outstanding at December 31, 2010
Additional paid-in capital
Accumulated deficit
Total stockholders' equity
$
$
$
$
518,281
17,274
16,267
551,822
3,182,128
447,084
4,181,034
$
$
45,011
258,750
262,500
325,640
14,608
906,509
11,369
-
-
5,177
5,871,473
(2,613,494)
3,263,156
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY
$
4,181,034
$
The accompanying notes are an integral part of these consolidated financial statements.
F-3
278,191
-
1,000
279,191
1,114,958
447,084
1,841,233
251,950
40,000
-
184,750
-
476,700
-
-
-
3,213
2,006,622
(645,302)
1,364,533
1,841,233
TORCHLIGHT ENERGY RESOURCES, INC.
(AN EXPLORATION STAGE
COMPANY)
CONSOLIDATED STATEMENTS OF OPERATIONS
YEAR
ENDING
DECEMBER 31, 2011
JUNE 25, 2010
(Inception)
TO
DECEMBER 31, 2010
JUNE 25, 2010
(Inception)
TO
DECEMBER 31, 2011
Revenue
Oil and gas sales
Cost of revenue
Gross loss
Operating expenses:
General and administrative expenses
Total operating expenses
Other income (expense)
Interest income
Interest 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
$
24,152
$
25,273
1,121
1,872,659
1,872,659
186
(94,598)
(94,412)
1,968,192
-
1,968,192
(0.138)
14,288,211
$
$
$
$
-
$
-
-
645,302
645,302
-
-
-
645,302
-
645,302
(0.069)
9,402,818
$
$
24,152
25,273
1,121
2,517,961
2,517,961
186
(94,598)
(94,412)
2,613,494
-
2,613,494
(0.185)
14,132,914
The accompanying notes are an integral part of these consolidated financial statements.
F-4
TORCHLIGHT ENERGY RESOURCES, INC.
(AN EXPLORATION STAGE
COMPANY)
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
FOR THE YEAR ENDING TO DECEMBER 31, 2011
AND THE PERIOD FROM JUNE 25, 2010 (INCEPTION) TO DECEMBER 31, 2010
Preferred
Stock
Common
Stock
Shares
Common
Stock
Amount
Additional
Paid-in
Capital
Deficit
accumulated
during the
Exploration
Stage
Total
-
$
-
$
-
$
-
$
-
Balance, June 25, 2010
$
Shares issued to management
Shares issued for private placement
Reverse merger transaction:
Recapitalization on reverse merger
Cancellation of common shares
Issuance of common stock for services
Forward stock split (4 for 1)
Issuance of common stock for services
Discount on convertible promissory note
Net loss
Balance, December 31, 2010
Issuance of common stock for services
Shares issued for private placement
Fair value of warrants issued
Net loss
Balance, December 31, 2011
$
$
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
2,000,000
2,000
8,000
361,125
361
1,444,140
4,301,730
(3,600,000)
4,302
(3,600)
442,782
(266,400)
100,000
100
162,900
9,488,565
50,000
-
-
-
50
-
-
-
149,950
65,250
-
(645,302)
(645,302)
12,701,420
$
3,213
$
2,006,622
$
(645,302)
$
1,364,533
420,971
421
1,105,552
1,542,424
1,543
2,580,915
-
-
-
-
178,384
-
(1,968,192)
(1,968,192)
14,664,815
$
5,177
$
5,871,473
$
(2,613,494)
$
3,263,156
-
-
-
-
-
-
-
-
10,000
1,444,501
447,084
(270,000)
163,000
-
150,000
65,250
-
-
-
1,105,973
2,582,458
178,384
The accompanying notes are an integral part of these consolidated financial statements.
F-5
TORCHLIGHT ENERGY RESOURCES, INC.
(AN EXPLORATION STAGE COMPANY)
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 discount
Depreciation, amortization and accretion
Change in:
Accounts receivable
Prepaid expenses
Accounts payable
Related party payable
Interest payable
Net cash used in operating activities
Cash Flows From Investing Activities
Investment in oil and gas properties
Cash Flows From Financing Activities
Issuance of promissory note
Payment of promissory note
Shares issued to management
Shares issued for private placement
Cancellation of common shares
Net cash provided by financing activities
Net increase in cash
Cash - beginning of period
Cash - end of period
Supplemental disclosure of cash flow information:
Non cash transactions:
Recapitalization on reverse merger
Discount on warrants issued in conjunction
with convertible note
Asset retirement obligation
Interest paid
YEAR
ENDING
DECEMBER 31,
2011
JUNE 25, 2010
(Inception)
TO
DECEMBER 31,
2010
JUNE 25, 2010
(Inception)
TO
DECEMBER 31,
2011
$
(1,968,192)
$
(645,302)
$
(2,613,494)
1,105,973
67,490
541
(17,274)
(15,267)
(206,939)
218,750
14,608
(800,310)
313,000
-
-
-
(1,000)
251,950
40,000
-
(41,352)
1,418,973
67,490
541
(17,274)
(16,267)
45,011
258,750
14,608
(841,662)
(2,056,342)
(1,114,958)
(3,171,300)
647,500
(250,000)
-
2,699,242
-
3,096,742
240,090
278,191
250,000
-
10,000
1,444,501
(270,000)
1,434,501
278,191
-
$
$
$
$
$
518,281
$
278,191
-
61,600
10,828
12,501
$
$
$
447,084
34,000
-
-
$
$
$
$
$
897,500
(250,000)
10,000
4,143,743
(270,000)
4,531,243
518,281
-
518,281
447,084
95,600
10,828
12,501
The accompanying notes are an integral part of these consolidated financial statements.
F-6
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1.
NATURE OF BUSINESS
Torchlight Energy, Inc. (“TEI”) was formed in the state of Nevada on June 25, 2010. TEI’s operations commenced with initial funding
on July 8, 2010. TEI is an Exploration Stage energy company formed as a corporation to engage in the acquisition, exploration,
exploitation and/or development of oil and natural gas properties in the United States.
On November 23, 2010 Torchlight Energy Resources, Inc. (“we,” “us” and the “Company”), formerly, Pole Perfect Studios, Inc.
(“Pole Perfect”) entered into a Share Exchange Agreement (the “Exchange Agreement”) with its major stockholders, TEI, and the
persons owning 100% of the outstanding capital stock of TEI (the “TEI Stockholders”). At closing, the TEI Stockholders transferred
9,444,501 shares of TEI common stock, representing 100% of the common stock of TEI, to the Company in exchange for an aggregate
of 2,361,125 shares (pre stock split) of newly issued common stock of the Company. Also at closing of the Exchange Agreement, the
Pole Perfect shareholders transferred to the Company an aggregate of 3,600,000 shares of common stock of the Company for
cancellation in exchange for an aggregate consideration of $270,000. This transaction was recorded as a reverse acquisition for
accounting purposes where TEI is the accounting acquirer. The assets and liabilities of Pole Perfect were recorded at a fair value of $0.
The Company recorded $447,084 of goodwill which represents the estimated fair value of the consideration exchanged. In addition, at
closing (i) TEI became the Company’s wholly-owned subsidiary, (ii) the Company abandoned all of its previous business plans within
the health and fitness industries, including opening and operating dance studios, and (iii) the business of TEI became the Company’s
sole business. Descriptions of its business hereinafter refer to the business of TEI.
On December 10, 2010, the Company effected a 4-for-1 forward split of its shares of common stock outstanding. All owners of record
at the close of business on December 10, 2010 (record date) received three additional shares for every one share they owned.
Effective February 8, 2011 the Company changed its name from “Pole Perfect Studios, Inc.” to “Torchlight Energy Resources, Inc.” In
connection with the name change, the Company’s ticker symbol changed from “PPFT” to “TRCH.”
In an Exploration Stage company, management devotes most of its activities to establishing a new business, including raising capital to
acquire interests in oil and gas properties. Planned principle activities have not yet produced any significant revenues, and the Company
has incurred operating losses as is normal in Exploration Stage companies.
The Company is engaged in the acquisition, exploration, development and producing of oil and gas properties. The Company is
interested in programs that have a short window of payback, a high internal rate of return and proven and bookable reserves. The
Company’s success will depend in large part on its ability to obtain and develop oil and gas interests within the United States.
2.
GOING CONCERN
These consolidated financial statements have been prepared in accordance with generally accepted accounting principles applicable to a
going concern, which assumes that the Company will be able to meet its obligations and continue its operations for its next fiscal year.
At December 31, 2011, the Company had not yet achieved profitable operations, has accumulated losses of $2,613,494 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.
F-7
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.
Concentration of risks – The Company’s cash is placed with a highly rated financial institution, and the Company conducts ongoing
evaluations of the credit worthiness of the financial institutions with which it does business. At times during the twelve months ended
December 31, 2011 and the period from June 25, 2010 (inception) to December 31, 2010, cash balances were in excess of amounts
guaranteed by the Federal Deposit Insurance Corporation.
Fair value of financial instruments – Financial instruments consist of cash, accounts receivable, accounts payable and convertible
promissory notes. The estimated fair values of cash, accounts receivable and accounts payable approximate the carrying amount due to
the relatively short maturity of these instruments. The carrying amounts of the convertible promissory notes approximate their fair value
giving affect for the term of the note and the effective interest rates. See note 7.
Accounts Receivable – Accounts receivable consist of uncollateralized oil and natural gas revenues due under normal trade terms, as
well as amounts due from working interest owners of oil and gas properties for their share of expenses paid on their behalf by the
Company. Management reviews receivables periodically and reduces the carrying amount by a valuation allowance that reflects
management’s best estimate of the amount that may not be collectible. As of December 31, 2011 and 2010 no valuation allowance was
considered necessary.
Investment in oil and gas properties – The Company uses the full cost method of accounting for exploration and development
activities as defined by the Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs of unsuccessful,
as well as successful, exploration and development activities are capitalized as properties and equipment. This includes any internal
costs that are directly related to property acquisition, exploration and development activities but does not include any costs related to
production, general corporate overhead or similar activities. Gain or loss on the sale or other disposition of oil and gas properties is not
recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves.
Oil and gas properties include costs that are excluded from costs being depleted or amortized. Oil and natural gas property costs
excluded represent investments in unevaluated properties and include non-producing leasehold, geological and geophysical costs
associated with leasehold or drilling interests and exploration drilling costs. The Company allocates a portion of its acquisition costs to
unevaluated properties based on relative value. Costs are transferred to the full cost pool as the properties are evaluated over the life of
the reservoir.
Depreciation, depletion and amortization –The depreciable base for oil and natural gas properties includes the sum of all capitalized
costs net of accumulated depreciation, depletion and amortization (“DD&A”), estimated future development costs and asset retirement
costs not included in oil and natural gas properties, less costs excluded from amortization. The depreciable base of oil and natural gas
properties is amortized on a unit-of-production method. During the twelve months ended December 31, 2011and the period from June
25, 2010 (inception) to December 31, 2010, the investment in oil and gas properties included only unevaluated oil and gas properties
and other costs excluded from amortization; therefore, no depreciation, depletion or amortization has been recognized.
F-8
Ceiling test – Future production volumes from oil and gas properties are a significant factor in determining the full cost ceiling limitation
of capitalized costs. Under the full cost method of accounting, the Company is required to periodically perform a “ceiling test” that
determines a limit on the book value of oil and gas properties. If the net capitalized cost of proved oil and gas properties, net of related
deferred income taxes, plus the cost of unproved oil and gas properties, exceeds the present value of estimated future net cash flows
discounted at 10 percent, net of related tax affects, plus the cost of unproved oil and gas properties, the excess is charged to expense and
reflected as additional accumulated DD&A. The ceiling test calculation uses a commodity price assumption which is based on the un-
weighed arithmetic average of the price on the first day of each month for each month within the prior 12 month period and excludes
future cash outflows related to estimated abandonment costs. The Company did not recognize impairment on its oil and gas properties
during the twelve months ended December 31, 2011and the period from June 25, 2010 (inception) to December 31, 2010. Due to the
volatility of commodity prices, should oil and natural gas prices decline in the future, it is possible that a write-down could occur.
Proved reserves are estimated quantities of crude oil, natural gas, and natural gas liquids, which geological and engineering data
demonstrate with reasonable certainty to be recoverable from known reservoirs under existing economic and operating conditions. The
independent engineering estimates include only those amounts considered to be proved reserves and do not include additional amounts
which may result from new discoveries in the future, or from application of secondary and tertiary recovery processes where facilities
are not in place or for which transportation and/or marketing contracts are not in place. Estimated reserves to be developed through
secondary or tertiary recovery processes are classified as unevaluated properties. As of December 31, 2011 and December 31, 2010,
the Company did not have any proved oil or gas reserves.
The determination of oil and gas reserves is a subjective process, and the accuracy of any reserve estimate depends on the quality of
available data and the application of engineering and geological interpretation and judgment. Estimates of economically recoverable
reserves and future net cash flows depend on a number of variable factors and assumptions that are difficult to predict and may vary
considerably from actual results. In particular, reserve estimates for wells with limited or no production history are less reliable than
those based on actual production. Subsequent evaluation of the same reserves as well as cost estimates related to future development
costs of proved oil and gas reserves could result in significant revisions due to changes in regulatory requirements, technological
advances and other factors which are difficult to predict.
Gains and losses on the sale of oil and gas properties are generally reflected in income. Sales of less than 100% of the Company’s
interest in the oil and gas property are treated as a reduction of the capital cost of the field, with no gain or loss recognized, as long as
doing so does not significantly affect the unit-of-production depletion rate. Costs of retired equipment, net of salvage value, are usually
charged to accumulated depreciation. During the twelve months ended December 31, 2011 and the period from June 25, 2010
(inception) to December 31, there were no gains or losses recognized from the sale of oil and gas properties.
Goodwill - Goodwill represents the excess of the purchase price over the fair value of the net identifiable tangible and intangible assets
of acquired companies. Goodwill is not amortized; instead, it is tested for impairment annually or more frequently if indicators of
impairment exist.
Goodwill was $447,084 as of December 31, 2011 and December 31, 2010 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.
F-9
Share-Based Compensation– Compensation cost for equity awards is based on the fair value of the equity instrument on the date of
grant and is recognized over the period during which an employee is required to provide service in exchange for the award.
Compensation cost for liability awards is based on the fair value of the vested award at the end of each period.
Revenue recognition – The Company recognizes oil and gas revenues when production is sold at a fixed or determinable price,
persuasive evidence of an arrangement exists, delivery has occurred and title has transferred, and collectability is reasonably assured.
Basic and Diluted Earnings (Loss) Per Share - Basic earnings (loss) per common share is computed by dividing net income (loss)
available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings
(loss) per common share is computed in the same way as basic earnings (loss) per common share except that the denominator is
increased to include the number of additional common shares that would be outstanding if all potential common shares had been issued
and if the additional common shares were dilutive.
Environmental laws and regulations – The Company is subject to extensive federal, state and local environmental laws and
regulations. Environmental expenditures are expensed or capitalized depending on their future economic benefit. The Company
believes that it is in compliance with existing laws and regulations.
Recent accounting pronouncements – In January 2010, the Financial Accounting Standards Board (“FASB”) issued its updates to oil
and gas accounting rules to align the oil and gas reserve estimation and disclosure requirements of Extractive Industries — Oil and Gas
with the requirements in the SEC’s final rule, Modernization of the Oil and Gas Reporting Requirements, which was issued on
December 31, 2008. It is intended to provide investors with a more meaningful and comprehensive understanding of oil and gas
reserves to help investors evaluate their investments in oil and gas companies. The amendments are also designed to modernize the oil
and gas disclosure requirements to align them with current practices and changes in technology. Revised requirements in this guidance
include, but are not limited to:
·
·
·
·
·
·
Oil and gas reserves must be reported using the average price over the prior 12-month period, determined as an un-weighted
arithmetic average of the first-day-of-the-month price for each month within such period, rather than year-end prices;
Companies are allowed to report, on an optional basis, probable and possible reserve;
Non-traditional reserves, such as oil and gas extracted from coal and shales, are included in the definitions of “oil and gas
producing activities”;
Companies are permitted to use new technologies to determine proved reserves, as long as those technologies have been
demonstrated empirically to lead to reliable conclusions with respect to reserve volumes;
Companies are required to disclose, in narrative form, additional details on their proved undeveloped reserves (PUDs), including
the total quantity of PUDs at year end, any material changes to PUDs to developed oil and gas reserves and an explanation of
the reasons why material concentrations of PUDs in individual fields or countries have remained undeveloped for five years or
more after disclosure as PUDs;
Companies are required to report the qualifications and measures taken to assure the independence and objectivity of any
business entity or employee primarily responsible for preparing or auditing the reserves estimates.
The Company adopted this guidance effective June 25, 2010 (inception). As of December 31, 2011 and December 31, 2010, the
Company did not have any proved reserves.
In December 2010, the FASB issued amended accounting guidance relating to goodwill impairment test for reporting units with zero or
negative carrying amounts. For those reporting units, an entity is required to perform “Step two” of the goodwill impairment test if it is
more likely than not that a goodwill impairment exists. In determining whether it is more likely than not, that a goodwill impairment
exists, an entity should consider whether there are any adverse qualitative factors indicating that an impairment may exist. The
Company is currently evaluating the impact of this guidance on its consolidated financial statements.
In September 2011, the FASB issued guidance that amends and simplifies the rules related to testing goodwill for impairment. The
revised guidance allows an entity to first assess qualitative factors to determine whether the existence of events or circumstances leads to
a determination whether it is more likely than not that the fair value of reporting unit is less than its carrying amount. The results of this
assessment will determine whether it is necessary to perform the currently required two-step impairment test. Under this update, an
entity also has the option to bypass the qualitative assessment for any reporting unit in any period and proceed directly to performing the
two-step goodwill impairment test. The adoption of this guidance will not have a material effect on the Company’s consolidated
financial statements.
F-10
The two preceding amendments listed above are effective for fiscal years, and interim periods within those years, beginning after
December 15, 2011, with early adoption permitted.
Other recently issued or adopted accounting pronouncements are not expected to have, or did not have, a material impact on the
Company’s financial position or results from operations.
Subsequent Events – The Company evaluated all subsequent events through March 30, 2012, the date of issuance of the financial
statements. Subsequent events are disclosed in Note 11.
Reclassifications – Certain amounts from the prior year have been reclassified to conform to the current year presentation. The
reclassifications had no impact on total assets or the net loss.
4.
RELATED PARTY TRANSACTIONS
In exchange for management services provided to the Company, Opal Marketing & Consulting, Inc. (“Opal”) charges the Company a
management fee of $240,000 per year. The Company’s Chief Executive Officer is the President of Opal. The Company recognized
payments due Opal of $240,000 for the twelve months ended December 31, 2011. The Company recognized payments due Opal of
$120,000 for the period from June 25, 2010 (inception) through December 31, 2010. The Company recognized payments due Opal of
$360,000 for the period from June 25, 2010 (inception) through December 31, 2011. The Company recognized an amount payable to
Opal of $180,000 and $40,000 at December 31, 2011 and December 31, 2010, respectively and is reflected in related party payable on
the consolidated balance sheet.
On December 1, 2010, the Company entered into a Business Consultant Agreement with a former Director and Chief Executive
Officer. The agreement provided that in consideration for consulting services, the Company will pay $4,000 per month for the term of
the agreement (three months) and issue 50,000 restricted shares of common stock. On December 17, 2010, the Company issued the
50,000 shares of common stock which were valued at $150,000 on that date. For the year ended December 31, 2010, the Company
paid the former Director and CEO a total of $4,000 in cash under the agreement. For the year ended December 31, 2011 a total of
$8,000 in cash was paid under the agreement. This agreement was terminated in early 2011.
The Company recognized a related party payable totaling $78,750 in connection with the February 2012 issuance of 25,000 shares of
common stock each to Wayne Turner and Ken Danneberg in consideration for serving on the Board of Directors in 2011.
5.
COMMITMENTS AND CONTINGENCIES
The Company is subject to contingencies as a result of environmental laws and regulations. Present and future environmental laws and
regulations applicable to the Company’s operations could require substantial capital expenditures or could adversely affect its operations
in other ways that cannot be predicted at this time. As of December 31, 2011 and December 31, 2010, no amounts had been recorded
because no specific liability has been identified that is reasonably probable of requiring the Company to fund any future material
amounts.
6.
STOCKHOLDERS’ EQUITY
The Board of Directors has the authority to issue up to 5,000,000 shares of preferred stock in one or more series, to fix the number of
shares constituting any such series, and to fix the rights and preferences of the shares constituting any series, without any further vote
or action by the stockholders. There are no issued and outstanding shares of preferred stock; there are no agreements or understandings
for the issuance of preferred stock, and the Board of Directors has no present intention to issue preferred stock.
During the year, the Company issued common shares as compensation for services as well as the following:
During February and March 2011, through subscription agreements, the Company received $944,499 for the issuance of 269,857
Units. Each Unit consisted of two restricted shares of common stock and one three year warrant to purchase a share of restricted
common stock at the price of $5.00.
During April, May and June 2011, through subscription agreements, the Company received $1,045,722 for the issuance of 298,778
Units. Each Unit consisted of two restricted shares of common stock and one three year warrant to purchase a share of restricted
common stock at the price of $5.00.
During August and September 2011, through subscription agreements, the Company issued 138,640 units. The Company received
$485,240 in cash for the issuance. Each Unit consisted of two restricted shares of common stock and one three year warrant to
purchase a share of restricted common stock at the price of $5.00.
F-11
During October and November 2011, through subscription agreements, the Company issued 63,937 units. The Company received
$223,781 in cash for the issuance. Each Unit consisted of two restricted shares of common stock and one three year warrant to
purchase a share of restricted common stock at the price of $5.00.
At December 31, 2011 the shares from the potential exercise of the warrants were excluded from the calculation of earnings per share as
the shares were anti-dilutive.
On October 7, 2011, the Company placed 1,672,375 shares of common stock into escrow in connection with a letter of intent with
Wexco Resources to acquire leases in Wilson County, Texas and two farm-in agreements with Hockley Energy. Under the terms, and
subject to closing, Hockley Energy was to fund a deposit of $1,500,000 by November 6, 2011. To date no funds have been deposited
and a petition to sue has been served Hockley Energy. Subsequent to December 31, 2012, the Company requested the return of the
shares held in escrow from the escrow agent.
A summary of warrant activity for the period from June 25, 2010 (inception) to December 31, 2011 is presented below:
Number of
Warrants
Weighted
Average
Exercise
Price
Outstanding June 25, 2010
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
Issued
12/28/2010
02/18/2011
03/08/2011
03/08/2011
03/14/2011
03/15/2011
04/13/2011
05/03/2011
05/09/2011
06/02/2011
06/03/2011
06/07/2011
06/20/2011
06/21/2011
06/22/2011
06/28/2011
08/12/2011
09/23/2011
10/25/2011
11/05/2011
11/14/2011
12/21/2011
Outstanding December 31, 2011
-
225,000
30,000
30,000
30,000
25,000
154,857
142,850
40,000
22,500
10,000
9,000
14,500
7,142
7,143
11,143
34,500
113,640
25,000
7,143
7,144
49,650
385,000
1,381,212
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
-
2.50
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
5.00
1.75
Weighted
Average
Expected
Life
-
3.00 years
2.25 years
2.25 years
2.25 years
2.25 years
2.25 years
2.50 years
2.50 years
2.50 years
2.50 years
2.50 years
2.50 years
2.50 years
2.50 years
2.50 years
2.50 years
2.75 years
2.75 years
3.00 years
3.00 years
3.00 years
4.00 years
At December 31, 2010, the Company had reserved 225,000 shares for future exercise of warrants. At December 31, 2011 the
Company had reserved 1,381,212 shares for future exercise of warrants.
Warrants issued in relation to the promissory notes issued (see note 9) and the equity Unites above were valued using the Black Scholes
Option Pricing Model. The assumptions used in calculating the fair value of the warrants issued are as follows:
Risk-free interest rate
Expected volatility of common stock
Dividend yield
Discount due to lack of marketability
Expected life of warrant
.68% - 0.64%
60.00% - 40.00%
0.00% - 0.00%
30.00% - 30.00%
4 years- 2 years
F-12
7.
FAIR VALUE MEASUREMENTS
Assets and liabilities that require measurement to fair value on a recurring basis are categorized in a three-level fair value hierarchy as
follows:
·
·
·
Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.
Level 2 inputs are quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or
liability, either directly or indirectly through market corroboration.
Level 3 inputs are unobservable inputs based on management’s own assumptions used to measure assets and liabilities at fair
value.
A financial asset or liability’s classification within the hierarchy is determined based on the lowest level input that is significant to the
fair value measurement. At December 31, 2011 and December 31, 2010, there were no financial assets or liabilities measured on a
recurring or a nonrecurring basis.
8.
INCOME TAXES
Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax
consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their
respective tax bases and operating loss carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected
to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on
deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A
valuation allowance is established to reduce deferred tax assets if it is more likely than not that the related tax benefits will not be
realized.
Authoritative guidance for uncertainty in income taxes requires that the Company recognize the financial statement benefit of a tax
position only after determining that the relevant tax authority would more likely than not sustain the position following an examination.
Management has reviewed the Company’s tax positions and determined there were no uncertain tax positions requiring recognition in
the consolidated financial statements. The Company’s tax returns remain subject to Federal and State tax examinations for all tax years
since inception as none of the statutes have expired. Generally, the applicable statutes of limitation are three to four years from their
respective filings.
Estimated interest and penalties related to potential underpayment on any unrecognized tax benefits are classified as a component of tax
expense in the statement of operation. The Company has not recorded any interest or penalties associated with unrecognized tax
benefits during the year ended December 31, 2011 and the period from June 25, 2010 (inception) to December 31, 2010.
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 year ended December 31, 2011, the period from June 25, 2010 (inception) to December 31, 2010
and the period from June 25, 2010 (inception) to December 31, 2011:
Federal income tax benefit at statutory rate
Permanent Differences
Change in valuation allowance
Provision for income taxes
12 Months ended
Dec. 31, 2011
(669,185)
22,947
646,238
-
$
$
$
$
June 25, 2010
(inception) through
Dec. 31, 2010
June 25, 2010
(inception) through
Dec. 31, 2011
(219,403)
-
219,403
-
$
$
(888,588)
22,947
865,641
-
F-13
The tax effects of temporary differences that gave rise to significant portions of deferred tax assets and liabilities are as follows:
Deferred tax assets:
Net operating loss carryforward
Accruals
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, 2011
Dec. 31, 2010
1,241,407
61,200
$
(436,966)
865,641
(865,641)
-
$
336,835
7,820
(125,252)
219,403
(219,403)
-
The Company had a net deferred tax asset related to federal net operating loss carryforwards of $3,651,197 and $990,692 at December
31, 2011 and December 31, 2010, respectively. The federal net operating loss carryforward will begin to expire in 2030. Realization of
the deferred tax asset is dependent, in part, on generating sufficient taxable income prior to expiration of the loss carryforwards. The
Company has placed a 100% valuation allowance against the net deferred tax asset because future realization of these assets is not
assured.
9.
PROMISSORY NOTES
On December 28, 2010, the Company issued a 10% convertible promissory note and a warrant to purchase 225,000 shares of common
stock to an accredited investor who paid $250,000 in aggregate consideration for the securities. The 10% convertible promissory note
bore interest at the rate of 10% per annum, had a principal amount of $250,000 and was convertible into shares of common stock in the
event the Company undertakes a private offering of securities to one or more third parties. The note was convertible on the identical
terms and conditions offered to such third parties. The warrant is exercisable into 225,000 shares of common stock as of December 28,
2010 at a price of $2.50 per share and expires on December 28, 2014. The note was collateralized by 750,000 shares of pledged
securities of a related party. The convertible note was recorded net of discount that includes the relative fair value of the warrants
amounting to $62,250. The discount is accreted over the life of the debt using the effective interest method. The initial value of the
warrants was calculated using the Black Scholes Option Pricing Model. On June 28, 2011, the Company paid $262,500 to the holder of
the convertible promissory note dated December 28, 2010 representing full payment of principal and interest.
The Company entered into an extension agreement, effective January 1, 2012, with stockholders Sawtooth Properties, LLLP, Black
Hills Properties, LLLP and Pine River Ranch, LLC (collectively the “Note Holders”). Previously on June 24, 2011, the Company
issued a total of three 10% Convertible Promissory Notes with an aggregate principal amount of $262,500 to the Note Holders who
paid $262,500 in aggregate consideration for the notes. Each of the notes bears interest at the rate of 10% per annum and was due on
December 31, 2011. Under the terms of the extension agreement, the Note Holders agreed to extend the maturity date of each of the
notes to December 31, 2012 in consideration of the following: (i) the pro-rata issuance of a total of 75,000 shares of common stock to
the Note Holders, (ii) the continued right to convert any of the outstanding principal and interest of the notes into Units of the
Company’s securities at the conversion price of $3.50 per Unit, which Units each consist of two shares of common stock and one
three-year warrant to purchase a share of common stock at the price of $5.00 per share, and (iii) for each Unit the Note Holder receives
upon such conversion set forth in “(ii)” above, the Note Holder will receive two additional three-year warrants to purchase a share of
common stock at the exercise price of $1.75 per share and one additional three-year warrant to purchase a share of common stock at the
exercise price of $5.00 per share.
On December 21, 2011, the Company issued a 10% promissory note and a warrant to purchase shares of common stock to an
accredited investor who paid $385,000 in aggregate consideration for the securities. The 10% promissory note bears interest at the rate
of 10% per annum, has a principal amount of $385,000 and has a maturity date of September 21, 2012.The warrant is exercisable into
385,000 shares of common stock as of December 20, 2011 at a price of $1.75 per share and expires on December 21, 2015. The note
was collateralized by 1,000,000 shares of pledged securities of a related party. The convertible note was recorded net of discount that
includes the relative fair value of the warrants amounting to $61,600. The discount is accreted over the life of the debt using the
effective interest method. Accretion expense was $2,240 for the 10 days ended December 31, 2011. The initial value of the warrants
was calculated using the Black Scholes Option Pricing Model.
F-14
10.
ASSET RETIREMENT OBLIGATIONS
The following is a reconciliation of the asset retirement obligation liability for the year ended December 31, 2011:
Asset retirement obligation – January 1, 2011
Liabilities incurred
Accretion expense
Asset retirement obligation – December 31, 2011
$
$
-
10,828
541
11,369
11.
SUBSEQUENT EVENTS
On January 10, 2012, the Company entered into a farm-in agreement, in which the Company acquired a working interest and a net
revenue interest for the purchase price of $350,000.
On February 16, 2012, the Company filed a lawsuit against Hockley Energy, Inc. and Frank O. Snortheim in the District Court of
Harris County, Texas. The lawsuit is in connection with farmout agreements the Company entered into with Hockley Energy in
November 2011.
On March 26, 2012, the Company issued two Series A 10% Convertible Promissory Notes to Sawtooth Properties, LLLP and Pine
River Ranch, LLC for aggregate consideration of $150,000. The notes are due on September 26, 2012 and bear interest at the rate of
10% per annum. Each of the notes is convertible on and after the earlier to occur of (i) August 26, 2012, (ii) an un-cured event of
default or (iii) the Company’s election to pre-pay the note. The notes are convertible into shares of common stock at the conversion
price of $1.75 per share. The notes are collateralized with (i) a first lien on the Company’s interest in the Johnson #4 well, (ii) a second
lien on the Company’s interest in the two John Coulter wells, and (iii) shares of stock pledged by the Company’s Chief Executive
Officer. In connection with the issuance of the notes, the Company also issued the holders three-year warrants to purchase an aggregate
of 150,000 shares of common stock at the exercise price of $1.75 per share, which warrants are not exercisable until August 26, 2012.
Also in connection with the issuance of the notes, the Company amended the promissory notes it had previously issued Sawtooth
Properties, LLLP, Pine River Ranch, LLC and Black Hills Properties, LLLP on June 24, 2011, which notes had previously been
amended pursuant to an extension agreement effective January 1, 2012. The new amendments to the notes give the holders collateral in
the Company’s interest in the Johnson #4 well and the two John Coulter wells. The new amendments also provide that each holder will
not have the right to convert outstanding principal and interest of the note or the right to receive additional warrants to purchase shares
of common stock until the earlier to occur of (i) December 1, 2012, (ii) an un-cured event of default and (iii) the Company’s election to
pre-pay the note.
12.
SUPPLEMENTARY OIL & GAS INFORMATION - UNAUDITED
The supplementary data presented reflects information for all of our oil and gas producing activities. Cost incurred for oil and gas
leasehold and drilling activity is as follows:
Year ending
December 31, 2011
June 25, 2010
(inception) through
December 31, 2010
June 25, 2010
(inception) through
December 31, 2011
Leasehold costs
Geological & geophysical costs
Drilling and exploration costs
$
$
$
344,986
5,900
1,705,456
$
$
$
207,500
74,571
832,887
$
$
$
552,486
80,471
2,538,343
F-15
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
Not Applicable.
ITEM 9A. CONTROLS AND PROCEDURES
Thomas Lapinski, our Chief Executive Officer, is our principal executive officer and principal financial officer.
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, 2011. Based on this evaluation, our principal executive officer and
our principal financial officer concluded that, as of the end of the period covered by this report, our disclosure controls and procedures
were effective and adequately designed to ensure that the information required to be disclosed by us in the reports we submit under the
Exchange Act is recorded, processed, summarized and reported within the time periods specified in the applicable rules and forms and
that such information was accumulated and communicated to our principal executive officer and principal financial officer, in a manner
that allowed for timely decisions regarding disclosure.
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) under the Exchange Act). Our internal control over financial reporting is a process designed to provide reasonable assurance
regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with
accounting principles generally accepted in the United States. Our internal control over financial reporting includes those policies and
procedures that:
(i)
(ii)
(iii)
pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions
of our assets;
provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements; and
provide reasonable assurance regarding prevention or timely detection of unauthorized transactions.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of
any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in
conditions, or that the degree of compliance with policies or procedures may deteriorate.
In making this assessment, our management used 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.
26
We evaluated control deficiencies identified through our test of the design and operating effectiveness of controls over financial
reporting to determine whether the deficiencies, individually or in combination, are significant deficiencies or material weaknesses. In
performing the assessment, our management has identified material weaknesses in internal control over financial reporting existing as of
December 31, 2011. Our evaluation of the significance of each deficiency included both quantitative and qualitative factors. Based on
that evaluation, our management concluded that as of December 31, 2011, our internal controls are not effective, for the reason
discussed below:
1.
2.
3.
4.
5.
6.
7.
We did not yet have written documentation of our internal control policies and procedures. Written documentation of key internal
controls over financial reporting is a requirement of Section 404 of the Sarbanes-Oxley Act and may be applicable to us in future
years.
We did not have sufficient segregation of duties within accounting functions, which is a basic internal control. Due to our extremely
small size and the fact that we only had one management employee as of December 31, 2011, whom is also an executive officer and
director, segregation of all conflicting duties may not always be possible and may not be economically feasible. Even though we
appointed a second management employee in January 2012 this problem with our segregation of all conflicting duties will likely
continue. To the extent possible, the initiation of transactions, the custody of assets and the recording of transactions should be
performed by separate individuals.
We did not have full-time accounting personnel, which means we lacked the requisite expertise in the key functional areas of finance
and accounting. In addition, this means we did not have available personnel to properly implement control procedures.
We did not have a functioning audit committee, resulting in ineffective oversight in the establishment and monitoring of required
internal controls and procedures.
We had not established adequate financial reporting monitoring activities to mitigate the risk of management override. Specifically,
because we had only one employee as of December 31, 2011 with management functions, there was a lack of segregation of duties.
Even though we appointed a second employee with management functions in January 2012, this lack of segregation of duties will
likely continue.
There was a strong reliance on the external auditors and contract accountant to review and adjust the annual and quarterly financial
statements, to monitor new accounting principles, and to ensure compliance with GAAP and SEC disclosure requirements.
There was a strong reliance on the external attorneys to review and edit the annual and quarterly filings and to ensure compliance
with SEC disclosure requirements.
In light of the material weaknesses described 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.
In addition, although our controls are not effective, these significant weaknesses did not result in any material misstatements in our
financial statements. Our management is committed to improving its internal controls and (1) will continue to use third party specialists
to address shortfalls in staffing and to assist us with accounting and finance responsibilities, (2) will increase the frequency of
independent reconciliations of significant accounts which is intended to mitigate the lack of segregation of duties until there are
sufficient personnel, (3) has, subsequent to the evaluation period, appointed additional directors and an additional executive officer and
(4) anticipates establishing an audit committee in the future.
27
Changes in internal control over financial reporting
Other than the weaknesses identified above, there were no changes in our internal control over financial reporting during the year ended
December 31, 2011 that have materially affected, or are reasonably likely to materially affect our internal control over financial
reporting.
Our management, including our principal executive officer and principal financial officer, does not expect that its 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.
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 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.
28
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Our executive officers and directors are as follows:
PART III
Name
Thomas Lapinski
John A. Brda
Kenneth I. Danneberg
Wayne Turner
Gregory Williams
Age Position(s) and Office(s)
67
47
84
62
57
Chief Executive Officer, Interim
Principal Financial Officer and Director
President, Secretary and Director
Director
Director
Director
Currently, Thomas Lapinski and John Brda are currently our sole executive officers. We presently rely on the assistance of outside
advisors and consultants to supplement our management. At such time as adequate funding is available, we anticipate adding additional
executive officers, including a Chief Financial Officer. Further, additional staff will be added as projects become successful and a need
develops to have focused attention on such projects’ future development.
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 various projects, both international and
domestic, including the purchase of energy related businesses, primarily focusing on evaluating exploration 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
numerous 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 vital to 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.
29
Kenneth I. Danneberg – Mr. Danneberg has been a member of the Board of Directors since June 20, 2011. He brings to the
company over 45 years of experience covering all aspects of oil and gas exploration and operation in the United States and Canada
and is a member of the Rocky Mountain Oil and Gas Hall of Fame. For the past 15 years he has been the President and CEO of
Danneberg Oil Inc., a company engaged in the drilling and production of oil and gas wells. Several career highlights are listed
below:
·
·
·
·
·
Founder of Zoller and Danneberg, Inc which later become Premier Resources, Ltd.
Served as CEO of Premier Resources, Ltd, an AMEX listed company, conducting oil and gas operations in the U.S. and
Canada
Drilling projects resulted in 22 field discoveries and averaged over 20 drilling projects per year
Extensive domestic and international drilling experience
Previously served on the boards of the following companies:
o
o
o
o
o
Alco Oil & Gas (predecessor to Ladd Petroleum a GE Subsidiary)
Premier Resources, Ltd
Zoller & Danneberg
International Bank of Denver
Great Horn, Inc.
We appointed Ken Danneberg to our Board because he brings a tremendous depth of knowledge of the oil and gas industry, and in
particular, Ken is a distinguished executive in the Rocky Mountain region.
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 bought into the company. JEBCO is a fully
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
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 all relevant
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 at the present time. Most of the activity is through partnerships, allowing the company to remain small
in staff, but have access to expertise in different areas through these partnerships. 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; primarily 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.
Gregory Williams – Mr. Willliams has served as one of our directors since March 2011. He is presently the Chief Financial Officer
for Oxane Materials, Inc. in Houston, Texas, a position he has held since October 2009. Oxane is a start-up company in the oil and
gas, exploration and production industry making high strength, light weight proppant used in hydraulic fracturing. As Chief
Financial Officer of Oxane, his duties have included corporate secretary responsibilities, equity and debt raising, accounting and
control, treasury and finance, corporate taxes, financial planning, risk exposure analysis, information technology, human resources,
contract review and financial compliance. Mr. Williams retired in 2009 from Ineos/Innovene/bp/Amoco after 32 years of financial
management experience. Mr. Williams has over 10 years of petrochemicals experience as the former CFO for Ineos Olefins &
Polymers North America including financial stewardship and corporate governance for all Ineos North American businesses and as
the bp Chemicals Segment North American Controller. He has a BBA in Finance from Sam Houston State University and MIM
from the American Graduate School of International Management (Thunderbird), in Phoenix, Arizona.
Mr. Williams has over 20 years of exploration and production experience both in the United States and internationally. This
experience and his accounting background make him a vital member of our Board of Directors.
30
Section 16(a) Beneficial Ownership Reporting Compliance
Based solely upon a review of Forms 3, 4 and 5 furnished to us, we are aware of three people who, during the fiscal year ended
December 31, 2010 were directors, officers, or beneficial owners of more than ten percent of our common stock, and who failed to file,
on a timely basis, reports required by Section 16(a) of the Securities Exchange Act of 1934 as follows:
Kenneth I. Danneberg, a member of our Board of Directors, failed to timely file a Form 3 when he became subject to the reporting
requirements of Section 16(a) of the Exchange Act on June 20, 2011. He ultimately filed the report, however, on July 13, 2011.
Wayne Turner, a member of our Board of Directors, failed to timely file a Form 3 when he became subject to the reporting
requirements of Section 16(a) of the Exchange Act on March 10, 2011. He ultimately filed the report, however, on July 8, 2011.
Gregory Williams, a member of our Board of Directors, failed to timely file a Form 3 when he became subject to the reporting
requirements of Section 16(a) of the Exchange Act on March 3, 2011. He ultimately filed the report, however, on July 8, 2011.
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 was filed as Exhibit 14.1 to our S-1 Registration Statement
filed with the SEC on May 2, 2008. 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., 2007 Enterprise Avenue, League
City, Texas 77573.
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 in the Schedule 14f-1 Information Statement we mailed to stockholders on or
around November 9, 2010.
Audit Committee
The Board of Directors has not yet established a separately-designated standing audit committee. An audit committee typically 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. Certain stock exchanges require listed companies to adopt a formal written
charter that establishes an audit committee that specifies the scope of an audit committee’s responsibilities and the means by which it
carries out those responsibilities. In order to be listed on any of these exchanges, we will be required to establish an audit committee.
There can be no assurances if and when we will establish an audit committee.
31
ITEM 11. EXECUTIVE COMPENSATION
The following table provides summary information for the years 2011 and 2010 concerning cash and non-cash compensation paid or
accrued to or on behalf of certain executive officers.
Summary Executive Compensation Table
Change in
Pension
Value
and
Nonqualified
Deferred
Compensation
($)
Non-Equity
Incentive
Plan
Compensation
($)
All Other
Compensation
($)
Total
($)
Salary
($)
Bonus
($)
Year
Stock
Awards
($)
Option
Awards
($)
2011
2010
$240,000(2)
$104,000
-
-
-
-
-
-
-
-
-
-
-
-
$240,000
$104,000
Name and
Principal
Position
Thomas Lapinski
President, CEO
and Director (1)
(1) Thomas Lapinski does not have a compensation arrangement directly with Torchlight Energy Resources, Inc. in connection with his
position as our executive officer. He is, however, also an executive officer of our wholly owned subsidiary, Torchlight Energy, Inc.,
and is entitled to receive a management fee pursuant to an employment agreement in effect with TEI. See “Employment Agreements,”
below.
(2) Mr. Lapinski’s employment agreement with TEI provides that he is to receive a management fee of $240,000 per year. For the year
ended December 31, 2011, $60,000 of his 2011 management fee has been paid to him and the remaining $180,000 is accrued and
unpaid.
Employment Agreements
In July 2010, Torchlight Energy, Inc., our wholly owned subsidiary (“TEI”), entered into an employment agreement with Opal
Marketing and Consulting, Inc. (“Opal”). Our Chief Executive Officer and director, Thomas Lapinski, owns and is the President of
Opal. The agreement provides that Opal will provide the services of Mr. Lapinski to serve as TEI’s President and Chairman of the
Board of Directors. The agreement has a term of two years and provides that TEI is to pay Opal a base fee equal to $240,000 per year,
payable monthly. TEI must also pay all applicable federal, state and local employment taxes, as well as social security and such other
amounts, from all amounts paid to Opal. Further, Mr. Lapinski is eligible to receive stock options and an additional annual bonus as
determined by the Board of Directors in its sole discretion in an amount not to exceed 100% of the base fee. There is currently no
employment agreement between Mr. Lapinski and Torchlight Energy Resources, Inc.
In January 2011 we appointed John A. Brda as President and Secretary. We entered into an Employment Agreement with Mr. Brda
that provides that Mr. Brda will serve as President and Secretary for a term of two years and will receive annual compensation of
$240,000 in addition to any performance bonuses the Board may choose to grant at its discretion.
Outstanding Equity Awards at Fiscal Year End
We do not have any unexercised options, stock that has not vested or equity incentive plan awards for any of our executive officers or
directors outstanding as of the end of our fiscal year ended December 31, 2010.
Compensation of Directors
At present, we do not pay our directors for attending meetings of the Board of Directors, although we may adopt a director
compensation policy in the future. We have no standard arrangement pursuant to which directors are compensated for any services they
provide or special assignments. We did, however, provide compensation to certain Directors during the year ended December 31, 2011
as follows:
32
Summary Director Compensation Table
Fees
Earned or
Paid in
Cash
($)
Stock
Awards
($)
Option
Awards
($)
Non-Equity
Incentive Plan
Compensation
($)
Nonqualified
Deferred
Compensation
Earnings
($)
-
-
-
-
- (1)
39,375 (2)
39,375 (3)
-
-
-
-
-
-
-
-
-
All Other
Compensation
($)
Total
($)
-
-
-
-
-
-
-
-
-
39,375
39,375
-
Name
Thomas Lapinski
Kenneth Danneberg
Wayne Turner
Gregory Williams
(1) Mr. Lapinski received no compensation in his capacity as a director during the year ended December 31, 2011. He did,
however, receive compensation in his capacity as an executive officer. (See the “Summary Executive Compensation Table”
above.)
(2) In February 2012, we issued Mr. Danneberg 25,000 shares of common stock in consideration for serving on the Board of
Directors during 2011. The shares were valued at $39,375.
(3) In February 2012, we issued Mr. Turner 25,000 shares of common stock in consideration for serving on the Board of
Directors during 2011. The shares were valued at $39,375.
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.
33
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following table sets forth certain information at March 1, 2012 with respect to the beneficial ownership of shares of common stock
by (i) each person known to us who owns beneficially more than 5% of the outstanding shares of common stock (based upon reports
which have been filed and other information known to us), (ii) each of our directors, (iii) each of our executive officers and (v) all of
our executive officers and directors as a group. Unless otherwise indicated, each stockholder has sole voting and investment power
with respect to the shares shown. As of March 20, 2011, there were 14,789,815 shares of common stock outstanding.
Name and address of beneficial owner
Thomas Lapinski
Chief Executive Officer and Director
2007 Enterprise Avenue
League City, Texas 77573
John A. Brda
President, Secretary and Director
1425 Frontenay
Warson Woods, Missouri 63122
Kenneth I. Danneberg
Director
4505 South Yosemite #379
Denver, Colorado 80237
Wayne Turner
Director
2450 Fondren, Suite 112
Houston, Texas 77063
Gregory Williams
Director
1105 Pine Hurst Court
Friendswood, Texas 77546
Amount of beneficial
ownership
Percent of class
4,600,000 shares
31.10%
2,512,500 shares (1)
16.99%
25,000 shares
0.17%
25,000 shares
0.17%
400,000 shares
2.70%
All directors and executive officers as a
group (5 persons)
7,562,500 shares
51.13%
(1) Includes 182,500 shares held individually by John A. Brda and 2,330,000 shares held by Brda & Company LLC, of
which Mr. Brda is the sole owner and Managing Director.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
On December 1, 2010, we entered into a Business Consultant Agreement with Tammy Skalko, our former director and Chief Executive
Officer. The agreement provided that in consideration for her consulting services, we would pay her $4,000 per month for the term of
the agreement (three months) and issue her 50,000 restricted shares of common stock. On December 17, 2010, we issued Ms. Skalko
the 50,000 shares of common stock which were valued at $150,000 on that date. For the year ended December 31, 2010, we paid Ms.
Skalko a total of $4,000 in cash under the agreement. For the year ended December 31, 2011, we paid Ms. Skalko a total of $8,000 in
cash under the agreement.
Director Independence
Currently three of our five directors are independent. Our independent directors are Kenneth Danneberg, Wayne Turner and Gregory
Williams. The definition of “independent” used herein is arbitrarily based on the independence standards of The NASDAQ Stock
Market LLC. The Board performed a review to determine the independence of Kenneth Danneberg, Wayne Turner and Gregory
Williams 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 our principal
independent accountants during the years ended December 31, 2011 and 2010. On November 23, 2010, we dismissed Patrick
Rodgers, CPA, PA (“Rodgers”) as our independent registered public accountant and engaged Calvetti, Ferguson & Wagner, P.C.
(“CFW”) as our new independent registered public accounting firm.
Audit Fees(1)
Audit Related Fees(2)
Tax Fees(3)
All Other Fees
Total Fees
2011
2010
$
29,000 $
11,477
780
-
$
41,257 $
23,000
-
-
-
23,000
(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 do not have a standing audit committee. Therefore, for the fiscal years ended December 31, 2011 and 2010 all audit services, audit-
related services and tax services, as described above, were provided to us by Rodgers and/or CFW based upon prior approval of the
Board of Directors.
35
ITEM 15. EXHIBITS
PART IV
Exhibit No. Description
2.1
Share Exchange Agreement dated November 23, 2010. (Incorporated by reference from Form 8-K filed with the SEC
on November 24, 2010.) *
3.1
3.2
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.) *
10.1
Employment Agreement between Thomas Lapinski and Torchlight Energy, Inc. (Incorporated by reference from Form
8-K filed with the SEC on November 24, 2010.) *
10.2
Agreement to Participate in Oil and Gas Development Joint Venture between Bayshore Operating Corporation, LLC
and Torchlight Energy, Inc. (Incorporated by reference from Form 8-K filed with the SEC on November 24, 2010) *
10.3
Employment Agreement with John A. Brda (Incorporated by reference from Form 8-K filed with the SEC on January
24, 2012.) *
14.1
16.1
21.1
31.1
Code of Ethics (Incorporated by reference from Form S-1 filed with the SEC on May 2, 2008.) *
Letter from Patrick Rodgers, CPA, PA to the SEC dated November 23, 2010. (Incorporated by reference from Form 8-
K filed with the SEC on November 24, 2010) *
Subsidiaries. (Incorporated by reference from Form 8-K filed with the SEC on November 24, 2010) *
Certification of principal executive officer required by Rule 13a – 14(1) or Rule 15d – 14(a) of the Securities Exchange
Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2
Certification of principal financial officer required by Rule 13a – 14(1) or Rule 15d – 14(a) of the Securities Exchange
Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1
Certification of principal executive officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and Section
1350 of 18 U.S.C. 63.
32.2
Certification of principal financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and Section 1350
of 18 U.S.C. 63.
101.INS
XBRL Instance Document
101.SCH
XBRL Taxonomy Extension Schema
101. CAL
XBRL Taxonomy Extension Calculation Linkbase
101.DEF
XBRL Taxonomy Extension Definitions Linkbase
101.LAB
XBRL Taxonomy Extension Label Linkbase
101.PRE
XBRL Taxonomy Extension Presentation Linkbase
* Incorporated by reference from our previous filings with the SEC
36
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 27, 2012
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
/s/ Thomas Lapinski
Thomas Lapinski
/s/ John A. Brda
John A. Brda
/s/ Kenneth I. Danneberg
Kenneth I. Danneberg
/s/ Wayne Turner
Wayne Turner
/s/ Gregory Williams
Gregory Williams
Title
Date
Director, Chief Executive Officer,
Principal Financial Officer and Principal
Accounting Officer
March 27, 2012
Director, President and Secretary
March 27, 2012
March 27, 2012
March 27, 2012
March 27, 2012
Director
Director
Director
37
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, 2011;
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. I am 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
Date: March 27, 2012
Exhibit 31.2
CERTIFICATION PURSUANT TO SECTION 302 OF THE
SARBANES-OXLEY ACT OF 2002
I, Thomas Lapinski, Principal 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, 2011;
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. I am 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, Principal Financial Officer
Date: March 27, 2012
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
In connection with the annual report on Form 10-K of Torchlight Energy Resources, Inc. (the "Company")
for the year ended December 31, 2011, as filed with the Securities and Exchange Commission on the date
hereof (the “Covered Report"), I, Thomas Lapinski, Chief Executive Officer of the Company, pursuant to 18
U.S.C. Sec.1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify
that:
The Covered Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the
Securities Exchange Act of 1934, as amended; and
The information contained in the Covered Report fairly presents, in all material respects, the financial
condition and results of operations of the Company.
IN WITNESS WHEREOF, I have executed this certificate as of this 37th day of March, 2012.
/s/ Thomas Lapinski
By: Thomas Lapinski, Chief Executive Officer
Exhibit 32.2
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002
In connection with the annual report on Form 10-K of Torchlight Energy Resources, Inc. (the "Company")
for the year ended December 31, 2011, as filed with the Securities and Exchange Commission on the date
hereof (the "Covered Report"), I, Thomas Lapinski, Principal Financial Officer of the Company, pursuant to
18 U.S.C. Sec.1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify
that:
The Covered Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the
Securities Exchange Act of 1934, as amended; and
The information contained in the Covered Report fairly presents, in all material respects, the financial
condition and results of operations of the Company.
IN WITNESS WHEREOF, I have executed this certificate as of this 27th day of March, 2012.
/s/ Thomas Lapinski
By: Thomas Lapinski, Principal Financial Officer