UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-KSB
(Mark One)
[X] Annual Report Pursuant to Section 13 or 15(d) of The Securities Exchange
Act of 1934
For the Fiscal Year Ended December 31, 2003
[ ] Transition Report Pursuant to Section 13 or 15(d) of The Securities
Exchange Act of 1934
Commission File Number 0-23530
TRANS ENERGY, INC.
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(Name of small business issuer in its charter)
Nevada 93-0997412
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(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
210 Second Street, P.O. Box 393, St. Marys, West Virginia 26170
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(Address of principal executive offices) (Zip Code)
Issuer's telephone no.: (304) 684-7053
Securities registered pursuant to Section 12(b) of the Exchange Act: None
Securities registered pursuant to Section 12(g) of the Exchange Act: Common
Check whether the issuer (1) filed all reports required to be filed by
Section 13 or 15(d) of the Exchange Act during the past 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 [
]
Check if there is no disclosure of delinquent filers in response to Item
405 of Regulation S-B contained in this form, and no disclosure will 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-
KSB or any amendment to this Form 10-KSB. [X]
State the issuer's revenues for its most recent fiscal year. $ 2,015,012
State the aggregate market value of the voting stock held by non-affiliates
computed by reference to the price at which the stock was sold, or the average
bid and ask prices of such stock as of a specified date within 60 days.
$2,102,996 (Based on price of $0.008 per share on March 30, 2004)
State the number of shares outstanding of each of the issuer's classes of
common equity, as of the latest practicable date.
Class Outstanding as of December 31, 2003
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Common Stock, Par Value 269,010,438
$.001 per share
DOCUMENTS INCORPORATED BY REFERENCE
A description of "Documents Incorporated by Reference" is contained in Part
III, Item 13.
Transitional Small Business Disclosure Format. Yes [ ] No [X]
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TRANS ENERGY, INC.
TABLE OF CONTENTS
Page
PART I
Item 1. Description of Business ....................................................... 3
Item 2. Description of Property........................................................ 13
Item 3. Legal Proceedings.............................................................. 15
Item 4. Submission of Matter to a Vote of Security Holders............................. 16
PART II
Item 5. Market for Common Equity and Related Stockholder Matters....................... 17
Item 6. Management's Discussion and Analysis or Plan of Operation...................... 17
Item 7. Financial Statements........................................................... 22
Item 8. Changes in and Disagreements with Accountants on Accounting and
Financial Disclosure........................................................... 22
Item 8A. Controls and Procedures........................................................ 22
PART III
Item 9. Directors, Executive Officers, Promoters and Control persons;
Compliance with Section 16(a) of the Exchange Act.............................. 22
Item 10. Executive Compensation......................................................... 24
Item 11. Security Ownership of Certain Beneficial Owners and Management................. 24
Item 12. Certain Relationships and Related Transactions................................. 25
Item 13. Exhibits and Reports on Form 8-K............................................... 26
Item 14. Principal Accountant Fees and Services......................................... 27
Signatures..................................................................... 28
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PART I
Item 1. Description of Business
History
Trans Energy, Inc. is engaged in the transportation, marketing and
production of natural gas and oil, and certain exploration and development
activities. We own interests in seven oil and gas wells in West Virginia and an
interest in seven oil wells in Wyoming that we do not operate. We also own and
operate an aggregate of over 100 miles of three-inch, 4-inch and 6-inch gas
transmission lines located within West Virginia in the Counties of Ritchie,
Tyler and Pleasants. This pipeline system gathers the natural gas produced from
these wells and from wells owned by third parties. We also have approximately
14,000 gross acres under lease in the Powder River Basin in Campbell, Crook and
Weston Counties, Wyoming.
In 1998, we purchased from GCRL Energy, Ltd. all of its interest in the
Powder River Basin in Campbell and Crook Counties, Wyoming, consisting of
interests in five (5) wells, four (4) of which are producing, interests in
30,000 leasehold acres, and interests in approximately seventy-three miles of
3-D seismic data. The properties include three producing fields from Minnelusa
Sandstone and were discovered on 3-D seismic. During 1999, the Sagebrush 3 well
was drilled in the Sagebrush field in Campbell County Wyoming. It will be used
as a water disposal well for the Sagebrush #1 and #2. It is anticipated that the
Sagebrush #3 will be put into operation as an injection well for the water flood
during the summer of 2004.
Our principal executive offices are located at 210 Second Street, P.O. Box
393, St. Marys, West Virginia 26170, and our telephone number is (304) 684-7053.
Business Development
In 2001, we continued our interest in the Trenton - Black River deep gas
field in the Appalachian Basin in West Virginia. We believes that this area may
become active in the counties in which we operate. We continue to focus much of
our efforts in this area to take advantage of the situation if the opportunity
becomes available. In 1999, we sold many of our Appalachian Basin assets and
purchased 51% of a producing well in the Powder River Basin in Wyoming. We then
focused our attention toward developing our acreage in the Powder River Basin in
Wyoming and drilling for deep gas in the Trenton- Black River area.
Our business strategy is to economically increase reserves, production and
the sale of gas and oil from existing and acquired properties in the Powder
River Basin, Appalachian Basin and elsewhere, in order to maximize shareholders'
return over the long term. Our strategic location in West Virginia enables us to
actively pursue the acquisition and development of producing properties in that
area that will enhance our revenue base without proportional increases in
overhead costs.
On December 31, 2003, we sold our 75% working interest ownership in five
oil and gas wells located in Tyler County, West Virginia to Ultra-Light
Investments for $380,000. Of the total proceeds, $30,000 was used to pay off
existing debt on the wells. The balance of $350,000 was used to settle an
ongoing dispute with Baker Hughes Oilfield Operations, Inc. d/b/a/ Baker Hughes
Inteq, Western Geophysical, a division of Western Atlas International, Inc. The
$350,000 was considered as payment in full and we were given a release of all
judgments and liens against us in the matter.
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The following is a summary of our oil and gas assets including wells and
pipelines that we acquired in September 1993:
Tyler Construction Company, Inc.
We acquired an interest equal to 65% of the total outstanding shares of
Tyler Construction Company from Loren E. Bagley and William F. Woodburn, both of
whom are directors of Trans Energy. Tyler Construction owns and operates a
natural gas gathering pipeline system serving the industrialized Ohio Valley,
initially consisting of approximately 27 miles of 6-inch pipeline and 10 miles
of 4-inch pipeline.
Tyler Construction's trunk line system consists of 6-inch pipeline that
begins at the town of St. Marys, West Virginia, located on the Ohio River in the
County of Pleasants in western West Virginia, and proceeds twenty-seven miles
due east to Bradden Station, West Virginia. Near Bradden Station, the pipeline
intercepts major transmission lines of Equitable Natural Gas, Dominion
Transmission, Inc. and Eastern American Energy. An intercepting line consisting
of ten miles of 4-inch pipeline begins at a point eight miles east of St. Marys
and proceeds north 10 miles to an industrial park located seven miles south of
Sistersville, West Virginia. At this point, gas is delivered to OSI Specialties
(formerly Union Carbide) and Consolidated Aluminum Corporation of America under
a marketing agreement with Sancho. Pursuant to our agreement with Sancho, we
have the right to sell natural gas subject to the terms and conditions of a
20-year contract, as amended, that Sancho entered into with Hope Gas, Inc. in
1988. This agreement is a flexible volume supply agreement whereby we receive
the full price which Sancho receives less a $.05 per Mcf marketing fee paid to
Sancho. The price of the natural gas is based upon the residential gas index and
the Inside F.E.R.C. CNG Index.
On February 28, 2003, we sold 7.6 miles of the 6-inch pipeline to PC
Pipeline, Inc., located in Morgantown, West Virginia. In consideration for the
sale, we received 35% of the outstanding stock of Tyler Construction from
Ecological Energy, Inc., an affiliate of PC Pipeline. As a result of the
transaction, we now own 100% of the capital stock of Tyler Construction.
Also on February 28, 2003, we sold 10 miles of the 4-inch pipeline to Triad
Energy Corporation, located in Marietta, Ohio, for the cash consideration of
$270,000. Proceeds from the sale were used to pay down existing short and
long-term debt.
On March 17, 2004, Tyler Construction sold 16,000 feet of 6-inch pipeline
located in Pleasants and Tyler Counties, West Virginia for $70,000. Tyler
Construction also sold 30,096 feet of 4-inch pipeline located in Pleasants and
Ritchie Counties, West Virginia for $130,000. The buyer in both instances was
Triad Energy Corporation of Reno, Ohio. Of the total proceeds, $161,391 was used
to pay off the bank debt of the pipelines and the balance was used as operating
capital. Following the sale, we retain approximately 16.3 miles of 6-inch
pipeline in Tyler County.
Spencer Wells
We acquired all rights, title and interest to six producing oil and gas
wells located in West Virginia, in exchange for shares of Trans Energy common
stock. Five of the wells identified as "Fowler," "Goff," "Locke," "McGill" and
"Workman" are situated in Ritchie County in a proven reservoir field. The
remaining well identified as "Spencer," is located in Tyler County. All six
wells were completed in 1991 and have been producing oil and gas through the
date hereof. In 1999, five of these wells were sold to an unaffiliated third
party and in 2000, the sixth well was sold to an unaffiliated third party.
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The Pipeline, Ltd.
We acquired from Tyler Pipeline, Inc. all rights, title and interest in the
natural gas gathering pipeline system known as The Pipeline, Ltd. (the name of
the pipeline, not a legal entity), a 4-inch pipeline that begins at Twiggs, West
Virginia, nine miles east of St. Marys, West Virginia where it intercepts Tyler
Construction's trunk line system and proceeds due south for a distance of six
miles. The Pipeline, Ltd. system is used for purchasing gas from third party
producers. Mr. Woodburn, our Secretary / Treasurer and a director, is also
President and owns 50% of Tyler Pipeline. Mr. Bagley, our Vice President and a
director, also owns 50% of Tyler Pipeline.
Ritchie County Gathering Systems, Inc.
We acquired all the issued and outstanding capital stock of Ritchie County
Gathering Systems, Inc., a West Virginia corporation. Ritchie County Gathering
owns and operates a 4-inch natural gas gathering line which begins five miles
south of Cairo, West Virginia at Rutherford, and proceeds due south for 4.6
miles, crossing Mellon Ridge and ending at Macfarlan Creek approximately 1/2
mile north of the South Fork of the Hughes River. The Ritchie County Gathering
pipeline is used for purchasing gas from third party producers and delivering
such gas to Hope Gas.
Powder River Basin Wyoming
On March 6, 1998, we entered into an agreement to purchase from GCRL
Energy, Ltd. all of its interest in the Powder River Basin in Campbell and Crook
Counties, Wyoming, consisting of interests in five (5) wells, four (4) of which
are producing, interests in 30,000 leasehold acres, and interests in
approximately seventy-three miles of 3-D seismic data. The properties include
three producing fields from Minnelusa Sandstone and were discovered on 3-D
seismic. We made an initial payment for the properties of $50,000 and the
balance of $2,987,962 was paid for with proceeds from the sale of debentures.
The following table sets forth information concerning the existing oil
production per day of the producing wells located on the GCRL property.
Gross Bbls.
Name of Well Oil Per Day Net % to TSRG Net Bbls. to TSRG
------------ ------------ ------------- -----------------
Sagebrush Fed #1 47 48.8% 23
Sagebrush Fed #2 0 47.5% 0
Pinon Fee #1 16 51.2% 8
Swartz Draw 34 15.4% 5
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Total 97 36
Current Business Activities
We operate our oil and natural gas properties and transports and markets
natural gas through our transmission systems in West Virginia. Although
management desires to acquire additional oil and natural gas properties and to
become more involved in exploration and development, this can only be
accomplished if we can secure future funding. Management intends to continue to
develop and increase the production from the oil and natural gas properties that
it currently owns.
Although we will continue to transport and market natural gas through our
various pipelines, there are no current plans to acquire or to lay any
additional pipeline systems in 2003. Apart from one well drilled in the Powder
River basin in Wyoming (Sagebrush #3) and the seven re-entry Benson wells
drilled in West Virginia, we have not participated in any new wells in the last
four years.
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Powder River Basin Wyoming - Prima
On December 28, 1996, we purchased 420 acres in the Powder River basin in
Wyoming for $50,000 from an unaffiliated third party. Included in the purchase
price was a condition that the previous owners would provide all of the geologic
and geophysical work as part of the purchase price. On February 3, 1997 we
leased an additional 480 acres that joined with our acreage position. The target
formation is the Minnelusa "B1" sand. There presently are no producing wells on
such acreage and no proved reserves located on the acreage owned by us.
Five two-dimensional ("2-D") seismic lines and a 6-square mile
three-dimensional ("3-D") seismic program have been shot across the acreage now
held by us. Unlike 2-D seismic testing which provides a cross-sectional view of
the subsurface of the Earth, 3-D testing provided a full, three-dimensional view
of the subsurface. Such views allow for greater precision in the location of
potential drilling sites. 3-D testing allows potential drillers to obtain
accurate estimates of the size of oil and gas bearing structures and the profile
of the structure. 2-D testing only informs the driller that an oil and gas
bearing structure is in a particular area, without giving information as to size
and shape. Without an accurate estimate of the size of the oil and gas bearing
structures, it is difficult to accurately estimate the reserves in the
structure, and, thus, the economic viability of drilling into a particular
structure. Without an accurate profile of the structure, a driller may not hit
the most economic portion of the structure.
Water pressure primarily is responsible for the movement of oil within the
area of our acreage. Where water pressure is the cause of oil movement, finding
the apex of the oil bearing structure is critical. Drilling into the apex of
such a structure usually assures that a maximum amount of oil, and a minimal
amount of water, will be recovered from a well. Hitting such a zone elsewhere
than at the apex will result in a lower proportion of oil to water and reduced
rates of recovery.
We completed drilling the Fowler 22-8 in January 1998 and determined the
well to be a dry hole and was plugged. We have not done further drilling on the
acreage.
Powder River Basin Wyoming - Wolffe Prospect
In 1997, we purchased a 30% working interest in the Wolffe Prospect in the
Powder River Basin in Campbell County, Wyoming for $65,000 from an unaffiliated
third party. Included in the purchase price was a 30% working interest in the
Wolffe #1-35 well and 30% interest in 240 acres. In October 1997, we
participated in our share of the drilling of the Horizon 32-35 well. The target
formation was the Minnelusa "B1" sand. The well was determined to be a dry hole
and plugged. On November 15, 1999, we purchased for $16,000 an additional 51%
working interest in the Wolff 1-35 well from Renor Exploration Limited. In
September 2002, we transferred this well to an unaffiliated third party in
settlement of a lawsuit.
Sistersville
In 1995, we purchased approximately 2,200 acres in a known producing field
located near Sistersville, West Virginia for $100,000. The Sistersville field
has been in operation since the 1890's, although at a very low level for the
past several years. To date the field has produced over 13 million barrels of
oil. The field contains portions of the Big Injun and Keener sands formations,
both well known oil and gas bearing formations, which are the zones we intend to
explore. These formations are approximately 1,700 feet deep. Recoverable
reserves of oil in the field are estimated at several million barrels. We
drilled a well on the Sistersville acreage in April 1997. In 1999, we sold the
Sistersville field for $125,000 to an unaffiliated third party.
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Research and Development
We have not allocated funds for conducting research and development
activities and, due to the nature of our business. We do not anticipate
allocating funds for research and development in the immediate future.
Marketing
We operate exclusively in the oil and gas industry. Natural gas production
from wells owned by us is generally sold to various intrastate and interstate
pipeline companies and natural gas marketing companies. Sales are generally made
on the spot market or under short-term contracts (one year or less) providing
for variable or market sensitive prices. These prices often are tied to natural
gas futures contracts as posted in national publications.
Natural gas delivered through our pipeline network is sold through the
Sancho Oil and Gas Corporation contract to the industrial facilities near
Sistersville, West Virginia, or to Hope Gas, a local utility. Some of the gas is
sold at a fixed price on a year long basis and some at a variable price per
month per Mcf. Under our contract with Sancho, we have the right to sell natural
gas subject to the terms and conditions of a 20-year contract, as amended, that
Sancho entered into with Hope Gas in 1988. This agreement is a flexible volume
supply agreement whereby we receive the full price which Sancho charges the end
user less a $.05 per Mcf marketing fee paid to Sancho. The price of the natural
gas is based upon the greater of the residential gas commodity index and
published Inside F.E.R.C. Index, at our option, for the first 1,500 Mcf
purchased per day by Hope Gas and thereafter the price is the Inside F.E.R.C.
Index. The residential gas commodity index does not directly fluctuate with the
overall price of natural gas. The Inside F.E.R.C. Index fluctuates monthly with
the change in the price of natural gas. While such option provides certain price
protection for us, there can be no assurance that prices paid by us to suppliers
will be lower than the price which we would receive under the Hope Gas
arrangement. Prior to June 1, 1996, the price was the residential gas commodity
index and when the market price of gas rose above such index, our ability to
purchase gas from third parties was adversely effected.
We sell our oil production to third party purchasers under agreements at
posted field prices. These third parties purchase the oil at the various
locations where the oil is produced.
Although management believes that we are not dependent upon any one
customer, our marketing arrangement with Sancho accounted for approximately 82%
of our revenue for the year ended December 31, 2003, and approximately 26% for
the year ended December 31, 2002. This marketing agreement is in effect until
September 1, 2008.
In addition to the natural gas produced by our wells, we also purchased
approximately 500 Mcf of natural gas per day in 2003.
Competition
We are in direct competition with numerous oil and natural gas companies,
drilling and income programs and partnerships exploring various areas of the
Appalachian and Powder River Basins and elsewhere, and competing for customers.
Many competitors are large, well-known oil and gas and/or energy companies,
although no single entity dominates the industry. Many of our competitors
possess greater financial and personnel resources enabling them to identify and
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acquire more economically desirable energy producing properties and drilling
prospects than us. Additionally, there is competition from other fuel choices to
supply the energy needs of consumers and industry. Management believes that
there exists a viable market place for smaller producers of natural gas and oil
and for operators of smaller natural gas transmission systems.
Under our contract with Sancho, we have the right to sell natural gas
subject to the terms and conditions of a 20-year contract, as amended, that
Sancho entered into with Hope Gas in 1988. This agreement is a flexible volume
supply agreement whereby we receive the full price which Sancho receives less a
$.05 per Mcf marketing fee paid to Sancho. The price of the natural gas is based
upon indices that include the residential gas commodity charge of Hope Gas and
the Inside F.E.R.C. CNG Index. Were it not for the relationship between Hope Gas
and Sancho, Hope Gas would compete directly with us for the sale of gas to
certain customers, specifically OSI Specialities, Inc. and Ormet Aluminum
Company.
Government Regulation
The oil and gas industry is extensively regulated by federal, state and
local authorities. The scope and applicability of legislation is constantly
monitored for change and expansion. Numerous agencies, both federal and state,
have issued rules and regulations binding on the oil and gas industry and its
individual members, some of which carry substantial penalties for noncompliance.
To date, these mandates have had no material effect on our capital expenditures,
earnings or competitive position.
Legislation and implementing regulations adopted or proposed to be adopted
by the Environmental Protection Agency ("EPA") and by comparable state agencies,
directly and indirectly affect our operations. We are required to operate in
compliance with certain air quality standards, water pollution limitations,
solid waste regulations and other controls related to the discharging of
materials into, and otherwise protecting the environment. These regulations also
relate to the rights of adjoining property owners and to the drilling and
production operations and activities in connection with the storage and
transportation of natural gas and oil.
We may be required to prepare and present to federal, state or local
authorities data pertaining to the effect or impact that any proposed operations
may have upon the environment. Requirements imposed by such authorities could be
costly, time-consuming and could delay continuation of production or exploration
activities. Further, the cooperation of other persons or entities may be
required for us to comply with all environmental regulations. It is conceivable
that future legislation or regulations may significantly increase environmental
protection requirements and, as a consequence, our activities may be more
closely regulated which could significantly increase operating costs. However,
management is unable to predict the cost of future compliance with environmental
legislation. As of the date hereof, management believes that we are in
compliance with all present environmental regulations. Further, we believe that
our oil and gas explorations do not pose a threat of introducing hazardous
substances into the environment. If such event should occur, we could be liable
under certain environmental protection statutes and laws. We presently carry
insurance for environmental liability.
Our exploration and development operations are subject to various types of
regulation at the federal, state and local levels. Such regulation includes the
requirement of permits for the drilling of wells, the regulation of the location
and density of wells, limitations on the methods of casing wells, requirements
for surface use and restoration of properties upon which wells are drilled, and
governing the abandonment and plugging of wells. Exploration and production are
also subject to property rights and other laws governing the correlative rights
of surface and subsurface owners.
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We are subject to the requirements of the Occupational Safety and Health
Act, as well as other state and local labor laws, rules and regulations. The
cost of compliance with the health and safety requirements is not expected to
have a material impact on our aggregate production expenses. Nevertheless, we
are unable to predict the ultimate cost of compliance.
Although past sales of natural gas and oil were subject to maximum price
controls, such controls are no longer in effect. Other federal, state and local
legislation, while not directly applicable to us, may have an indirect effect on
the cost of, or the demand for, natural gas and oil.
Employees
As of the date hereof we employ eight people full-time, consisting of three
executives, two marketing and clerical persons, and three production persons.
Management presently anticipates hiring additional employees as business
conditions warrant and as funds are available.
Facilities
We currently occupy approximately 4,000 square feet of office space in St.
Marys, West Virginia, which we share with our subsidiaries, Tyler Construction
Company and Ritchie County Gathering Systems. We lease an aggregate of
approximately 4,000 square feet from an unaffiliated third party under a verbal
arrangement for $1,400 per month, inclusive of utilities. Management believes
that our present office facilities are adequate for our current business
operations.
Industry Segments
No information is presented as to industry segments. We are presently
engaged in the principal business of the exploration, development, production,
transportation and marketing of natural gas and oil. Reference is made to the
statements of operations contained in the financial statements included herewith
for a statement of our revenues and operating loss for the past two fiscal
years.
Risk Factors
You should carefully consider the risks and uncertainties described below
and other information in this report. If any of the following risks or
uncertainties actually occur, our business, financial condition and operating
results, would likely suffer. Additional risks and uncertainties, including
those that are not yet identified or that we currently believe are immaterial,
may also adversely affect our business, financial condition or operating
results.
We have a history of losses and anticipate future losses
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Although our revenues increased approximately 126% during the fiscal year
ended December 31, 2003, and we may not achieve, or subsequently maintain
profitability if anticipated revenues do not increase in the future. We have
experienced operating losses, negative cash flow from operations and net losses
in each quarterly and annual period for the past several years. As of December
31, 2003, our net operating loss carryforward was approximately $19.7 million
and our accumulated deficit was approximately $28.7 million. We expect to
continue to incur significant expenses in connection with
* exploration and development of new and existing properties;
* costs of sales and marketing efforts;
* additional personnel; and
* increased general and administrative expenses.
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Accordingly, we will need to generate significant revenues to achieve and
attain, and eventually sustain profitability. If revenues do not increase, we
may be unable to attain or sustain profitability on a quarterly or annual basis.
Any of these factors could cause the price of our stock to decline.
There are many competitors in the oil and gas industry
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We encounter many competitors in the oil and gas industry, both in the
exploration and development of properties and in the sale of oil and gas.
Management expects competition to continue and intensify in the future. If we
are unable to successfully compete with other oil and gas companies, our
business will be adversely affected.
Our operating results are likely to fluctuate significantly and cause our
stock price to be volatile which could cause the value of your investment
in our shares to decline
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Quarterly and annual operating results are likely to fluctuate
significantly in the future due to a variety of factors, many of which are
outside of our control. If operating results do not meet the expectations of
securities analysts and investors, the trading price of our common stock could
significantly decline which may cause the value of your investment to decline.
Some of the factors that could affect quarterly or annual operating results or
impact the market price of our common stock include:
* our ability to develop properties and to market our oil and gas;
* the timing and amount of, or cancellation or rescheduling of,
orders for our oil and gas;
* our ability to retain key management, sales and marketing and
engineering personnel;
* a decrease in the prices of oil and gas; and
* changes in costs of exploration or marketing oil and gas.
Due to these and other factors, quarterly and annual revenues, expenses and
results of operations could vary significantly in the future, and
period-to-period comparisons should not be relied upon as indications of future
performance.
Additional share issuances could be dilutive
--------------------------------------------
If we do not generate necessary cash from our operations to finance future
business, we may need to raise additional funds through public or private
financing opportunities. Selling additional stock could dilute the equity
interests of existing stockholders. If we borrow more money, we will have to pay
interest and may also have to agree to restrictions that limit operating
flexibility. We may not be able to obtain funds needed to finance operations at
all, or may be able to obtain funds only on very unattractive terms. Management
may also explore other alternatives such as a joint venture with other oil and
gas companies. There can be no assurances, however, that we will conclude any
such transaction.
Outside factors may influence our business development
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We expect to experience significant fluctuations in future results of
operations due to a variety of factors, many of which are outside of our
control, including:
* demand for oil and gas;
* attempts to expand into new markets;
* competitive factors that affect pricing;
* the timing and magnitude of capital expenditures, including costs
relating to the expansion of operations;
* hiring and retention of key personnel;
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* changes in generally accepted accounting policies, especially those
related to the oil and gas industry; and
* new government legislation or regulation.
Any of the above factors could have a negative effect on our business and
on the price of our common stock.
If we lose key personnel, we may be unable to operate successfully
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We depend on the continued contributions of our executive officers and
other technical and marketing personnel to work effectively as a team, to
execute our business strategy and to manage our business. The loss of key
personnel or their failure to work effectively could have a material adverse
effect on our business, financial condition and results of operations.
Going concern issue
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Our independent auditors have expressed a going concern issue. Our ability
to continue as a going concern is dependant upon our ability to achieve a
profitable level of operations. Management will need, among other things,
additional capital resources which it may seek through loans from shareholders.
We expect that we will need approximately $300,000 to cover our negative cash
flow through fiscal 2004. However, management cannot provide any assurances that
we will be successful in accomplishing any of our plans.
Risks relating to ownership of our common stock
The price of our common stock is extremely volatile and investors may not
be able to sell their shares at or above their purchase price, or at all.
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Our common stock is presently traded on the OTC Bulletin Board, although
there is no assurance that a viable market will continue. The price of our
shares in the public market is highly volatile and may fluctuate substantially
because of:
* actual or anticipated fluctuations in our operating results;
* changes in or failure to meet market expectations;
* conditions and trends in the oil and gas industry; and
* fluctuations in stock market price and volume, which are
particularly common among securities of small capitalization
companies.
We do not intend to pay dividends
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To date, we have never declared or paid a cash dividend on shares of our
common stock. We currently intend to retain any future earnings for growth and
development of business and, therefore, do not anticipate paying any dividends
in the foreseeable future.
Possible "Penny Stock" Regulation
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Trading of our common stock on the OTC Bulletin Board may be subject to
certain provisions of the Securities Exchange Act of 1934, commonly referred to
as the "penny stock" rule. A penny stock is generally defined to be any equity
security that has a market price less than $5.00 per share, subject to certain
exceptions. If our stock is deemed to be a penny stock, trading in our stock
will be subject to additional sales practice requirements on broker-dealers.
These may require a broker dealer to:
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* make a special suitability determination for purchasers of penny
stocks;
* receive the purchaser's written consent to the transaction prior to
the purchase; and
* deliver to a prospective purchaser of a penny stock, prior to the
first transaction, a risk disclosure document relating to the penny
stock market.
Consequently, penny stock rules may restrict the ability of broker-dealers
to trade and/or maintain a market in our common stock. Also, many prospective
investors may not want to get involved with the additional administrative
requirements, which may have a material adverse effect on the trading of our
shares.
Item 2. Description of Property
Our properties consist essentially of working and royalty interests owned
by us in various oil and gas wells and leases located in West Virginia. On
December 31, 2003, we sold our 75% working interest ownership in five oil and
gas wells located in Tyler County, West Virginia to Ultra-Light Investments for
$380,000. The wells included Eastlack #1, Nolan #2, Nolan #3, Nolan #4 and Nolan
#5. Our proved reserves for the years ended December 31, 2003, 2002 and 2001 are
set forth below:
December 31,
2003 2002 2001
-------- ----------- -----------
Natural Gas (MMcf)
Developed -- 1,131,415 1,133,839
Undeveloped -- -- --
Total Proved -- 1,131,415 1,133,839
Crude Oil (MBbl)
Developed 99,880 113,406 147,876
Undeveloped -- -- --
Total Proved 99,880 113,406 147,876
These estimates are bases primarily on the reports of Robert L. Richards,
Geologist and presently an officer and director of Trans Energy. Such reports
are, by their very nature, inexact and subject to changes and revisions. Proved
developed reserves are reserves expected to be recovered from existing wells
with existing equipment and operating methods. Proved undeveloped reserves are
expected to be recovered from new wells drilled to known reservoirs on undrilled
acreage for which existence and recoverability of such reserves can be estimated
with reasonable certainty, or from existing wells where a relatively major
expenditure is required to establish production. No estimates of reserves have
been included in any reports to any federal agency other than the SEC. See SFAS
69 Supplemental Disclosures included as part of our consolidated financial
statements.
Set forth in the following schedule is the average sales price per unit of
oil, expressed in barrels ("bbl"), and of natural gas, expressed in thousand
cubic feet ("mcf"), produced by us for the past three fiscal years.
Years ended December 31,
Average sales price: 2003 2002 2001
------------------- ------ ------ ------
Gas (per mcf) $ 7.04 $ 4.73 $ 5.22
Oil (per bbl) 23.38 17.91 16.22
Average cost of production:
Gas (per mcf) -- -- --
Oil (per bbl) 4.58 5.03 4.05
-13-
We have not filed any estimates of total, proved net oil and gas reserves
with any federal authority or agency since the beginning of our last fiscal
year.
The following schedule sets forth the capitalized costs relating to oil and
gas producing activities by us for the past three fiscal years.
Years ended December 31,
2003 2002 2001
----------- ----------- -----------
Proved oil and gas
producing properties
and related lease
and well equipment $ 3,171,426 $ 3,678,730 $ 3,617,505
Unproved oil and gas
properties 99,945 95,945 114,426
Accumulated depreciation
and depletion (2,555,878) (1,839,295) (1,009,429)
----------- ----------- -----------
Net Capitalized Costs $ 715,493 $ 1,935,380 $ 2,722,502
=========== =========== ===========
The following schedule summarizes changes in the standardized measure of
discounted future net cash flows relating to our proved oil and gas reserves.
Years ended December 31,
2003 2002 2001
----------- ----------- -----------
Standardized measure,
beginning of year $ 4,314,941 $ 3,649,994 $ 4,425,778
Oil and gas sales, net
of production costs (2,411,293) -- --
Sales of mineral in place -- -- (1,039,658)
Purchases -- -- --
Net change due to revisions
in quantity estimates (39,271) 664,947 263,874
----------- ----------- -----------
Standardized measure,
end of year $ 1,864,377 $ 4,314,941 $ 3,649,994
=========== =========== ===========
We do not anticipate investing in or purchasing assets and/or property for
the purpose of capital gains. It is our intention to purchase assets and/or
property for the purpose of enhancing our primary business operations. We are
not limited as to the percentage amount of our assets we may use to purchase any
additional assets or properties.
-14-
Item 3. Legal Proceedings
Certain material pending legal proceedings to which we are a party or to
which any of our property is subject is set forth below.
(a) On February 7, 2001, the United States Bankruptcy Court, Southern
District of Texas, entered an Order Granting Motion to Dismiss Chapter 7
Case in the action entitled In Re: Trans Energy, Inc., Case No.
00-39496-H4-7. The Order dismissed the involuntary bankruptcy action
instituted against us on October 16, 2000. The sole petitioning creditor
named in the Involuntary Petition was Western Atlas International, Inc. An
Order for Relief Under Chapter 7 was entered by the Court on November 22,
2000.
On April 23, 2000, the 189th District Court of Harris County, Texas entered
an Agreed Final Judgment in favor of Western against us in the amount of
$600,665.36, together with post judgment interest at 10% per annum.
Following the judgment, we entered into settlement negotiations with
Western concerning our satisfaction of the judgment through payments over a
four to five month period, together with the pledge of collateral on
certain unencumbered assets. Previously, on or about July 9, 1998, a
judgment had been entered in the 152nd District Court of Harris County,
Texas against us in favor of Baker Hughes Oilfield Operations, Inc. d/b/a/
Baker Hughes Inteq. Western Geophysical ("Baker"), a division of Western
Atlas International, Inc., in the amount of $41,142.00, together with
interest and attorney fees. This judgment was outstanding at the time of
the filing of the Involuntary Petition.
During our negotiations with Western for settlement of the Judgment, we
made a $200,000 "good faith payment" to Western's counsel on October 23,
2000. On December 12, 2000, Joe Hill was named as the Chapter 7 Trustee.
Subsequently, Western's counsel delivered the $200,000 to the Trustee.
On January 19, 2001, we filed with the Bankruptcy Court the Motion to
Dismiss Chapter 7 Case. The reasons cited in support of the Motion to
Dismiss included, but were not limited to, (i) the Texas Court being an
improper venue for the action, and (ii) we never receiving the Involuntary
Petition and Summons notifying it of the action. In anticipation of the
Bankruptcy Court dismissing the Involuntary Petition, on February 2, 2001,
we entered into a Settlement Agreement with Baker Hughes Oilfield
Operation, Inc., d/b/a/ Baker Hughes Inteq. Western Geophysical, a division
of Western Atlas International, Inc. (the "Baker Entities"). In entering
its order on February 7, 2001 to dismiss the action, the Court ordered the
Trustee to retain $17,694.80 for satisfaction of administrative fees and
expenses, and to pay to Western and Baker the sum of $182,736.66, on our
behalf and pursuant to the terms of the Settlement Agreement.
The Settlement Agreement provided that, subject to the approval of the
Bankruptcy Court, we agreed to pay to the Baker Entities $759,664.31, plus
interest at 10%. In addition to the $200,000 payable from the escrow, we
pledged as collateral certain properties, personal property and fixtures
and two directors each pledged 750,000 shares of our common stock which
they personally own. Subsequently, we assigned the income stream from the
sale of oil in the Pinon Fee #1, Sagebrush #1 and Sagebrush #2 to the Baker
Entities as payments toward the amounts owed.
The Baker Entities continue their proceedings to enforce a foreign judgment
against us in Pleasants County, West Virginia. On December 23, 2003 we
entered into a Settlement Agreement and Mutual Release with the Baker
Entities whereby we paid $350,000 to the Baker Entities as payment in full
for all monies owed and the Baker Entities gave us a release of all
judgments and liens against us.
-15-
(b) On September 22, 2000, Tioga Lumber Company obtained a judgment of
$43,300 plus interest in the Circuit Court of Pleasants County, West
Virginia, against Tyler Construction Company for breach of contract. On
February 28, 2002, we reached a negotiated payment schedule with Tioga and
made the initial payment. We believe that we have satisfied the balance
owed to Tioga of $26,233.58, although the judgment has not yet been
released. We are proceeding to secure the release of the judgment.
(c) On April 16, 2001, Ross Forbus obtained a judgment of $428,018 against
us to satisfy a promissory note previously entered into with Mr. Forbus on
April 8, 1996. We agreed to payment terms and has made several payments to
Mr. Forbus. Mr. Forbus has made a demand upon for payment in full.
(d) In January 2002, a suit entitled Dennis L. Spencer vs. Trans Energy,
Inc. and Messrs. Woodburn and Bagley was filed in the Circuit Court of
Ritchie County, West Virginia ( Civil Action No. 02-C- 02). The complaint
alleges that we sold certain assets which Mr. Spencer claims to be the
beneficial owner. The complaint seeks $1,000,000 in damages. We have filed
an answer to the complaint and the matter is still pending.
(e) On January 15, 2003, a suit against us entitled Lario Oil & Gas Company
vs. Trans Energy, Inc. (Civil Action No. 24575) was initiated in the Sixth
District Court of Campbell County, Wyoming. Lario's suit asks for
$50,692.10 which it claims we owe for operating fees on the Sagebrush #1
and #2 and the Pinon Fee #1 wells, operated by Lario and in which we have
working interests. We are preparing an answer to the complaint and are
asking for a complete accounting of all monies owed. Lario is retaining our
share of monthly oil production monies and applying them to the amount
owed. As of December 31, 2003, the amount due was $51,371.
(f) On February 5, 2003, O.C. Smith obtained a judgment against us for
$6,000 in the Circuit Court of Ritchie County, West Virginia. Mr. Smith had
brought suit against our predecessor Apple Corporation, for an accounting
of all gas purchased by us as well as judgment for all amounts still owing.
We acquired all of Apple Corporation's interest in this well and management
determined that there was an unpaid balance still owing Mr. Smith. The
$6,000 was payable in three monthly installments beginning on April 25,
2003. The final installment was paid on February 23, 2004 and we consider
the judgment paid in full.
Item 4. Submission of Matters to a Vote of Security Holders
No matters were submitted to a vote of our securities holders during the
fourth quarter of the fiscal year ended December 31, 2003.
PART II
Item 5. Market for Common Equity and Related Stockholder Matters
Our common stock is quoted on the OTC Bulletin Board under the symbol
"TSRG." Set forth in the table below are the quarterly high and low prices of
our common stock as obtained from the Nasdaq Small-Cap Market and the OTC
Bulletin Board for the past two fiscal years.
High Low
---- ---
2003
----
First Quarter $ .004 $ .002
Second Quarter $ .007 $ .002
Third Quarter $ .006 $ .002
Fourth Quarter $ .028 $ .003
-16-
2002
----
First Quarter $ .026 $ .005
Second Quarter $ .019 $ .007
Third Quarter $ .012 $ .002
Fourth Quarter $ .009 $ .002
--------------------------
As of December 31, 2003, there were approximately 390 holders of record of
our common stock, which figure does not take into account those shareholders
whose certificates are held in the name of broker-dealers or other nominee
accounts.
Dividend Policy
We have not declared or paid cash dividends or made distributions in the
past, and we do not anticipate that we will pay cash dividends or make
distributions in the foreseeable future. We currently intends to retain and
reinvest future earnings to finance operations.
Recent Sales of Unregistered Securities
During 2002, we issued 60,835,938 shares of common stock for cash, services
and conversion of debt at an average of $.01 per share, or an aggregate of
$337,250.
During 2003, we issued 27,841,311 shares of common stock for the
extinguishment of certain debts and related interest valued at $75,116, or an
average price of $.0027 per share, and an additional 150,000 shares upon the
conversion of convertible debt in the amount of $5,250, or $.035 per share. We
also issued 3,500,000 shares in exchange for services valued at $10,500, or
$.003 per share.
Shares issued for cash, services and extinguishment of debt, were issued in
reliance upon the exemption from registration under the Securities Act of 1933,
provided by Section 4(2) thereunder. Issuances of shares upon conversion of
debentures or other debt were pursuant to the exemption provided by Section
3(a)(9) of said Act.
Item 6. Management's Discussion and Analysis or Plan of Operation
The following information should be read in conjunction with the
consolidated financial statements and notes thereto appearing elsewhere in this
Form 10-KSB.
Results of Operations
The following table sets forth the percentage relationship to total
revenues of principal items contained in the statements of operations of the
consolidated financial statements included herewith for the two most recent
fiscal years ended December 31, 2003, and 2002. It should be noted that
percentages discussed throughout this analysis are stated on an approximate
basis.
-17-
Fiscal Years Ended
December 31,
2003 2002
----- ------
Total revenues............................................... 100% 100%
Total costs and expenses..................................... 153 257
Total other income (expenses)................................ (14) (62)
Loss before taxes and change in accounting principal......... (67) (219)
Income taxes................................................. - -
Change in accounting principal............................... (6) -
Net (loss)................................................... (73) (219)
For the Year Ended December 31, 2003 Compared to the Year Ended December 31,
2002
--------------------------------------------------------------------------------
Total revenues of $2,015,012 for the year ended December 31, 2003 ("2003")
increased 126% when compared to $889,764 for the year ended December 31, 2002
("2002") due primarily to increased oil and gas prices and greater gas volume in
our pipelines. In 2003, oil made up 26% of total revenues compared to 31% in
2002, and gas sales represented 74% of sales in 2003 compared to 67% in 2002.
The changes were considered minimal representing only a slight difference in
percentage points.
We had a net loss of $1,470,004 for 2003 compared to a net loss of
$1,946,959 in 2002. Total costs and expenses increased 35% in 2003 primarily due
to the 132% increase in cost of oil and gas, attributed to higher oil and gas
prices and increased pipeline costs. As a percentage of revenues, total costs
and expenses decreased from 257% in 2002 to 153% in 2003, attributed to the
significant increase in revenues from pipeline transmissions. Salaries and wages
remained constant in 2003. Selling, general and administrative expenses
decreased 35% in 2003 when compared to 2002, primarily due to a lower legal fees
and settlement of prior legal issues. Depreciation, depletion and amortization
increased 5% in 2003 due to increased oil production.
Interest expense in 2003 decreased 17% in 2003 due to lower interest rates,
paying off certain debt with proceeds form the sale of assets, and settlement of
the Baker Hughes judgment. We also realized a gain on disposition of assets of
$231,702 in 2003, compared to $82,522 in 2002, which was offset by a loss on
sale and valuation of assets in 2003 of $266,496. We also recognized a charge of
$116,486 in 2003 due to a change in accounting principal.
Our net loss for 2003 was $1,470,004 versus a net loss of $1,946,959 for
2002. The decrease in net loss in 2003 is primarily attributed to increased
revenues and recognized gains on disposition of assets and debt.
Net Operating Losses
We have accumulated approximately $19.7 million of net operating loss
carryforwards as of December 31, 2003, which may be offset against future
taxable income through 2023. The use of these losses to reduce future income
taxes will depend on the generation of sufficient taxable income prior to the
expiration of the net operating loss carryforwards. In the event of certain
changes in control, there will be an annual limitation on the amount of net
operating loss carryforwards which can be used. No tax benefit has been reported
in the financial statements for the year ended December 31, 2003 because the
potential tax benefits of the loss carryforward is offset by valuation allowance
of the same amount.
-18-
Liquidity and Capital Resources
Historically, working capital needs have been satisfied through our
operating revenues and from borrowed funds. Working capital at December 31, 2003
was a negative $5,317,857 compared with a negative $6,332,583 at December 31,
2002. This improvement in working capital was primarily attributed to the
increase in accounts receivable and settlement and payment of the Baker Hughes
judgment. We anticipate meeting working capital needs during the 2004 fiscal
year with revenues from operations and possibly from capital raised through the
sale of either equity or debt securities. We have no other current agreements or
arrangements for additional funding and there can be no assurance such funding
will be available to us, or if available, such funding will be on acceptable or
favorable terms to us.
As of December 31, 2003, we had total assets of $1,405,051 and
stockholders' deficit of $5,317,857 compared to total assets of $2,747,636 and
total stockholders' deficit of $3,938,719 at December 31, 2002.
In 1998, we issued $4,625,400 face value of 8% Secured Convertible
Debentures Due March 31, 1999. A portion of the proceeds were used to acquire
the GCRL properties and interest in Wyoming. During 2000, all but one of the
remaining outstanding debentures were converted into commons stock. At December
31, 2003, we owed $331,462 in connection with the debentures consisting of
$50,000 for a debenture and $281,462 in penalties and interest.
Because we have generated significant losses from operations through
December 31, 2003, and has a working capital deficit at December 31, 2003, there
exists substantial doubt about our ability to continue as a going concern.
Revenues have not been sufficient to cover operating costs and to allow us to
continue as a going concern. Potential proceeds from the future sale of common
stock, other contemplated debt and equity financing, and increases in operating
revenues from new development would enable us to continue as a going concern.
There can be no assurance that we can or will be able to complete any debt or
equity financing.
In the opinion of management, inflation has not had a material effect on
the operations of Trans Energy.
Forward-Looking and Cautionary Statements
This report includes "forward-looking statements" within the meaning of
Section 27A of the Securities Act of 1933, and Section 21E of the Securities
Exchange Act of 1934. These forward-looking statements may relate to such
matters as anticipated financial performance, future revenues or earnings,
business prospects, projected ventures, new products and services, anticipated
market performance and similar matters. When used in this report, the words
"may," "will," "expect," "anticipate," "continue," "estimate," "project,"
"intend," and similar expressions are intended to identify forward-looking
statements regarding events, conditions, and financial trends that may affect
our future plans of operations, business strategy, operating results, and
financial position. We caution readers that a variety of factors could cause our
actual results to differ materially from the anticipated results or other
matters expressed in forward-looking statements. These risks and uncertainties,
many of which are beyond our control, include:
* the sufficiency of existing capital resources and our ability to
raise additional capital to fund cash requirements for future
operations;
* uncertainties involved in the rate of growth of our business and
acceptance of any products or services;
* volatility of the stock market, particularly within the technology
sector; and
* general economic conditions.
-19-
Although we believe the expectations reflected in these forward-looking
statements are reasonable, such expectations cannot guarantee future results,
levels of activity, performance or achievements.
Recent Accounting Pronouncements
In August 2001,the Financial Accounting Standards Board, or FASB, issued
Statement of Financial Accounting Standards (SFAS) SFAS No. 143, Accounting for
Asset Retirement Obligations, which established a uniform methodology for
accounting for estimated reclamation and abandonment costs. The statement was
effective for fiscal years beginning after June 15, 2002. We recorded an
environmental remediation accrual of $200,000. A change in accounting principal
of $116,486 was recognized in the year ended December 31, 2003.
On April 30, 2002, the FASB issued FASB Statement No. 145 (SFAS 145),
"Rescission of FASB Statements No. 4, 44, and 64, Amendment of FASB Statement
No. 13, and Technical Corrections." SFAS 145 rescinds both FASB Statement No. 4
(SFAS 4), "Reporting Gains and Losses from Extinguishment of Debt," and the
amendment to SFAS 4, FASB Statement No. 64 (SFAS 64), "Extinguishments of Debt
Made to Satisfy Sinking-Fund Requirements." Through this rescission, SFAS 145
eliminates the requirement (in both SFAS 4 and SFAS 64) that gains and losses
from the extinguishment of debt be aggregated and, if material, classified as an
extraordinary item, net of the related income tax effect. However, an entity is
not prohibited from classifying such gains and losses as extraordinary items, so
long as it meets the criteria in paragraph 20 of Accounting Principles Board
Opinion No. 30, Reporting the Results of Operations Reporting the Effects of
Disposal of a Segment of a Business, and Extraordinary, Unusual and Infrequently
Occurring Events and Transactions. Further, SFAS 145 amends paragraph 14(a) of
FASB Statement No. 13, "Accounting for Leases," to eliminate an inconsistency
between the accounting for sale-leaseback transactions and certain lease
modifications that have economic effects that are similar to sale-leaseback
transactions. The amendment requires that a lease modification (1) results in
recognition of the gain or loss in the 9 financial statements, (2) is subject to
FASB Statement No. 66, "Accounting for Sales of Real Estate," if the leased
asset is real estate (including integral equipment), and (3) is subject (in its
entirety) to the sale-leaseback rules of FASB Statement No. 98, "Accounting for
Leases: Sale-Leaseback Transactions Involving Real Estate, Sales- Type Leases of
Real Estate, Definition of the Lease Term, and Initial Direct Costs of Direct
Financing Leases." Generally, FAS 145 is effective for transactions occurring
after May 15, 2002. The adoption of SFAS 145 did not have a material effect on
our financial statements.
In June 2002, the FASB issued SFAS No. 146, "Accounting for Exit or
Disposal Activities" (SFAS 146). SFAS 146 addresses significant issues regarding
the recognition, measurement, and reporting of costs that are associated with
exit and disposal activities, including restructuring activities that are
currently accounted for under EITF No. 94-3, "Liability Recognition for Certain
Employee Termination Benefits and Other Costs to Exit an Activity (including
Certain Costs Incurred in a Restructuring)." The scope of SFAS 146 also includes
costs related to terminating a contract that is not a capital lease and
termination benefits that employees who are involuntarily terminated receive
under the terms of a one- time benefit arrangement that is not an ongoing
benefit arrangement or an individual deferred- compensation contract. SFAS 146
will be effective for exit or disposal activities that are initiated after
December 31, 2002 and early application is encouraged. The provisions of EITF
No. 94-3 shall continue to apply for an exit activity initiated under an exit
plan that met the criteria of EITF No. 94-3 prior to the adoption of SFAS 146.
The effect on adoption of SFAS 146 will change on a prospective basis the timing
of when the restructuring charges are recorded from a commitment date approach
to when the liability is incurred. The adoption of SFAS 146 did not have a
material effect on our financial statements.
-20-
In October 2002, the FASB issued SFAS No. 147, "Acquisitions of Certain
Financial Institutions" which is effective for acquisitions on or after October
1, 2002. This statement provides interpretive guidance on the application of the
purchase method to acquisitions of financial institutions. Except for
transactions between two or more mutual enterprises, this Statement removes
acquisitions of financial institutions from the scope of both SFAS 72 and
Interpretation 9 and requires that those transactions be accounted for in
accordance with SFAS No. 141, "Business Combinations" and No. 142, "Goodwill and
Other Intangible Assets." The adoption of SFAS No. 147 did not have a material
effect on our financial statements.
In December 2002, the FASB issued SFAS No. 148, "Accounting for Stock Based
Compensation- Transition and Disclosure-an amendment of FASB Statement No. 123"
which is effective for financial statements issued for fiscal years ending after
December 15, 2002. This Statement amends SFAS 123, "Accounting for Stock-Based
Compensation," to provide alternative methods of transition for a voluntary
change to the fair value based method of accounting for stock-based employee
compensation. In addition, this Statement amends the disclosure requirements of
SFAS 123 to require prominent disclosures in both annual and interim financial
statements about the method of accounting for stock- based compensation and the
effect of the method used on reported results. The adoption of SFAS No. 148 did
not have a material effect on our financial statements.
In April 2003, the FASB issued SFAS No. 149, "Amendment of Statement 133 on
Derivative Instruments and Hedging Activities" which is effective for contracts
entered into or modified after June 30, 2003 and for hedging relationships
designated after June 30, 2003. This statement amends and clarifies financial
accounting for derivative instruments embedded in other contracts (collectively
referred to as derivatives) and hedging activities under SFAS 133. The adoption
of SFAS No. 149 did not have a material effect on our financial statements.
In May 2003, the FASB issued SFAS No. 150, "Accounting for Certain
Financial Instruments with Characteristics of both Liabilities and Equity" which
is effective for financial instruments entered into or modified after May 31,
2003, and is otherwise effective at the beginning of the first interim period
beginning after June 15, 2003. This Statement establishes standards for how an
issuer classifies and measures in its statement of financial position certain
financial instruments with characteristics of both liabilities and equity. It
requires that an issuer classify a financial instrument that is within its scope
as a liability (or an asset in some circumstances) because that financial
instrument embodies an obligation of the issuer. The adoption of SFAS No. 150
did not have a material effect on our financial statements.
FASB Interpretation No. 45, "Guarantor's Accounting and Disclosure
Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of
Others - an Interpretation of FASB Statements No. 5, 57 and 107". The initial
recognition and initial measurement provisions of this Interpretation are to be
applied prospectively to guarantees issued or modified after December 31, 2002.
The disclosure requirements in the Interpretation were effective for financial
statements of interim or annual periods ending after December 15, 2002. The
adoption of FASB Interpretation No. 45 did not have a material effect on our
financial statements.
In January 2003, the FASB issued FASB Interpretation No. 46 "Consolidation
of Variable Interest Entities." FIN 46 provides guidance on the identification
of entities for which control is achieved through means other than through
voting rights, variable interest entities, and how to determine when and which
business enterprises should consolidate variable interest entities. This
interpretation applies immediately to variable interest entities created after
January 31, 2003. It applies in the first fiscal year or interim period
beginning after June 15, 2003, to variable interest entities in which an
enterprise holds a variable interest that it acquired before February 1, 2003.
The adoption of FIN 46 did not have a material impact on our financial
statements.
-21-
During the year ended December 31, 2003, we adopted the following Emerging
Issues Task Force Consensuses: EITF Issue No. 00-21 "Revenue Arrangements with
Multiple Deliverables," EITF Issue No. 01 -8 "Determining Whether an Arrangement
Contains a Lease," EITF Issue No. 02-3 "Issues Related to Accounting for
Contracts Involved in Energy Trading and Risk Management Activities," EITF Issue
No. 02-9 "Accounting by a Reseller for Certain Consideration Received from a
Vendor," EITF Issue No. 02-17, "Recognition of Customer Relationship Intangible
Assets Acquired in a Business Combination," EITF Issue No. 02-18 "Accounting for
Subsequent Investments in an Investee after Suspension of Equity Method Loss
Recognition," EITF Issue No. 03-1, "The Meaning of Other Than Temporary and its
Application to Certain Instruments," EITF Issue No. 03-5, "Applicability of
AICPA Statement of Position 9702, 'Software Revenue Recognition' to Non-Software
Deliverables in an Arrangement Containing More Than Incidental Software," EITF
Issue No. 03-7, "Accounting for the Settlement of the Equity Settled Portion of
a Convertible Debt Instrument That Permits or Requires the Conversion Spread to
be Settled in Stock," EITF Issue No. 03-10, "Application of EITF Issue No. 02-16
by Resellers to Sales Incentives Offered to Consumers by Manufacturers."
Item 7. Financial Statements
Our financial statements as of and for the fiscal years ended December 31,
2003 and 2002 have been examined to the extent indicated in their report by H J
& Associates, LLC, independent certified public accountants, and have been
prepared in accordance with generally accepted accounting principles and
pursuant to Regulation S-B as promulgated by the SEC. The aforementioned
financial statements are included herein starting with page F-1.
Item 8. Changes in and Disagreements with Accountants on Accounting and
Financial Disclosure
This Item is not Applicable.
Item 8A. Controls and Procedures
As of the end of the period covered by this report, we carried out an
evaluation, under the supervision and with the participation of management,
including our chief executive officer and chief financial officer, of the
effectiveness of the design and operation of our disclosure controls and
procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities
Exchange Act of 1934. Based upon that evaluation, our chief executive officer
and chief financial officer concluded that our disclosure controls and
procedures are effective to cause the material information required to be
disclosed by us in the reports that we file or submit under the Exchange Act to
be recorded, processed, summarized and reported within the time periods
specified in the SEC's rules and forms. There have been no significant internal
controls or in other factors which could significantly affect internal controls
subsequent to the date we carried out our evaluation.
PART III
Item 9. Directors, Executive Officers, Promoters and Control Persons;
Compliance with Section 16(a) of the Exchange Act
The following table sets forth the names, ages, and offices held by our
directors and executive officers:
Name Position Director Since Age
---- -------- -------------- ---
Robert L. Richards President, C.E.O. September 2001 58
and Director
Loren E. Bagley Vice President August 1991 61
and Director
William F. Woodburn Secretary / Treasurer August 1991 62
and Director
John B. Sims Director January 1988 78
-22-
All directors hold office until the next annual meeting of stockholders and
until their successors have been duly elected and qualified. There are no
agreements with respect to the election of directors. We have not compensated
our directors for service on the Board of Directors or any committee thereof,
but directors are reimbursed for expenses incurred for attendance at meetings of
the Board and any committee thereof. Executive officers are appointed annually
by the Board and each executive officer serves at the discretion of the Board.
The Executive Committee of the Board of Directors, to the extent permitted under
Nevada law, exercises all of the power and authority of the Board in the
management of the business and affairs of Trans Energy between meetings of the
Board.
The business experience of each of the persons listed above during the past
five years is as follows:
Robert L. Richards became a director and was appointed President and C.E.O.
in September 2001. From 1982 to the present, he has been President of Robert L.
Richards, Inc. as a consulting geologist with 27 years experience in the
petroleum industry. He has also served as a geologist with Exxon, exploration
geologist with Union Texas Petroleum, and regional exploration manager for
Carbonit Exploration, Inc. From 2000 to the present, he has been President and
C.E.O. of Derma - Rx, Inc., a formulator and marketer of skin care products.
Also, from 1992 to August 2000, Mr. Richards was C.E.O. of Kaire Nutraceuticals,
Inc., a developer and marketer of health and nutritional products. Mr. Richards
served as Vice President of Continental Tax Corporation from March 1989 to
August 1992. He has five and one- half years experience in the United States Air
Force as an Instructor Pilot. Mr. Richards holds a B.S. degree in geology from
Brigham Young University.
Loren E. Bagley served as our President and C.E.O. from September 1993 to
September 2001, at which time he resigned as President and was appointed Vice
President. From 1979 to the present, Mr. Bagley has been self -employed in the
oil and gas industry as president, C.E.O. or vice president of various
corporations which he has either started or purchased, including Ritchie County
Gathering Systems, Inc. Mr. Bagley's experience in the oil and gas industry
includes acting as a lease agent, funding and drilling of oil and gas wells,
supervising production of over 175 existing wells, contract negotiations for
purchasing and marketing of natural gas contracts, and owning a well logging
company specializing in analysis of wells. Prior to becoming involved in the oil
and gas industry, Mr. Bagley was employed by the United States government with
the Agriculture Department. Mr. Bagley attended Ohio University and Salem
College and earned a B.S. Degree.
William F. Woodburn has served as our Vice President from August 1991 to
September 2001, at which time he resigned as Vice President and was appointed
Secretary / Treasurer. Mr. Woodburn has been actively engaged in the oil and gas
business in various capacities for the past twenty years. For several years
prior to 1991, Mr. Woodburn supervised the production of oil and natural gas and
managed the pipeline operations of Tyler Construction Company, Inc. and Tyler
Pipeline, Inc. Mr. Woodburn is a stockholder and serves as President of Tyler
Construction Company, Inc., and is also a stockholder of Tyler Pipeline, Inc.
which owns and operates oil and gas wells in addition to natural gas pipelines,
and Ohio Valley Welding, Inc. which owns a fleet of heavy equipment that
services the oil and gas industry. Prior to his involvement in the oil and gas
industry, Mr. Woodburn was employed by the United States Army Corps of Engineers
for twenty four years and was Resident Engineer on several construction
projects. Mr. Woodburn graduated from West Virginia University with a B.S. in
civil engineering.
-23-
John B. Sims served as our President, C.E.O. and a director from 1988 to
September, 1993 and currently is a director. Prior to joining Trans Energy and
from 1984 to 1988, Mr. Sims was the General Partner of Ben's Run Oil Company
which was acquired by the Company in January, 1988. Mr. Sims has also been the
general partner for fourteen limited partnerships from 1977 to 1984 drilling a
total of twenty eight wells. Prior to his involvement in the oil and gas
business, Mr. Sims was a real estate developer for twenty years as well as an
exclusive real estate broker for Ednam Forrest in Charlottesville, Virginia.
During 1994, Mr. Sims voluntarily initiated a personal bankruptcy proceeding
pursuant to Chapter 7 of the United States Bankruptcy Code. Pursuant to the
terms of such proceeding, Mr. Sims was discharged of certain of his debts which
were incurred as a consequence of his personal guarantees of certain business
related debts, not related to Trans Energy, upon which the primary obligor
defaulted.
Item 10. Executive Compensation
We do not have a bonus, profit sharing, or deferred compensation plan for
the benefit of employees, officers or directors, nor have we entered into
employment contracts with any of the aforementioned persons.
Cash Compensation
For the past three fiscal years ended December 31, 2003, we have not paid
any cash compensation for services rendered by our executive officers.
Item 11. Security Ownership of Certain Beneficial Owners and Management
The following table sets forth information, to the best of our knowledge as
December 31, 2003, with respect to each person known by us to own beneficially
more than 5% of our outstanding common stock, each director and all directors
and officers as a group.
Name and Address Amount and Nature of Percent
of Beneficial Owner Beneficial Ownership of Class(1)
------------------- -------------------- -----------
Robert L. Richards 1,691,287(2) 0.6%
210 Second Street
St. Marys, WV 26170
Loren E. Bagley * 2,074,527(3) 0.7%
210 Second Street
St. Marys, WV 26170
William F. Woodburn * 2,067,394(4) 0.8%
210 Second Street
St. Marys, WV 26170
John B. Sims * 302,614(5) 0.1%
210 Second Street
St. Marys, WV 26170
All directors and executive 6,135,822(6) 2.3%
officers as a group
(4 persons in group)
* Director and/or executive officer
Note: Unless otherwise indicated in the footnotes below, we have been advised
that each person above has sole voting power over the shares indicated
above.
-24-
(1) Based upon 269,010,438 shares of common stock outstanding on December
31, 2003,but does not take into consideration stock options owned by
certain officers and directors entitling the holders to purchase an
aggregate of 650,000 shares of common stock and which are currently
exercisable. Therefore, for purposes of the table above, 238,169,127 shares
of common stock are deemed to be issued and outstanding in accordance with
Rule 13d-3 adopted by the SEC under the Securities Exchange Act of 1934, as
amended. Percentage ownership is calculated separately for each person on
the basis of the actual number of outstanding shares as of December 31,
2003 and assumes the exercise of stock options held by such person (but not
by anyone else) exercisable within sixty days.
(2) Includes 1,012,670 shares held in the name of Argene Richards, wife of
Mr. Richards.
(3) Includes 312,500 shares that may be acquired by Mr. Bagley pursuant to
stock options exercisable at $.50 per share and 50,000 shares of common
stock held in the name of Carolyn S. Bagley, wife of Mr. Bagley, over which
Ms. Bagley retains voting power.
(4) Includes 312,500 shares that may be acquired by Mr. Woodburn pursuant
to stock options exercisable at $.50 per share and 31,250 shares of common
stock in the name of Janet L. Woodburn, wife of Mr. Woodburn, over which
shares Ms. Woodburn retains voting power. (5) Includes 25,000 shares that
may be acquired by Mr. Sims pursuant to stock options exercisable at $.50
per share and 13,807 shares of common stock held jointly with Virginia
Sims, wife of Mr. Sims. (6) Includes 650,000 shares that may be acquired by
certain directors pursuant to stock options exercisable at $.50 per share.
Item 12. Certain Relationships and Related Transactions
During the past two fiscal years, there have been no transactions between
us and any officer, director, nominee for election as director, or any
shareholder owning greater than five percent (5%) of our outstanding shares, nor
any member of the above referenced individuals' immediate family, except as set
forth below.
(a) Loren E. Bagley is President of Sancho, a principal purchaser of our
natural gas. Mr. Bagley's wife, Carolyn S. Bagley is a director and owner of 33%
of the outstanding capital stock of Sancho. Under our contract with Sancho, we
have the right to sell natural gas subject to the terms and conditions of a
20-year contract, as amended, that Sancho entered into with Hope Gas in 1988.
This agreement is a flexible volume supply agreement whereby we receive the full
price which Sancho receives less a $.05 per Mcf marketing fee paid to Sancho.
The price of the natural gas is based upon the greater of the residential gas
commodity index or the published Inside F.E.R.C. Index, at our option, for the
first 1,500 Mcf purchased per day by Hope Gas and thereafter the price is the
Inside F.E.R.C. Index. The residential gas commodity index does not directly
fluctuate with the overall price of natural gas. The Inside F.E.R.C. Index
fluctuates monthly with the change in the price of natural gas. While such
option provides certain price protection for us there can be no assurance that
prices paid by us to suppliers will be lower than the price which we would
receive under the Hope Gas arrangement. During 2003, we paid Sancho an aggregate
of approximately $11,000 pursuant to such contract.
(b) On May 7, 1996, we borrowed $100,000 from William Stevenson. Such
amount is repayable in one installment of principal and interest of $110,000 on
November 7, 1996. Messrs. Bagley, William F. Woodburn and John B. Sims are
jointly and severally liable with us for the repayment of such obligation. Such
obligation is secured by the pledge of 50,000 shares of common stock owned by
Mr. Woodburn's wife, Janet L. Woodburn. The loan remains outstanding.
-25-
We occupy approximately 4,000 square feet of office space in St. Marys,
West Virginia, which we share with Tyler Construction and Ritchie County
Gathering Systems. Prior to 1997, the office space was paid for by Sancho and we
used the office space rent free. We believe that the foregoing transactions with
Sancho were made on terms no less favorable to us than those available from
unaffiliated third parties.
It is our policy that any future material transactions between us and
members of management or their affiliates shall be on terms no less favorable
than those available from unaffiliated third parties.
Item 13. Exhibits and Reports on Form 8-K
(a) Exhibits
Exhibit No. Exhibit Name
----------- ------------
2.1(1) Stock Acquisition Agreement between Trans Energy and Loren E.
Bagley and William F. Woodburn
2.2(1) Asset Acquisition Agreement between Trans Energy and Dennis L.
Spencer
2.3(1) Asset Acquisition Agreement between Trans Energy and Tyler
Pipeline, Inc.
2.4(1) Stock Exchange Agreement between Trans Energy and Ritchie County
Gathering Systems, Inc.
2.5(1) Plan and Agreement of Merger between Trans Energy, Inc. (Nevada)
and Apple Corp. (Idaho), to facilitate the change of our corporate
domicile to Nevada
2.6(2) Agreements related to acquisition of Vulcan Energy Corporation
3.1(1) Articles of Incorporation and all amendments pertaining thereto,
for Apple Corp., an Idaho corporation
3.2(1) Articles of Incorporation for Trans Energy, Inc., a Nevada
corporation
3.3(1) Articles of Merger for the States of Nevada and Idaho 3.4(1)
By-Laws
4.1(1) Specimen Stock Certificate
10.1(1) Marketing Agreement with Sancho Oil and Gas Corporation 10.2(1)
Gas Purchase Agreement with Central Trading Company 10.3(1) Price
Agreement with Key Oil Company
10.4(3) Settlement Agreement and Mutual Release
21.1(1) Subsidiaries Schedule
31.1 Certification of C.E.O. Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002
31.2 Certification of Principal Accounting Officer Pursuant to Section
302 of the Sarbanes-Oxley Act of 2002 32.1 Certification of C.E.O.
Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section
906 of the Sarbanes-Oxley Act of 2002 32.2 Certification of
Principal Accounting Officer Pursuant to 18 U.S.C. Section 1350,
as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of
2002
-26-
99.1(1) Reserve Estimate and Evaluation of oil and gas properties 99.2(1)
Reserve Estimate and Evaluation for Dennis L. Spencer wells
(1) Previously filed as exhibit to Form 10-SB.
(2) Previously filed as exhibit to Form 8-K dated August 7, 1995.
(3) Previously filed as exhibit to Form 8-K file January 23, 2004
(b) Reports on Form 8-K
We filed a Current Report on Form 8-K on January 15, 2004 and an
amended report on January 23, 2004 reporting under Items 2 and 5 the
sale of certain working interests in five oil and gas wells and the
use of a portion of the proceeds to settle an ongoing lawsuit.
Item 14. Principal Accountants Fees and Services
We do not have an audit committee and as a result our entire board of
directors performs the duties of an audit committee. Our board of directors will
approve in advance the scope and cost of the engagement of an auditor before the
auditor renders audit and non-audit services. As a result, we do not rely on
pre-approval policies and procedures.
Audit Fees
The aggregate fees billed by our independent auditors, H J & Associates,
for professional services rendered for the audit of our annual financial
statements included in our Annual Reports on Form 10-KSB for the years ended
December 31, 2003 and 2002, and for the review of quarterly financial statements
included in our Quarterly Reports on Form 10-QSB for the quarters ending April
30, June 30 and September 30, 2003 and 2002, were $30,250 for 2003 and $33,500
for 2002.
Audit Related Fees
For the years ended December 31, 2003 and 2002, there were no fees billed
for assurance and related services by H J & Associates relating to the
performance of the audit of our financial statements which are not reported
under the caption "Audit Fees" above.
Tax Fees
For the years ended December 31, 2003 and 2002, fees billed by H J &
Associates for tax compliance, tax advice and tax planning were $1,250 and
$1,000, respectively.
We do not use H J & Associates for financial information system design and
implementation. These services, which include designing or implementing a system
that aggregates source data underlying the financial statements or generates
information that is significant to our financial statements, are provided
internally or by other service providers. We do not engage H J & Associates to
provide compliance outsourcing services.
The board of directors has considered the nature and amount of fees billed
by H J & Associates and believes that the provision of services for activities
unrelated to the audit is compatible with maintaining H J & Associates'
independence.
-27-
SIGNATURES
In accordance with Section 13 or 15(d) of the Exchange Act, the Registrant
caused this report to be signed on its behalf by the undersigned, thereunto duly
authorized.
TRANS ENERGY, INC.
BY: /S/ ROBERT L. RICHARDS
----------------------------
Robert L. Richards,
President and C.E.O.
Dated: April 2, 2004
In accordance with the Exchange Act, this report has been signed below by
the following persons on behalf of the Registrant and in the capacities and on
the dates indicated.
Signature Title Date
--------- ----- ----
President, C.E.O. and April 2, 2004
/S/ ROBERT L. RICHARDS Director
------------------------------------
Robert L. Richards
Vice President and April 2, 2004
/S/ LOREN E. BAGLEY Director
------------------------------------ Principal Financial Officer
Loren E. Bagley
Secretary Treasurer / Treasurer April 2, 2004
/S/ WILLIAM F. WOODBURN and Director
------------------------------------ Chief Accounting Officer
William F. Woodburn
April 2, 2004
/S/ JOHN B. SIMS Director
------------------------------------
John B. Sims
-29-
TRANS ENERGY, INC.
AND SUBSIDIARIES
CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2003
F-1
C O N T E N T S
Independent Auditors' Report .............................................. F-3
Consolidated Balance Sheet ................................................ F-4
Consolidated Statements of Operations ..................................... F-6
Consolidated Statements of Stockholders' Equity (Deficit).................. F-7
Consolidated Statements of Cash Flows ..................................... F-8
Notes to the Consolidated Financial Statements ............................ F-10
F-2
INDEPENDENT AUDITORS' REPORT
Board of Directors
Trans Energy, Inc. and Subsidiaries
St. Marys, West Virginia
We have audited the accompanying consolidated balance sheet of Trans Energy,
Inc. and Subsidiaries as of December 31, 2003 and the related consolidated
statements of operations, stockholders' equity (deficit), and cash flows for the
years ended December 31, 2003 and 2002. These consolidated financial statements
are the responsibility of the Company's management. Our responsibility is to
express an opinion on these consolidated financial statements based on our
audits.
We conducted our audits in accordance with auditing standards generally accepted
in the United States of America. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the consolidated
financial statements are free of material misstatement. An audit includes
examining, on a test basis, evidence supporting the amounts and disclosures in
the consolidated financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by management, as well
as evaluating the overall consolidated financial statement presentation. We
believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present
fairly, in all material respects, the consolidated financial position of Trans
Energy, Inc. and Subsidiaries as of December 31, 2003 and the consolidated
results of their operations and their cash flows for the years ended December
31, 2003 and 2002, in conformity with accounting principles generally accepted
in the United States of America.
The accompanying consolidated financial statements have been prepared assuming
that the Company will continue as a going concern. As discussed in Note 8 to the
consolidated financial statements, the Company has generated significant losses
from operations, has an accumulated deficit of $28,692,026 and has a working
capital deficit of $6,246,995 at December 31, 2003, which together raises
substantial doubt about its ability to continue as a going concern. Management's
plans in regards to these matters are also described in Note 8. The consolidated
financial statements do not include any adjustments that might result from the
outcome of this uncertainty.
/s/ HJ & Associates, LLC
------------------------
HJ & Associates, LLC
Salt Lake City, Utah
March 17, 2004
F-3
TRANS ENERGY, INC. AND SUBSIDIARIES
Consolidated Balance Sheet
ASSETS
December 31,
2003
-------------
CURRENT ASSETS
Cash $ 183
Accounts receivable, net (Note 1) 310,867
Other receivables 58,452
Prepaid expenses 990
-----------
Total Current Assets 370,492
-----------
PROPERTY AND EQUIPMENT (Note 2)
Vehicles 77,118
Machinery and equipment 10,092
Pipelines 1,739,287
Well equipment 49,155
Wells 3,079,481
Leasehold acreage 95,945
Accumulated depreciation (4,021,605)
-----------
Total Fixed Assets 1,029,473
-----------
OTHER ASSETS
Cash surrender value - life insurance (net) 5,086
-----------
Total Other Assets 5,086
-----------
TOTAL ASSETS $ 1,405,051
===========
The accompanying notes are an integral part
of these onsolidated financial statements.
F-4
TRANS ENERGY, INC. AND SUBSIDIARIES
Consolidated Balance Sheet (Continued)
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
December 31,
2003
CURRENT LIABILITIES -----------
Bank overdraft $ 49,120
Accounts payable - trade 786,191
Notes payable - convertible (Note 12) 36,325
Accrued expenses 954,749
Salaries payable 1,266,479
Notes payable - current portion (Note 3) 1,221,083
Judgments payable (Note 7) 500,397
Related party payables (Note 4) 1,271,681
Debentures payable (Note 9) 331,462
Environmental remediation (Note 1) 200,000
------------
Total Current Liabilities 6,617,487
------------
LONG-TERM LIABILITIES
Notes payable (Note 3) 105,421
------------
Total Long-Term Liabilities 105,421
------------
Total Liabilities 6,722,908
------------
COMMITMENTS AND CONTINGENCIES (Note 7)
STOCKHOLDERS' EQUITY (DEFICIT) (Note 6)
Preferred stock; 10,000,000 shares authorized
at $0.001 par value; -0- shares issued and outstanding --
Common stock; 500,000,000 shares authorized
at $0.001 par value; 269,010,438 shares issued
and outstanding 269,010
Capital in excess of par value 23,105,159
Accumulated deficit (28,692,026)
------------
Total Stockholders' Equity (Deficit) (5,317,857)
------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) $ 1,405,051
============
The accompanying notes are an integral part
of these consolidated financial statements.
F-5
TRANS ENERGY, INC. AND SUBSIDIARIES
Consolidated Statements of Operations
For the Years Ended
December 31,
2003 2002
--------------- -------------
REVENUES $ 2,015,012 $ 889,764
--------------- -------------
COSTS AND EXPENSES
Cost of oil and gas 1,536,434 662,958
Salaries and wages 381,743 382,117
Depreciation, depletion and amortization 961,181 919,364
Selling, general and administrative -- --
210,926 324,874
------------- -------------
Total Costs and Expenses 3,090,284 2,289,313
------------- -------------
LOSS FROM OPERATIONS (1,075,272) (1,399,549)
------------- -------------
OTHER INCOME (EXPENSE)
Other income -- 22,537
Gain on disposition of debt 231,702 82,522
Interest expense (404,336) (488,877)
Loss on sale and valuation of assets, net (Note 1 and 2) (266,496) (105,753)
Loss on extinguishments of debt (11,268) --
Gain on disposition of assets 172,152 2,650
Settlement expense -- (60,489)
------------- -------------
Total Other Income (Expense) (278,246) (547,410)
------------- -------------
LOSS BEFORE INCOME TAXES,
AND CHANGE IN ACCOUNTING PRINCIPAL (1,353,518) (1,946,959)
INCOME TAXES (Note 1) -- --
------------- -------------
CHANGE IN ACCOUNTING PRINCIPAL (Note 1) (116,486) --
------------- -------------
NET LOSS - attributed to common shareholders $ (1,470,004) $ (1,946,959)
============= =============
BASIC LOSS PER SHARE (Note 1)
Operations $ (0.01) $ (0.01)
Change in accounting principal (0.00) (0.00)
------------- -------------
Total Basic Loss Per Share $ (0.01) $ (0.01)
============= =============
WEIGHTED AVERAGE NUMBER OF COMMON SHARES
OUTSTANDING 253,125,570 207,824,349
============= =============
The accompanying notes are an integral part
of these consolidated financial statements.
F-6
TRANS ENERGY, INC. AND SUBSIDIARIES
Consolidated Statements of Stockholders' Equity (Deficit)
Preferred Stock Common Stock Capital in
----------------------------- --------------------------- Excess of Accumulated
Shares Amount Shares Amount Par Value Deficit
------------ ------------- ------------ ------------ ------------ ------------
Balance, December 31, 2001 300 $ -- 176,683,189 $ 176,682 $ 22,769,371 $(25,275,063)
Conversion of preferred stock and
preferred dividends to common
stock (300) -- 16,835,938 16,836 6,414 --
Conversion of notes payable to
common stock -- -- 5,000,000 5,000 45,000 --
Common stock issued for services -- -- 1,000,000 1,000 28,000 --
Conversion of notes payable to
common stock -- -- 4,166,667 4,167 20,833 --
Common stock issued for cash -- -- 33,333,333 33,333 166,667 --
Common stock issued for services -- -- 500,000 500 9,500 --
Net loss for the year ended
December 31, 2002 -- -- -- -- -- (1,946,959)
------------ ------------- ------------ ------------ ------------ ------------
Balance, December 31, 2002 -- -- 237,519,127 237,518 23,045,785 (27,222,022)
Common stock issued for
services -- -- 3,500,000 3,500 7,000 --
Common stock issued for
conversion of convertible
debt -- -- 150,000 150 5,100 --
Common stock issued for
extinguishments of
related party debt -- -- 22,833,163 22,834 7,209 --
Common stock issued for
extinguishments of debt -- -- 5,008,148 5,008 40,065 --
Net loss for the year ended
December 31, 2003 -- -- -- -- -- (1,470,004)
------------ ------------- ------------ ------------ ------------ ------------
Balance, December 31, 2003 -- $ -- 269,010,438 $ 269,010 $ 23,105,159 $(28,692,026)
============ ============= ============ ============ ============ ============
The accompanying notes are an integral part
of these consolidated financial statements.
F-7
TRANS ENERGY, INC. AND SUBSIDIARIES
Consolidated Statements of Cash Flows
For the Years Ended
December 31,
2003 2002
----------- -----------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss $(1,470,004) $(1,946,959)
Adjustments to reconcile net loss to net cash used by operating activities:
Depreciation, depletion and amortization 961,181 919,364
Loss on sale and valuation of assets 266,496 103,103
Loss on extinguishments of debt 11,268 --
Gain on disposition of assets (172,152) (2,650)
Common stock issued for services and
beneficial conversion features 10,500 39,000
Gain on disposition of debt (231,702) (82,522)
Settlement expense -- 54,489
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivable (172,246) 45,612
(Increase) decrease in prepaid and other current assets (62,078) 6,341
Increase in accounts payable and accrued expenses 682,320 656,705
Decrease in judgments payable (385,697) (61,625)
Increase in environmental remediation 200,000 --
----------- -----------
Net Cash Used by Operating Activities (362,114) (269,142)
=========== ===========
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of property and equipment 670,000 2,650
Expenditures for property and equipment (152,848) (10,249)
----------- -----------
Net Cash Provided (Used) by Investing Activities 517,152 (7,599)
=========== ===========
CASH FLOWS FROM FINANCING ACTIVITIES:
Change in cash overdraft 49,120 --
Common stock issued for cash -- 200,000
Principal payments to related parties (249,161) (208,754)
Proceeds from related parties 233,650 337,896
Principal payments on notes payable (217,980) (76,968)
Proceeds from notes payable 17,289 35,303
----------- -----------
Net Cash Provided (Used) by Financing Activities $ (167,082) $ 287,477
=========== ===========
The accompanying notes are an integral part of these
consolidated financial statements.
F-8
TRANS ENERGY, INC. AND SUBSIDIARIES
Consolidated Statements of Cash Flows
(Continued)
For the Years Ended
December 31,
2003 2002
----------- -----------
NET INCREASE (DECREASE) IN CASH $ (12,044) $ 10,736
CASH, BEGINNING OF YEAR 12,227 1,491
--------- ---------
CASH, END OF YEAR $ 183 $ 12,227
========= =========
CASH PAID FOR:
Interest $ 295,947 $ 288,561
Income taxes $ -- $ --
NON-CASH FINANCING ACTIVITIES:
Common stock issued for services and beneficial conversion
features $ 10,500 $ 39,000
Common stock issued for conversion of debt and interest $ 80,366 $ 75,000
Common stock issued for conversion of preferred stock and
dividends -- $ 23,250
The accompanying notes are an integral part
of these consolidated financial statements.
F-9
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Organization
The Company was originally incorporated in the State of Idaho on
January 16, 1964. On January 11, 1988, the Company changed its name to
Apple Corporation. In 1988, the Company acquired oil and gas leases
and other assets from Ben's Run Oil Company (a Virginia limited
partnership) and has since engaged in the business of oil and gas
production.
On November 5, 1993, the Board of Directors caused to be incorporated
in the State of Nevada, a new corporation by the name of Trans Energy,
Inc., with the specific intent of effecting a merger between Trans
Energy, Inc. of Nevada and Apple Corp. of Idaho, for the sole purpose
of changing the domicile of the Company to the State of Nevada. On
November 15, 1993, Apple Corp. and the newly formed Trans Energy, Inc.
executed a merger agreement whereby the shareholders of Apple Corp.
exchanged all of their issued and outstanding shares of common stock
for an equal number of shares of Trans Energy, Inc. common stock.
Trans Energy, Inc. was the surviving corporation and Apple Corp. was
dissolved.
Accounting Method
The Company uses the successful efforts method of accounting for oil
and gas producing activities. Costs to acquire mineral interests in
oil and gas properties, to drill and equip exploratory wells that find
proved reserves, and to drill and equip development wells are
capitalized. Costs to drill exploratory wells that do not find proved
reserves, geological and geophysical costs, and costs of carrying and
retaining unproved properties are expensed.
Unproved oil and gas properties that are individually significant are
periodically assessed for impairment of value, and a loss is
recognized at the time of impairment by providing an impairment
allowance. Other unproved properties are amortized based on the
Company's experience of successful drilling and average holding
period. Capitalized costs of producing oil and gas properties, after
considering estimated dismantlement and abandonment costs and
estimated salvage values, are depreciated and depleted by the
unit-of-production method. Support equipment and other property and
equipment are depreciated over their estimated useful lives.
On the sale or retirement of a complete unit of a proved property, the
cost and related accumulated depreciation, depletion, and amortization
are eliminated from the property accounts, and the resultant gain or
loss is recognized. On the retirement or sale of a partial unit of
proved property, the cost is charged to accumulated depreciation,
depletion, and amortization with a resulting gain or loss recognized
in income.
On the sale of an entire interest in an unproved property for cash or
cash equivalent, gain or loss on the sale is recognized, taking into
consideration the amount of any recorded impairment if the property
had been assessed individually.
F-10
\
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
b. Accounting Method (Continued)
If a partial interest in an unproved property is sold, the amount
received is treated as a reduction of the cost of the interest
retained. During the year ended December 31, 2002, the Company
transferred 240 acres and one of its wells as settlement with
George Hillyer for an expense of $54,489. Also during 2002, the
Company recognized an impairment loss of $103,103 on one of its
natural gas wells in West Virginia that was shut down. During the
year ended December 31, 2003, the Company recognized an
impairment loss of $87,040 on one of its natural gas wells.
The Company has elected a December 31 year-end.
c. Basic Loss per Share of Common Stock
The basic loss per share of common stock is based on the weighted
average number of shares issued and outstanding at the date of
the consolidated financial statements. Fully diluted loss per
share of common stock is not disclosed as the common stock
equivalents are antidilutive in nature.
For the Years Ended December 31,
2003 2002
--------------------------------------------------------------------------------
Numerator:
Loss from operations $ (1,353,518) $ --
(1,946,959) --
Change in accounting principal (116,486) --
------------- ---------------
Net Loss $ (1,470,004) $ (1,946,959)
============= ===============
Denominator - weighted average shares 253,125,570 207,824,349
============= ===============
Net loss per share:
Change in accounting principal $ (0.00) $ (0.00)
Loss from operations (0.01) (0.01)
------------- ---------------
Total Basic Loss Per Share $ (0.01) $ (0.01)
============= ===============
d. Provision for Taxes
Deferred taxes are provided on a liability method whereby
deferred tax assets are recognized for deductible temporary
differences and operating loss and tax credit carryforwards and
deferred tax assets are recognized for taxable temporary
differences. Temporary differences are the differences between
the reported amounts of assets and liabilities and their tax
bases. Deferred tax assets are reduced by a valuation allowance
when, in the opinion of management, it is more likely than not
that some portion or all of the deferred tax assets will not be
realized. Deferred tax assets and liabilities are adjusted for
the effects of changes in tax laws and rates on the date of
enactment.
F-11
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 -
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
d. Provision for Taxes (Continued)
Net deferred tax assets consist of the following components as of
December 31, 2003 and 2002:
2003 2002
----------- -----------
Deferred tax assets:
NOL Carryover$ $ 8,183,500 $ 7,682,610
Deferred tax liabilities: -- --
Accrued Wages (493,900) (378,116)
Valuation allowance (7,689,600) (7,304,494)
----------- -----------
Net deferred tax asset $ -- $ --
=========== ===========
The income tax provision differs from the amount of income tax
determined by applying the U.S. federal income tax rates of 39%
to pretax income from continuing operations for the years ended
December 31, 2003 and 2002 due to the following:
2003 2002
--------- ---------
Book income $(573,300) $(759,314)
Other (16,831) 94
Penalties 5,370 64,620
Officer Insurance 6,645 4,610
Stock for Services 4,095 15,200
Accrued Wages 115,810 127,478
Impairment Loss 33,945 --
Accrued Interest/Payroll 424,265 --
Valuation allowance -- 547,312
--------- ---------
$ -- $ --
========= =========
At December 31, 2003, the Company had net operating loss
carryforwards of approximately $19,700,000 that may be offset
against future taxable income from the year 2003 through 2023. No
tax benefit has been reported in the December 31, 2003
consolidated financial statements since the potential tax benefit
is offset by a valuation allowance of the same amount.
Due to the change in ownership provisions of the Tax Reform Act
of 1986, net operating loss carryforwards for Federal income tax
reporting purposes are subject to annual limitations. Should a
change in ownership occur, net operating loss carryforwards may
be limited as to use in future years.
F-12
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
e. Principles of Consolidation
The consolidated financial statements include the Company and its
wholly owned subsidiaries, Prima Oil Company, Inc., Ritchie
County Gathering Systems, Inc. and its 100% owned subsidiary,
Tyler Construction Company, Inc. All significant intercompany
accounts and transactions have been eliminated.
f. Presentation
Certain 2002 balances have been reclassified to conform to the
presentation of the 2003 consolidated financial statements.
g. Depreciation
Fixed assets are stated at cost. Depreciation on vehicles,
machinery and equipment is provided using the straight line
method over expected useful lives of five years. Depreciation on
pipelines and well equipment is provided using the straight-line
method over the expected useful lives of fifteen years. Wells are
being depreciated using the units-of-production method on the
basis of total estimated units of proved reserves.
h. 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 assumptions
that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ
from those estimates.
i. Long Lived Assets
The Company reviews long-lived assets and identifiable
intangibles whenever events or circumstances indicate that the
carrying amounts of such assets may not be fully recoverable. The
Company evaluates the recoverability of long-lived assets by
measuring the carrying amounts of the assets against the
estimated undiscounted cash flows associated with these assets.
At the time such evaluation indicates that the future
undiscounted cash flows of certain long-lived assets are not
sufficient to recover the assets' carrying value, the assets are
adjusted to their fair values (based upon discounted cash flows).
F-13
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
j. Newly Issued Accounting Pronouncements
During the year ended December 31, 2003, the Company adopted the
following accounting pronouncements:
SFAS No. 143 -- In August 2001, the FASB issued SFAS No. 143,
Accounting for Asset Retirement Obligations, which established a
uniform methodology for accounting for estimated reclamation and
abandonment costs. The statement was effective for fiscal years
beginning after June 15, 2002. The Company recorded an
environmental remediation accrual of $200,000. A change in
accounting principal of $116,486 was recognized in the year ended
December 31, 2003.
SFAS No. 145 -- On April 30, 2002, the FASB issued FASB Statement
No. 145 (SFAS 145), "Rescission of FASB Statements No. 4, 44, and
64, Amendment of FASB Statement No. 13, and Technical
Corrections." SFAS 145 rescinds both FASB Statement No. 4 (SFAS
4), "Reporting Gains and Losses from Extinguishment of Debt," and
the amendment to SFAS 4, FASB Statement No. 64 (SFAS 64),
"Extinguishments of Debt Made to Satisfy Sinking-Fund
Requirements." Through this rescission, SFAS 145 eliminates the
requirement (in both SFAS 4 and SFAS 64) that gains and losses
from the extinguishment of debt be aggregated and, if material,
classified as an extraordinary item, net of the related income
tax effect. However, an entity is not prohibited from classifying
such gains and losses as extraordinary items, so long as it meets
the criteria in paragraph 20 of Accounting Principles Board
Opinion No. 30, Reporting the Results of Operations Reporting the
Effects of Disposal of a Segment of a Business, and
Extraordinary, Unusual and Infrequently Occurring Events and
Transactions. Further, SFAS 145 amends paragraph 14(a) of FASB
Statement No. 13, "Accounting for Leases", to eliminate an
inconsistency between the accounting for sale-leaseback
transactions and certain lease modifications that have economic
effects that are similar to sale-leaseback transactions. The
amendment requires that a lease modification (1) results in
recognition of the gain or loss in the 9 financial statements,
(2) is subject to FASB Statement No. 66, "Accounting for Sales of
Real Estate," if the leased asset is real estate (including
integral equipment), and (3) is subject (in its entirety) to the
sale- leaseback rules of FASB Statement No. 98, "Accounting for
Leases: Sale- Leaseback Transactions Involving Real Estate,
Sales-Type Leases of Real Estate, Definition of the Lease Term,
and Initial Direct Costs of Direct Financing Leases." Generally,
FAS 145 is effective for transactions occurring after May 15,
2002. The adoption of SFAS 145 did not have a material effect on
the financial statements of the Company.
SFAS No. 146 -- In June 2002, the FASB issued SFAS No. 146,
"Accounting for Exit or Disposal Activities" (SFAS 146). SFAS 146
addresses significant issues regarding the recognition,
measurement, and reporting of costs that are associated with exit
and disposal activities, including restructuring activities that
are currently accounted for under EITF No. 94-3, "Liability
Recognition for Certain Employee Termination Benefits and Other
Costs to Exit an Activity (including Certain Costs Incurred in a
Restructuring)." The scope of SFAS 146 also includes costs
F-14
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
j. Newly Issued Accounting Pronouncements (Continued)
related to terminating a contract that is not a capital lease and
termination benefits that employees who are involuntarily
terminated receive under the terms of a one-time benefit
arrangement that is not an ongoing benefit arrangement or an
individual deferred-compensation contract. SFAS 146 will be
effective for exit or disposal activities that are initiated
after December 31, 2002 and early
application is encouraged. The provisions of EITF No. 94-3 shall
continue to apply for an exit activity initiated under an exit
plan that met the criteria of EITF No. 94-3 prior to the adoption
of SFAS 146. The effect on adoption of SFAS 146 will change on a
prospective basis the timing of when the restructuring charges
are recorded from a commitment date approach to when the
liability is incurred. The adoption of SFAS 146 did not have a
material effect on the financial statements of the Company.
SFAS No. 147 -- In October 2002, the Financial Accounting
Standards Board (FASB) issued Statement of Financial Accounting
Standards (SFAS) No. 147, "Acquisitions of Certain Financial
Institutions" which is effective for acquisitions on or after
October 1, 2002. This statement provides interpretive guidance on
the application of the purchase method to acquisitions of
financial institutions. Except for transactions between two or
more mutual enterprises, this Statement removes acquisitions of
financial institutions from the scope of both SFAS 72 and
Interpretation 9 and requires that those transactions be
accounted for in accordance with SFAS No. 141, "Business
Combinations" and No. 142, "Goodwill and Other Intangible
Assets". The adoption of SFAS No. 147 did not have a material
effect on the financial statements of the Company.
SFAS No. 148 -- In December 2002, the FASB issued SFAS No. 148,
"Accounting for Stock Based Compensation-Transition and
Disclosure-an amendment of FASB Statement No. 123" which is
effective for financial statements issued for fiscal years ending
after December 15, 2002. This Statement amends SFAS 123,
Accounting for Stock-Based Compensation, to provide alternative
methods of transition for a voluntary change to the fair value
based method of accounting for stock-based employee compensation.
In addition, this Statement amends the disclosure requirements of
SFAS 123 to require prominent disclosures in both annual and
interim financial statements about the method of accounting for
stock-based compensation and the effect of the method used on
reported results. The adoption of SFAS No. 148 did not have a
material effect on the financial statements of the Company.
SFAS No. 149 -- In April 2003, the FASB issued SFAS No. 149,
"Amendment of Statement 133 on Derivative Instruments and Hedging
Activities" which is effective for contracts entered into or
modified after June 30, 2003 and for hedging relationships
designated after June 30, 2003. This statement amends and
clarifies financial accounting for derivative instruments
embedded in other contracts (collectively referred to as
derivatives) and hedging activities under SFAS 133. The adoption
of SFAS No. 149 did not have a material effect on the financial
statements of the Company.
F-15
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
j. Newly Issued Accounting Pronouncements (Continued)
SFAS No. 150 -- In May 2003, the FASB issued SFAS No. 150,
"Accounting for Certain Financial Instruments with
Characteristics of both Liabilities and Equity" which is
effective for financial instruments entered into or modified
after May 31, 2003, and is otherwise effective at the beginning
of the first interim period beginning after June 15, 2003. This
Statement establishes standards for how an issuer classifies and
measures in its statement of financial position certain financial
instruments with characteristics of both liabilities and equity.
It requires that an issuer classify a financial instrument that
is within its scope as a liability (or an asset in some
circumstances) because that financial instrument embodies an
obligation of the issuer. The adoption of SFAS No. 150 did not
have a material effect on the financial statements of the
Company.
FASB Interpretation No. 45 -- "Guarantor's Accounting and
Disclosure Requirements for Guarantees, Including Indirect
Guarantees of Indebtedness of Others - an Interpretation of FASB
Statements No. 5, 57 and 107". The initial recognition and
initial measurement provisions of this Interpretation are to be
applied prospectively to guarantees issued or modified after
December 31, 2002. The disclosure requirements in the
Interpretation were effective for financial statements of interim
or annual periods ending after December 15, 2002. The adoption of
FASB Interpretation No. 45 did not have a material effect on the
financial statements of the Company.
FASB Interpretation No. 46 -- In January 2003, the FASB issued
FASB Interpretation No. 46 "Consolidation of Variable Interest
Entities." FIN 46 provides guidance on the identification of
entities for which control is achieved through means other than
through voting rights, variable interest entities, and how to
determine when and which business enterprises should consolidate
variable interest entities. This interpretation applies
immediately to variable interest entities created after January
31, 2003. It applies in the first fiscal year or interim period
beginning after June 15, 2003, to variable interest entities in
which an enterprise holds a variable interest that it acquired
before February 1, 2003. The adoption of FIN 46 did not have a
material impact on the Company's financial statements.
During the year ended December 31, 2003, the Company adopted the
following Emerging Issues Task Force Consensuses: EITF Issue No.
00-21 "Revenue Arrangements with Multiple Deliverables", EITF
Issue No. 01 -8 " Determining Whether an Arrangement Contains a
Lease", EITF Issue No. 02-3 "Issues Related to Accounting for
Contracts Involved in Energy Trading and Risk Management
Activities", EITF Issue No. 02-9 "Accounting by a Reseller for
Certain Consideration Received from a Vendor", EITF Issue No.
02-17, "Recognition of Customer Relationship Intangible Assets
Acquired in a Business Combination", EITF Issue No. 02-18
"Accounting for Subsequent Investments in an Investee after
Suspension of Equity Method Loss Recognition", EITF Issue No.
03-1, "The Meaning of Other Than Temporary and its Application to
F-16
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 1 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)
j. Newly Issued Accounting Pronouncements (Continued)
Certain Instruments", EITF Issue No. 03-5, "Applicability of
AICPA Statement of Position 9702, 'Software Revenue Recognition'
to Non-Software Deliverables in an Arrangement Containing More
Than Incidental Software", EITF Issue No. 03-7, "Accounting for
the Settlement of the Equity Settled Portion of a Convertible
Debt Instrument That Permits or Requires the Conversion Spread to
be Settled in Stock", EITF Issue No. 03-10, "Application of EITF
Issue No. 02-16 by Resellers to Sales Incentives Offered to
Consumers by Manufacturers.
k. Accounts Receivable
Accounts receivable are shown net of an allowance for bad debt of
$2,000 at December 31, 2003.
l. Preferred Stock
The Company has authorized 10,000,000 shares of $0.001 par value
preferred stock. The preferred stock shall have preference as to
dividends and to liquidation of the Company. During the year
ended December 31, 2002, the Company converted the preferred
stock and accrued dividend payable into 16,835,938 shares of
common stock. The common stock was valued at 80% of the closing
price on August 31, 2001 which was the dividend declaration date.
NOTE 2 - OIL AND GAS PROPERTY
At December 31, 2003 the Company's proved properties consist of
costs in the following areas net of accumulated depletion of
$2,555,872.
Wyoming $ 523,603
=================
Productive Gas Wells
The following summarizes the Company's productive oil and gas
wells as of December 31, 2003. Productive wells are producing
wells and wells capable of production. Gross wells are the total
number of wells in which the Company has an interest. Net wells
are the sum of the Company's fractional interests owned in the
gross wells.
Gross Net
------------------ -----------------
Productive oil wells 6 1.93
================== =================
The Company does not operate any of these wells.
F-17
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 2 - OIL AND GAS PROPERTY (Continued)
Oil and Gas Acreage
The following table sets forth the undeveloped leasehold acreage,
by area, held by the Company as of December 31, 2003. Undeveloped
acres are acres on which wells have not been drilled or completed
to a point that would permit the production of commercial
quantities of oil and gas, regardless of whether or not such
acreage contains proved reserves. Gross acres are the total
number of acres in which the Company has a working interest. Net
acres are the sum of the Company's fractional interests owned in
the gross acres. In certain leases, the Company's ownership
varies at different depths; therefore, the net acres in these
leases are calculated using the lowest ownership interest at any
depth.
Gross Net
------------------ -----------------
Wyoming 14,158 12,168
================== =================
During the year ended December 31, 2003, the Company sold its 75%
working interest in the West Virginia gas wells for $380,000. The
proceeds were used to settle the Baker Hughes litigation.
F-18
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 3 - LONG-TERM DEBT
The Company had the following debt obligations at December 31,
2003:
First National Bank of St. Marys, $9,244 payable monthly,
prime plus 2% interest rate, secured by equipment and personal
guarantee of officers. $ 158,473
Union Bank of Tyler County, $332 due monthly, 10% interest
rate, due November 20, 2005, secured by vehicle. 6,968
Union Bank of Tyler County, interest at 10% due quarterly,
renewable, due on demand, unsecured 19,683
Union Bank of Tyler County, principal and interest payments of
$799 due monthly, interest rate of 14.4%, due September 25,
2004,
secured by vehicle and personal guarantee of officers. 6,866
Wesbanco, interest payable quarterly, prime +1%, due on demand,
secured by officers' personal assets. 300,000
Note payable to an individual, due on demand, bearing interest at
NY prime +1%, interest payments due monthly, secured by
equipment. 292,078
Union Bank of Tyler County, principal and interest payments of
$326 due monthly, interest at 5.0%, secured by vehicle of the
Company. 16,517
Note due to a private individual, due on demand with interest
at 20%, secured by personal guarantee of officers. 200,919
Note payable to Raven Group, interest imputed at 10%, due on
demand, unsecured. 325,000
-----------------
Total 1,326,504
Less Current Portion (1,221,083)
-----------------
Total Long-Term Debt $ 105,421
=================
F-19
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 3 - LONG-TERM DEBT (Continued)
Future maturities of long-term debt are as follows:
2004 $ 1,221,083
2005 95,100
2006 3,479
2007 3,656
2008 3,186
2009 and thereafter --
--------------------
Total $ 1,326,504
====================
At December 31, 2003, total interest accrued for these debt
obligations was $171,942.
NOTE 4 - RELATED PARTY TRANSACTIONS
a. Marketing Agreement - Sancho
Natural gas delivered through the Company's pipeline network is
sold either to Sancho Oil and Gas Corporation ("Sancho"), a
company controlled by the Vice President of the Company, at the
industrial facilities near Sistersville, West Virginia, or to
Dominion Gas, a local utility, on an on-going basis at a variable
price per month per Mcf.
Under its contract with Sancho, the Company has the right to sell
natural gas subject to the terms and conditions of a 20-year
contract, as amended, that Sancho entered into with Dominion Gas
in 1988. This agreement is a flexible volume supply agreement
whereby the Company receives the full price which Sancho charges
the end user less a $0.05 per Mcf marketing fee paid to Sancho.
b. Well Drilling and Operating Agreement
In June 2000, the Company entered into a well drilling and
operating agreement with Sancho Oil and Gas Corporation
("Sancho"), a company controlled by the Vice President of the
Company, on an on-going basis. Sancho provided seven drill-down
wells located in Tyler County, West Virginia and the Company was
to pay 100% of the cost of drilling and completing the well
including any topside equipment needed and other related
equipment. The Company will receive 75% of the working interest
in each of the wells competed.
c. Receivables and Payables
The Company has various receivables from and payables to the
officers and companies of the officers. These amounts have been
grouped together with a net payable of $1,030,033 at December 31,
2003. The net payable bears interest at 10%, is due on demand and
is unsecured. At December 31, 2003, total interest accrued in the
net related party payable was $241,648.
F-20
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 5 - ECONOMIC DEPENDENCE AND MAJOR CUSTOMERS
The Company's marketing arrangement with Sancho accounted for
approximately 82% and 82% of the Company's revenue for the years
ended December 31, 2003 and 2002, respectively in Tyler
Construction Company. This marketing agreement is in effect until
December 1, 2008. Another customer also generated sales of 99%
and 99% of Ritchie County total sales in 2003 and 2002,
respectively.
NOTE 6 - STOCKHOLDERS' EQUITY
In 2001, the Company issued 4,655,000 shares of common stock for
services rendered. The shares were valued at an average price of
$0.03 per share for total consideration of $141,305. The shares
were issued after the services were rendered and were valued at
the closing price on the dates of issue.
During February 2002, the Company converted 300 shares of
preferred stock and $23,250 of cumulative preferred dividends
into 16,835,938 shares of common stock. As a result of this
conversion, the Company has -0- shares of preferred stock issued
and outstanding at December 31, 2002.
During February 2002, the Company received $200,000 for the
purchase of 33,333,333 shares of common stock and was shown as a
stock subscription deposit. During September 2002, the Company
issued the 33,333,333 shares and at September 30, 2002 the stock
subscription deposit was reduced to $-0-.
During March 2002, the Company entered into a promissory note
with an unrelated party for $25,000. The note is payable upon
demand and accrues interest at 10% per annum. During September
2002, the Company issued 4,166,667 shares of its common stock for
the conversion of notes payable for this amount.
During April 2002, the Company issued 5,000,000 shares of its
common stock for the conversion of notes payable in the amount of
$50,000. The Company additionally issued 1,000,000 shares of its
common stock for services rendered and valued at $29,000.
During October 2002, the Company entered into an agreement for a
proposed private offering of either its debt or equity securities
with an investment banking firm. The Company was required to pay
$10,000 at the time of the agreement as an advance towards
expenses. The advance may be paid using cash and/or the Company's
common stock not to exceed 500,000 shares regardless of the
market value of the stock at the time of issuance. During October
2002, the Company issued 500,000 shares of its common stock
valued at $10,000 as an advance in accordance with the agreement.
The Company later decided not to proceed with the proposed
private offering and forfeited the $10,000 advance as per the
terms of the agreement.
In January 2003, the Company issued 3,500,000 shares of common
stock valued at $0.003 per share for total cash consideration of
$10,500.
In March 2003, the Company issued 150,000 shares of common stock
valued at $0.035 per share for the conversion of convertible debt
of $5,250.
F-20
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 6 - STOCKHOLDERS' EQUITY (Continued)
In June 2003, the Company issued 22,833,163 shares of common
stock for the extinguishment of related party debt valued at
$30,043.
In December 2003, the Company issued 5,008,148 shares of common
stock for the extinguishment of debts valued at $33,805.
NOTE 7 - JUDGMENTS PAYABLE
Tioga Lumber Company
A foreign judgment has been filed with the Circuit Court in
Pleasants County, West Virginia for a judgment against the
Company by Tioga Lumber Company (Tioga) rendered by the Circuit
Court in Pleasants County, West Virginia for non-payment of an
accounts payable. The judgment is for $46,375 plus prejudgment
interest at 10.00%.
On February 28, 2002, the Company and Tioga reached an agreement
wherein the Company would pay Tioga $10,000 by March 5, 2002 and
$8,000 per month thereafter. The court appointed a special
commissioner to act as an arbitrator if the Company defaults. The
special commissioner would attach a lien if property is found
which does not have a lien attached. The first payment has been
made, and at December 31, 2002, the balance due including
interest to Tioga was $26,092 and is included in judgments
payable and is classified as a current liability. This judgment
was paid in full in 2003, however the judgment has not yet been
released.
Dennis L. Spencer
In January 2002, Dennis L. Spencer filed suit against the Company
and William F. Woodburn and Loren E. Bagley in the Circuit Court
of Ritchie County, West Virginia (Civil Action No. 02-C-02). The
complaint alleges that the Company sold certain assets that Mr.
Spencer claims to be the beneficial owner. The complaint seeks
$1,000,000 in damages. The Company has filed its answer to the
allegations and feels that the Company has met its obligations in
full to Mr. Spencer. Management also believes the suit is without
merit and intends to vigorously defend the action. The Company
has not accrued any amounts for these claims as of December 31,
2003 because the Company feels that based on its defenses against
the claims that the Company will have no additional liability.
Due to the early stage of litigation, it is not possible to
evaluate the likelihood of an unfavorable outcome or estimate the
extent of potential loss.
F-21
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 7 - JUDGMENTS PAYABLE (Continued)
Ross O. Forbus
On April 16, 2001, Ross O. Forbus obtained a judgment against the
Company for $428,018 plus post judgment interest at 10.00% per
annum. The judgment was obtained to satisfy a previous note
payable. The Company has made several small payments to Mr.
Forbus and is currently negotiating with him toward extending the
payments until the judgment can be paid in full. Mr. Forbus has
made a demand upon the Company for payment of the full
obligation. The Company has accrued the balance of $428,018 plus
accrued interest of $83,730 which is included in judgments
payable and accrued expenses respectively.
Core Laboratories, Inc.
On July 28, 1999, Core Laboratories, Inc. (Core) obtained a
judgment against the Company for non-payment of an accounts
payable. The judgment calls for monthly payments of $351 and is
bearing interest at 10.00% per annum. At December 31, 2003, the
Company had accrued a balance of $13,587 including interest of
$3,580 which is included in judgments payable and accrued
expenses, respectively.
RR Donnelly
On July 1, 1998, RR Donnelly (RR) obtained a judgment against the
Company for non-payment of accounts payable. The judgment calls
for monthly payments of $3,244 and is bearing interest at 10.00%
per annum. At December 31, 2002, the Company has accrued a
balance of $56,792 including interest of $20,736 which is
included in judgment payable and accrued expenses, respectively.
Baker Hughes Entities
On February 7, 2001, the United States Bankruptcy Court, Southern
District of Texas, entered an Order Granting Motion to Dismiss
Chapter 7 Case in the action entitled In Re: Trans Energy, Inc.,
Case No. 00-39496-H4-7. The Order dismissed the involuntary
bankruptcy action instituted against the Company on October 16,
2000. The sole petitioning creditor named in the Involuntary
Petition was Western Atlas International, Inc. ("Western"). An
Order for Relief Under Chapter 7 was entered by the Court on
November 22, 2000.
On April 23, 2000, the 189th District Court of Harris County,
Texas entered an Agreed Final Judgment in favor of Western
against the Company in the amount of $600,665, together with post
judgment interest at 10% per annum. Following the judgment,
Western and the Company entered into settlement negotiations
concerning the Company's satisfaction of the judgment through
payments over a four to five month period together with the
pledge of collateral on certain unencumbered assets.
F-22
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 7 - JUDGMENTS PAYABLE (Continued)
Baker Hughes Entities (Continued)
Previously, on or about July 9, 1998, a judgment had been entered
in the 152nd District Court of Harris County, Texas against the
Company in favor of Baker Hughes Oilfield Operations, Inc. d/b/a/
Baker Hughes Inteq. Western Geophysical ("Baker"), a division of
Western Atlas International, Inc., in the amount of $41,142,
together with interest and attorney fees. This judgment was
outstanding at the time of the filing of the Involuntary
Petition.
During its negotiations with Western for settlement of the
Judgment, the Company made a $200,000 "good faith payment" to
Western's counsel on October 23, 2000. On December 12, 2000, Joe
Hill was named as the Chapter 7 Trustee. Subsequently, Western's
counsel delivered the $200,000 to the Trustee.
On January 19, 2001, the Company filed with the Bankruptcy Court
the Motion to Dismiss Chapter 7 Case. The reasons cited by the
Company in support of its Motion to Dismiss included, but were
not limited to, (i) the Texas Court being an improper venue for
the action, and (ii) the Company never receiving the Involuntary
Petition and Summons notifying it of the action.
In anticipation of the Bankruptcy Court dismissing the
Involuntary Petition, on February 2, 2001, the Company entered
into a Settlement Agreement with Baker Hughes Oilfield
Operations, Inc. d/b/a/ Baker Hughes Inteq. Western Geophysical,
a division of Western Atlas International, Inc. (the "Baker
Entities"). In entering its order on February 7, 2001 to dismiss
the action, the Court ordered the Trustee to retain $17,695 for
satisfaction of administrative fees and expenses, and to pay to
Western and Baker the sum of $182,737, on behalf of the Company
and pursuant to the terms of the Settlement Agreement.
The Settlement Agreement provided that, subject to the approval
of the Bankruptcy Court, the Company agreed to pay to the Baker
Entities $759,664, plus interest at 10%. In addition to the
$200,000 payable from the escrow, the Company agreed to pay to
the Baker Entities an initial payment of $117,261 within fifteen
days from the date of the Dismissal Order (due February 21,
2001).
The Company also agreed to make additional payments of $100,000
every thirty days following the initial payment, with the first
payment due beginning no later than March 23, 2001, continuing
until the total obligation plus interest is paid in full.
Further, the Company pledged as collateral certain properties,
personal property and fixtures and two directors each pledged
750,000 shares of the Company's common stock which they
personally own.
F-23
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 7 - JUDGMENTS PAYABLE (Continued)
Baker Hughes Entities (Continued)
During 2002, the Company assigned the income stream from the sale
of oil from three of its wells (Pinon Fee #1, Sagebrush #1 and
Sagebrush #2) to the Baker entities as payments towards the
amounts owed. The Company believes that this payment will satisfy
the Baker Entities until the Company has paid the full
obligation. The Baker Entities continue its proceedings to
enforce a foreign judgment against the Company in Pleasants
County, West Virginia.
The Baker Entities continued its proceedings to enforce a foreign
judgment against the Company in Pleasants County, West Virginia.
Then on December 23, 2003, the Company and the Baker Entities
entered into a Settlement Agreement and Mutual Release whereby
the Company paid $350,000 to the Baker Entities as payment in
full for all monies owned and the Baker Entities gave the Company
a release of all judgments and liens against.
Lario Oil & Gas Company
On January 15, 2003, Lario Oil & Gas Company ("Lario") filed a
suit against the Company in the Sixth District Court of Campbell
County, Wyoming (Civil Action No. 24575). Lario is asking for
$50,692, which it claims the Company owes for operating fees on
the Pinon Fee #1, Sagebrush #1 and Sagebrush #2 wells, operated
by Lario and in which the Company has working interests. The
Company is preparing an answer to the complaint and is asking for
a complete accounting of all monies owed. Lario is retaining a
portion of the Company's share of the monthly oil production
monies and applying them to the amount owed.
F-24
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 7 - JUDGMENTS PAYABLE (Continued)
O.C. Smith
On February 5, 2003, O.C. Smith obtained a judgment against the
Company for $6,000 as ordered by the Circuit Court of Ritchie
County, West Virginia. Mr. Smith had brought suit against the
Company, successor of Apple Corporation, for an accounting of all
gas purchased by the Company as well as judgment for all amounts
still owing. The Company had acquired all of Apple Corporation's
interest in this gas and management determined that there was an
unpaid balance still owing Mr. Smith. The $6,000 is payable in
three monthly installments beginning on April 25, 2003. At
December 31, 2003, the Company had accrued the total amount of
$2,000 and has included it in judgments payable and has
classified it as a current liability.
NOTE 8 - GOING CONCERN
The Company's consolidated financial statements are prepared
using generally accepted accounting principles applicable to a
going concern which contemplates the realization of assets and
liquidation of liabilities in the normal course of business. The
Company has incurred cumulative operating losses through December
31, 2002 of $28,692,026, and has a working capital deficit at
December 31, 2002 of $6,246,995.
Revenues have not been sufficient to cover its operating costs
and to allow it to continue as a going concern. The potential
proceeds from the sale of common stock, sale of drilling
programs, and other contemplated debt and equity financing, and
increases in operating revenues from new development would enable
the Company to continue as a going concern. There can be no
assurance that the Company can or will be able to complete any
debt or equity financing. The Company's consolidated financial
statements do not include any adjustments that might result from
the outcome of this uncertainty.
NOTE 9 - CONVERTIBLE DEBENTURES
On September 10, 1998, the Company completed a debenture issue of
$4,625,400 face value of 8% Secured Convertible Debentures due
March 31, 1999 (the "Debentures"). Interest shall accrue from the
date of issuance until payment in full of the principal sum has
been made or duly provided for. Holders of the Debentures shall
have the option, at any time, until maturity, to convert the
principal amount of their Debenture, or any portion of the
principal amount which is at least $10,000 into shares of the
Company's Common Stock at a conversion price for each share equal
to the lower of (a) seventy percent (70%) of the market price of
the Company's Common Stock averaged over the five trading days
prior to the date of conversion, or (b) the market price on the
issuance date of the Debentures. Any accrued and unpaid interest
shall be payable, at the option of the Company, in cash or in
shares of the Company's Common Stock valued at the then effective
conversion price.
F-25
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 9 - CONVERTIBLE DEBENTURES (Continued)
Pursuant to the terms of the Debentures, the Company had agreed
to file a registration statement with the Commission to register
the shares of the Company's Common Stock into which the
Debentures may be converted. Upon effectiveness of the
registration statement, the shares of the Company's Common Stock
underlying the Debentures, when issued, will be deemed registered
securities and will not be restricted as to the resale of such
securities.
If the Company failed to file its registration statement within
forty-five (45) days from the closing of the Debenture offering,
the Company would be obligated to increase by up to fifteen
percent (15%) the number of shares issuable upon conversion to
each holder.
The Company failed to obtain an effective registration statement.
The Company has accrued and fully amortized a discount on the
Debentures of $1,445,480 to compensate for the seventy percent
(70%) market price conversion and contributed this amount to
additional paid-in capital. The Company has also accrued an
additional amount of $963,653 as a penalty payable to compensate
for the non-filing of the registration statement penalty of 15%
and for the 5% discount on the conversion of the debentures
penalty and have added these amounts to the debenture payable as
of December 31, 1999. In 1999, the Company converted $469,064 of
the debenture and $60,102 of the penalties and interest into
4,398,929 shares of common stock.
In 2000, the Company converted $1,547,655 of interest and
penalties and $4,106,337 of the debentures payable into
151,930,606 shares of common stock. At December 31, 2003, the
Company owed $331,462 on the debentures consisting of $50,000 for
a debenture and $281,462 in penalties.
NOTE 10 - BUSINESS SEGMENTS
The Company has adopted SFAS No. 131, "Disclosure about Segments
of an Enterprise and Related Information." The Company conducts
its operations principally as oil and gas sales with Trans Energy
and Prima Oil and pipeline transmission with Ritchie County and
Tyler Construction.
F-26
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 10 - BUSINESS SEGMENTS (Continued)
Certain financial information concerning the Company's operations
in different industries is as follows:
For the
Years Ended Pipelines Corporate
December 31, Sales Transmission Unallocated
------------ ---------- ------------ -----------
Oil and gas revenue 2003 $ 535,278 $ 1,479,734 $ --
2002 454,288 435,476 --
Operating loss applicable to
industry segment 2003 994,005 113,567 --
2002 1,137,369 262,180 --
General corporate expenses
not allocated to industry
segments 2003 -- -- --
2002 -- -- --
Interest expense 2003 (344,923) (59,413) --
2002 (390,687) (98,190) --
Other income (expenses) 2003 20,386 105,704 --
2002 19,669 2,868 --
Assets
(net of intercompany accounts) 2003 766,733 638,316 --
2002 2,250,407 497,229 --
Depreciation and amortization 2003 870,537 90,644 --
2002 810,451 108,913 --
Property and equipment
acquisitions 2003 152,848 -- --
2002 -- 10,249 --
NOTE 11 - OUTSTANDING STOCK OPTIONS
The Company applies Accounting Principles Board ("APB") Opinion
25, "Accounting for Stock Issued to Employees," and related
Interpretations in accounting for all stock option plans. Under
APB Opinion 25, compensation cost is recognized for stock options
granted to employees when the option price is less than the
market price of the underlying common stock on the date of grant.
F-27
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
NOTE 11 - OUTSTANDING STOCK OPTIONS (Continued)
FASB Statement 123, "Accounting for Stock-Based Compensation"
("SFAS No. 123"), requires the Company to provide proforma
information regarding net income and net income per share as if
compensation costs for the Company's stock option plans and other
stock awards had been determined in accordance with the fair
value based method prescribed in SFAS No. 123. The Company
estimates the fair value of each stock award at the grant date by
using the Black-Scholes option pricing model.
A summary of the status of the Company's stock option plans as of
December 31, 2002 and changes during the year is presented below:
Weighted
Average
Shares Exercise Price
------ --------------
Outstanding, December 31, 2002 795,057 $ 0.50
Granted -- --
Canceled/Expired (795,057) (0.50)
-------- ---------
Exercised -- --
-------- ---------
Outstanding, December 31, 2003 -- $ --
======== =========
Exercisable, December 31, 2003 -- --
======== =========
NOTE 12 - NOTES PAYABLE - CONVERTIBLE
Nine (9) convertible debentures dated between February 21, 2001
and April 27, 2001 bearing interest at 10% with interest and
principal due upon demand; unsecured; convertible into the
Company's common stock at $0.035 per share $ 36,325
----------
Less current portion (36,325)
----------
Long-term portion $ --
==========
The Company recognized an additional expense of $23,989 because
of the additional beneficial feature offered to the debenture
holders below the market value. This beneficial conversion
feature was expensed during the year ended December 31, 2001
pursuant to the EITF 96-18 and has been included in the general
and administrative expense in the accompanying consolidated
statement of operations.
F-28
TRANS ENERGY, INC. AND SUBSIDIARIES
Notes to the Consolidated Financial Statements
December 31, 2003 and 2002
(Unaudited)
NOTE 13- SUBSEQUENT EVENTS
Subsequent to year end the Company's subsidiary Tyler
Construction sold approximately 47,000 feet of pipeline to Triad
Energy Corporation for $200,000. The Company used $161,391 of the
proceeds to pay off the loan to the First National Bank of St.
Marys.
Subsequent to year end, the Company issued 3,190,396 shares of
common stock for the conversion of all convertible debentures and
the associated accrued interest.
S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES
(1) Capitalized Costs Relating to Oil
and Gas Producing Activities
December 31,
2003 2002
----------- -----------
Proved oil and gas producing properties and related
lease and well equipment $ 3,171,426 $ 3,678,730
Unproved oil and gas properties 99,945 95,945
Accumulated depreciation and depletion (2,555,878) (1,839,295)
----------- -----------
Net Capitalized Costs $ 715,493 $ 1,935,380
=========== ===========
(2) Costs Incurred in Oil and Gas Property
Acquisition, Exploration, and Development Activities
For the Years Ended
December 31,
2003 2002
---------------- ----------------
Acquisition of Properties
Proved $ -- $ --
Unproved -- --
Exploration Costs -- --
Development Costs -- --
The Company does not have any investments accounted for by the
equity method.
F-29
TRANS ENERGY, INC. AND SUBSIDIARIES
S.F.A.S. 69 Supplemental Disclosures
December 31, 2003 and 2002
(Unaudited)
S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES (CONTINUED)
(3) Results of Operations for
Producing Activities
For the Year Ended
December 31,
----------------------
2003 2002
--------- ---------
Sales $ 535,278 $ 454,288
Production costs (299,851) (277,125)
Depreciation and depletion (841,250) (801,776)
Income tax expenses -- --
--------- ---------
Results of operations for producing activities
(excluding the activities of the pipeline transmission
operations, corporate overhead and interest costs) $(605,823) $(624,613)
========= =========
(4) Reserve Quantity Information
Oil Gas
BBL MCF
----------- -----------
Proved developed and undeveloped reserves 113,406 1,131,415
End of the year 2002 17,454 --
Revisions of previous estimates
Improved recovery -- --
Purchases of minerals in place -- --
Extensions and discoveries -- --
Production (30,980) (45,055)
Sales of minerals in place -- (1,086,360)
---------- ----------
End of the year 2003 99,880 --
========== ==========
Proved developed reserves:
Oil Gas
BBL CF
---------- ----------
End of the year 2002 113,406 1,131,415
End of the year 2003 99,880 --
F-30
TRANS ENERGY, INC. AND SUBSIDIARIES
S.F.A.S. 69 Supplemental Disclosures
December 31, 2003 and 2002
(Unaudited)
S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES (CONTINUED)
During the years ended December 31, 2003 and 2002, the Company had
reserve studies and estimates prepared on its various properties. The
difficulties and uncertainties involved in estimating proved oil and
gas reserves makes comparisons between companies difficult. Estimation
of reserve quantities is subject to wide fluctuations because it is
dependent on judgmental interpretation of geological and geophysical
data.
(5) Standardized Measure of Discounted
Future Net Cash Flows Relating to
Proved Oil and Gas Reserves
At December 31, 2003
Trans Energy
and
Subsidiaries
-----------------
Future cash inflows $ 3,220,287
Future production and development costs (740,666)
Future income tax expense --
----------------
Future net cash flows 2,479,621
10% annual discount for estimated timing of cash flows (615,244)
----------------
Standardized measure of discounted future net cash flows $ 4,769,701
=================
At December 31, 2002
Trans Energy
and
Subsidiaries
-----------------
Future cash inflows $ 8,063,052
Future production and development costs (1,854,502)
Future income tax expense --
----------------
Future net cash flows 6,208,550
10% annual discount for estimated timing of cash flows (1,438,849)
----------------
Standardized measure of discounted future net cash flows $ 4,769,701
================
Future income taxes were determined by applying the statutory income
tax rate to future pre-tax net cash flow relating to proved reserves.
The following schedule summarizes changes in the standardized measure
of discounted future net cash flow relating to proved oil and gas
reserves:
F-31
TRANS ENERGY, INC. AND SUBSIDIARIES
S.F.A.S. 69 Supplemental Disclosures
December 31, 2003 and 2002
(Unaudited)
S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES (CONTINUED)
For the Years Ended
December 31,
2003 2002
----------- -----------
Standardized measure, beginning of year $ 4,314,941 $ 3,649,994
Oil and gas sales, net of production costs -- --
Sales of mineral in place (2,411,293) --
Purchases -- --
Net change due to revisions in quantity estimates (39,271) 664,947
Accretion of discount items -- --
----------- -----------
Standardized measure, end of year $ 1,864,377 $ 4,314,941
=========== ===========
The above schedules relating to proved oil and gas reserves,
standardized measure of discounted future net cash flows and changes
in the standardized measure of discounted future net cash flows have
their foundation in engineering estimates of future net revenues that
are derived from proved reserves and prepared using the prevailing
economic conditions. These reserve estimates are made from evaluations
conducted by independent geologists, of such properties and will be
periodically reviewed based upon updated geological and production
data. Estimates of proved reserves are inherently imprecise. The above
standardized measure does not include any restoration costs due to the
fact the Company does not own the land.
Subsequent development and production of the Company's reserves will
necessitate revising the present estimates. In addition, information
provided in the above schedules does not provide definitive
information as the results of any particular year but, rather, helps
explain and demonstrate the impact of major factors affecting the
Company's oil and gas producing activities. Therefore, the Company
suggests that all of the aforementioned factors concerning assumptions
and concepts should be taken into consideration when reviewing and
analyzing this information.
F-32