<PAGE>
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
Annual Report Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
For the fiscal year ended December 31, 1995 Commission File
Number 0-9394
BLACK DOME ENERGY CORPORATION
------------------------------------------------------
(Exact name of registrant as specified in its charter)
Colorado 84-0808397
---------------------------------- -------------------
(State or other jurisdiction (IRS Employer
of incorporation or organization) Identification No.)
1536 Cole Boulevard, Suite 325
Golden, Colorado 80401
----------------------------------- ----------
(Address of principal executive (Zip Code)
offices)
Registrant's telephone number, including area code: (303) 231-9059
Securities registered pursuant to Section 12(b) of the Act: None
Securities registered pursuant to Section 12(g) of the Act:
Common Stock, No Par Value
(Title of Class)
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the Securities Exchange
Act of 1934 during the preceding 12 months (or for such shorter period that
the registrant was required to file such reports), and (2) has been subject to
such filing requirements for the past 90 days. Yes X No
Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be
contained, to the best of registrant's knowledge, in definitive proxy or
information statements incorporated by reference in Part III of this
Form 10-K or any amendment to this Form 10-K. [ X ]
As of March 21, 1996, 73,755 shares of no par value common stock (the
registrant's only class of voting stock) were outstanding, the market value
of which is currently indeterminable because of a lack of trading market
for the shares.
Documents incorporated by reference:
None.
This Form 10-K consists of 41 pages. Exhibits are indexed at
page 38
Page 1
<PAGE>
Index for Black Dome Energy Corporation
Page
----
PART I
Item 1. Business
General Developement of Business 2
Financial Information about Industry Segments 2
Narrative Discription of Business 2
Principal Products Produced and Services Rendered 2
Status of New Products or Industry Segments 3
Sources and Availability of Raw Materials 3
Patents, Trademarks, Licenses, Franchises and Concesssions 3
Seasonal Nature of Business 3
Working Capital Items 3
Major Customers 3
Backlog 3
Renegotiation or Termination of Goverment Contracts 4
Competitive Conditions 4
Research and Development 4
Enviromental Protection 4
Employees 5
Financial Information About Foreign and Domestic Operations
and Export Sales 5
Item 2. Properties
Office Facilities 5
Reserves 5
Proved Developed Reserves 6
Proved Developed Producing Reserves 6
Proved Developed Non-Producing Reserves 6
Proved Undeveloped Reserves 6
Present Value of Estimated Future Net Revenues from Proved
Developed and Proved Undeveloped Oil and Gas Reserves 6
Reserves Reported to Other Agencies 7
Production 7
Productive Wells and Acreage 7
Productive Oil and Gas Wells 7
Developed Acreage 8
Undeveloped Acreage 8
Drilling Activity 8
Present Activities 9
Delivery Commitments 9
Item 3. Legal Proceedings 9
Item 4. Submission of Matters to a Vote of Security Holders 9
PART II
Item 5. Market for the Registrant's Common Equity and Related
Stockholder Matters
Market Information 9
Holders 9
Dividends 9
Item 6. Selected Financial Data 10
<PAGE>
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations
Liquidity and Capital Resources 10
Results of Operations 11
Changes in Prices, Costs and Impact of Inflation 12
Item 8. Financial Statements and Supplementary Data
Report of Independent Certified Public Accountants 14
Balance Sheet Assets 16
Balance Sheet Liabilities and Stockholders Equity 17
Statement of Income 18
Statement of Stockholders Equity 19
Statement of Cash Flows 20
Notes to Financial Statements
1. Summary of Significatant Accounting Policies 21
Operations of the company 21
Property and equipment and depreciation, depletion,
and amortization 21
Inventory 21
Income taxes 21
Gain (loss) per share 21
Basis of presentation and going concern 22
2. Oil and Gas Operations 22
3. Income Taxes 22
4. Employment Contracts 23
5. Major Customers 23
6. Supplementary Oil and Gas Information (Unaudited) 23
7. Commitments and Contingencies 26
8. Related Party Transactions 26
9. Enviromental Liabilities 26
10. Reverse Stock Split and Treasury Stock 27
Item 9. Changes in and Disagreements with Accountantants on
Accounting and Financial Disclosure 28
PART III
Item 10. Directors and Executive Officers of the Registrant 28
Item 11. Executive Compensation
Executive Compensation 30
Compensation of Directors 32
Other Compensation 33
Employment Contracts and Termination of Employment
and Change of Control Arrangements 33
Item 12. Security Ownership of Certain Beneficial Owners and
Management 34
Item 13. Certain Relationships and Related Transactions
Transactions with Management and Others 36
Related Party Transactions 36
Certain Business Relationships 36
Indebtedness of Management 37
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on
Form 8-K. 38
Signatures 39
Letter of Consent - Joseph R. Albi, Jr. 40
Letter of Consent - Donald M. Osmus 41
<PAGE>
PART I
ITEM 1. BUSINESS
- ------- --------
(a) General Development of Business. Black Dome Energy Corporation
(referred to herein as the "Company" or "Black Dome"), was incorporated
under the laws of the State of Colorado on December 12, 1979, and maintains
its principal executive offices at 1536 Cole Boulevard, Suite 325, Golden,
Colorado 80401. It is an oil and gas company engaged in the exploration
for oil and gas, the purchase of producing oil and gas properties, the
sale of portions of the producing oil and gas properties and the operation
of producing oil and gas leases.
The Company explores for, developes and acquires interests in producing
oil and gas leases for the purpose of resale of a portion of the working
interest to industry participants, or for addition of reserves for its own
account. The Company acquires and retains the operation of the oil and gas
production from these leases.
During the fiscal year ended December 31, 1995, the Company's revenues
attributable to its overall income were derived primarily from the sale
of oil and gas from its producing oil and gas leases.
The Company owns working interests in certain properties located solely
in the continental United States. A more detailed description of the
Company's properties and reserves is set forth in Item 2 hereof.
(b) Financial Information About Industry Segments. The Company has
engaged in business in only one industry segment, namely the exploration
for oil and gas, production of oil and gas and the development of oil and gas
properties. Therefore, no information is provided with respect to any other
industry segment.
(c)(1) Narrative Description of Business. The Company is involved
in the exploration, development and purchase and production of oil and gas
properties as a general partner, joint venturer, or for its own account, and
as an oil and gas lease operator. The Company's activities have in the
past included the formation of joint ventures and drilling programs, and will
include in the future, the formation of partnerships and joint ventures for
the purchase, exploration, development and production of oil and gas leases
and the management of such programs. Should the Company be unsuccessful in
finding joint venturers and partners to share costs, the Company will sell
a portion of each oil and gas property purchased for cash, or will purchase
and pay for such property costs out of its own cash flow.
As a joint venturer, the Company may enter into joint venture agreements
to develop the full potential of properties purchased by the Company,
or to acquire and develop new oil and gas properties. The Company may drill
wells on such properties, complete the wells if appropriate, and act as the
operator of such properties.
(i) Principal Products Produced and Services Rendered. The Company's
principal products are natural gas, crude oil and oilfield operations and
supervision. Crude oil and natural gas are sold to various purchasers, which
generally service the areas in which the producing wells are located. The
Company operates oil and gas properties for its own account and for the
account of other working interest owners in the property.
Page 2
<PAGE>
(ii)Status of New Products or Industry Segments. There has been no
public announcement of, and no information otherwise has been made public
about, a new product or industry segment which would require the investment of a
material amount of the Company's assets or which otherwise is material.
(iii) Sources and Availability of Raw Materials. The existence of
commercial oil and gas reserves is essential to the ultimate realization of
value from the Company's properties and thus may be considered a raw
material essential to the Company's business. However, the acquisition,
exploration, development, production, and sale of oil and gas are
subject to many factors which areoutside the Company's control. These
factors include national and international economic conditions,
availability of drilling rigs, casing, pipe, and other equipment and
supplies, proximity to and capacity of pipelines, the supply and price of
other fuels, and the regulation of prices, production, transportation, and
marketing by the Department of Energy and other federal and state
governmental authorities. These factors have not materially hindered nor
adversely affected the business of the Company; however, it is not known
what, if any, additional regulations or constraints may arise, or to
what extent, if any, they may affect the Company's operations. The Company
acquires oil and gas properties from landowners, other owners of interests
in such properties, or governmental entities. For information relating to
specific properties of the Company, see Item 2 below.
(iv) Patents, Trademarks, Licenses, Franchises and Concessions. The
Company does not own any patents, trademarks, licenses, franchises or
concessions, except oil and gas leases and other interests granted by private
landowners, the loss of any one of which could have a material impact on the
Company.
(v) Seasonal Nature of Business. The Company's business is not
seasonal in nature, except to the extent that natural gas prices may tend to
fluctuate on a seasonal basis and development of its oil and gas properties
and its ability to drill oil and gas wells and the availability of drilling
rigs and other equipment, have occasionally been more restricted at calendar
year end due to increased demand from tax-sheltered drilling programs
conducted by others.
(vi) Working Capital Items. It is the practice of the Company as
well as others similarly situated in the industry to attempt to retain
working capital in order to participate in the purchase of producing
properties and the drilling and development of properties via partnerships,
joint ventures and other arrangements, and to acquire significant blocks of
undeveloped properties for future development and/or exploration. Working
capital is not needed to meet rapid delivery requirements of customers,
or to assure the Company of continuous allotments of goods from suppliers.
(vii) Major Customers. During fiscal 1995, two customers accounted
for 10% or more (individually) of total oil and gas sales: Boyd Rosene
and Associates, 73% and Helmerich & Payne Energy Services, Inc., 13%. The
Company believes that it could be adversely affected by the loss of these
major gas customers; however, there are numerous spot market gas purchasers
who could be utilizedfor the sale of natural gas. During 1995, the Company
sold oil and/or gas to eight (8) customers. No revenues were received in
connection with foreign governments in which the Company acted as a producer.
(viii) Backlog. The Company has no backlog due to the nature of its
business, nor is backlog material to an understanding of the Company's
business.
Page 3
<PAGE>
(ix) Renegotiation or Termination of Government Contracts. The
Company has no material portion of its business which may be subject to
renegotiation of profits or termination of contracts or subcontracts at the
election of government.
(x) Competitive Conditions. The purchase of existing producing
properties and exploration, development and production of oil and gas are
subject to considerable competition, and the Company is faced with strong
competition from major and medium sized oil and gas companies and other
independent operators. The principal methods of competition in the industry
for the acquisition of producing oil and gas properties and leases are
industry sales packages and the solicitation, bidding and auctioning of
individual producing properties, and the payment of bonus payments
at the time of acquisition of leases. Companies with greater financial and
operational resources, larger technical staffs and labor forces, better
developed equipment for exploration, and more extensive experience will be
in a better position than the Company to compete for such leases. In
addition, the ability of the Company to market any oil or gas which it
might produce could be severely limited by its inability to compete with
larger companies operating in the same area who may be willing or able
to offer any oil or gas produced by them at a price lower than that of the
Company. In addition, the availability of a ready market for oil and gas
will depend upon numerous factors beyond the Company's control, including
the extent of domestic production and imports of oil and gas, proximity and
capacity of pipelines, the overall foreign domestic supply and demand of oil
and gas, and the effect of federal, state and local regulations of oil
and gas production and sales. The Company has an insignificant competitive
position in the oil and gas industry.
(xi) Research and Development. The Company is engaged in finding and
producing oil and gas, and no funds are allocated to product research and
development in the conventional sense. Since its inception, the Company
has not had any customer or government sponsored research activities relating
to the development of new products, services or techniques or the improvement
of existing products, services or techniques.
(xii) Environmental Protection. The Company, as an owner and
operator of oil and gas properties, is subject to various federal, state
and local laws and regulations relating to the discharge of materials into,
and protection of, the environment. These laws and regulations, among other
things, impose liability on the Company for the cost of pollution clean-up
resulting from operations, subject the Company to liability for pollution
damages, require suspension or cessation of operations in affected areas and
impose restrictions on the injection of liquids into subsurface aquifers
that may contain groundwater.
Environmental requirements may necessitate significant capital outlays
which may materially affect the Company's earnings and potential earnings
and could cause material changes in its form of business. The Company
has made and will continue to make expenditures in its efforts to comply
with these requirements which it believes are necessary business costs
in the oil and gas industry. As of December 31, 1995, the Company is not
aware of any existing environmental claims which would have a material adverse
effect upon its capital expenditures, earnings or competitive position.
Page 4
<PAGE>
There is no assurance, however, that existing laws or regulations or
changes in or additions to laws or regulations regarding the protection of the
environment will not adversely affect the Company. It is impossible to
determine whether or to what extent the Company's future performance may be
affected by environmental laws; however, management does not believe that such
laws have had a material adverse effect on the Company's financial position
or results of operations.
(xiii) Employees. The Company currently has 2 full-time salaried
employees, one full-time contract employee, one part-time contract employee,
and one contract engineer employed on a retainer basis who are directly
engaged in its activities. The employees and retainer perform geologic,
engineering and economic property evaluations, production enhancement design
and operations, management and marketing of production on a daily basis,
accounting, and secretarial and administrative services for the Company,
as well as all general corporate management, under the direction of the
Board of Directors.
(d) Financial Information About Foreign and Domestic Operations and
Export Sales. The Company has no material operations in foreign countries
and no material portion of its sales or revenues is derived from customers
in foreign countries.
ITEM 2. PROPERTIES.
- ------- -----------
(a) Office Facilities. The Company's offices are located at 1536 Cole
Boulevard, Suite 325, Golden, Colorado 80401. The Company pays $1,240.00
monthly rental for the use of office facilities. The Company believes that
its present offices are suitable and adequate for its present operations.
(b)(1) Reserves. Proved developed and undeveloped oil and gas
reserves of the Company at December 31, 1995 and December 31, 1994 were
computed by Joseph R. Albi, Jr., a consulting petroleum engineer and former
Executive Vice President of the Company, and were audited by Donald M. Osmus,
a consulting Petroleum Engineer. Proved developed and undeveloped oil and gas
reserves of the Company at December 31, 1993 were computed by the Company and
audited by Donald M. Osmus.
All of the Company's reserves are located in the continental United States
and the majority of the properties comprising these reserves are operated
by Black Dome Energy Corporation.
<TABLE>
<CAPTION>
Reserve Category
-----------------------------------------------------------
Proved Developed Proved Undeveloped Total Proved
---------------- ------------------ ------------
(1) (2)
----- -----
December 31, (Bbls)* (Mcf)** (Bbls)* (Mcf)** (Bbls)* (Mcf)**
- ------------ ------- ------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C> <C>
1993 25,985 2,664,920 9,005 4,169 34,990 2,669,089
1994 9,355 2,031,425 -- -- 9,355 2,031,425
1995 9,825 1,431,318 -- 52,256 9,825 1,483,574
(*) Refers to barrels consisting of 42 U.S. gallons.
(**) Refers to a volume of 1,000 cubic feet under prescribed conditions of
pressure and temperature and represents the basic unit for measuring
the volume of natural gas.
</TABLE>
Page 5
<PAGE>
(1) Proved Developed Reserves. These are proved reserves which can
be expected to be recovered through existing wells with existing equipment
and operating methods. This classification includes:
(i) Proved Developed Producing Reserves. These are proved developed
reserves which are expected to be produced from existing completion
interval(s) now open for production in existing wells; and
(ii) Proved Developed Non-Producing Reserves. These are proved
developed reserves which exist behind the casing of existing wells, or
at minor depths below the present bottom of such wells, which are
expected to be produced through these wells in the predictable future,
where the cost of making such oil and gas available for production
should be relatively small compared to the cost of a new well.
Additional oil and gas expected to be obtained through the application
of fluid injection or other improved recovery techniques for supplementing
the natural forces and mechanisms of primary recovery are included
as "Proved Developed Reserves" only after testing by a pilot project or
after the operation of an installed program has confirmed through production
response that increased recovery will be achieved.
(2) Proved Undeveloped Reserves. These are proved reserves which
are expected to be recovered from new wells on undrilled acreage, or from
existing wells where a relatively major expenditure is required for
recompletion. Reserves on undrilled acreage are limited to those
drilling units offsetting productive units, which are reasonably certain
of production when demonstrated with certainty that there is continuity
of production from the existing productive formation. Estimates for proved
undeveloped reserves may be attributable to acreage for which an application
of fluid injection or other improved recovery technique is used or
contemplated only where such techniques have been proved effective by actual
tests in the area and in the same reservoir.
Present Value of Estimated Future Net Revenues from Proved Developed
and Proved Undeveloped Oil and Gas Reserves. The table below presents, as
of the end of 1995, 1994 and 1993, the present value of the estimated
future net revenues attributable to proved developed reserves and proved
undeveloped reserves discounted at an annual rate of ten percent (10%)
per year.
<TABLE>
<CAPTION>
Present Value of Future
Net Revenues (dis- Future Net Revenues
counted at 10%) as of Proved Proved Total
December 31, Developed Undeveloped Proved
------------------------ --------- ----------- ---------
<S> <C> <C> <C>
1993 $2,720,531 $19,185 $2,739,716
1994 $1,281,621 $ 0 $1,281,621
1995 $1,175,279 $21,037 $1,196,316
</TABLE>
While it is reasonable to anticipate that the prices received from the
future sale of production may be higher or lower than the prices used
in the evaluation described above, and the operating and other costs relating
to such production may increase above existing levels, such increases in
prices and costs have been omitted from consideration in making these
evaluations in accordance with rules adopted by the Securities and Exchange
Commission.
Page 6
<PAGE>
The Company emphasizes that reserve estimates and rates of production
are inherently imprecise and that estimates of new discoveries and
non-producing and/or undeveloped reserves are more imprecise than those of
mature producing oil and gas properties. Accordingly, the estimates are
subject to change as further information becomes available.
For additional information concerning oil and gas revenues, see Note
6 to the Financial Statements.
(b)(2) Reserves Reported to Other Agencies. The Company did not
file any oil or gas reserve estimates with, or include such estimates in
reports to, any other federal governmental authority or agency within its
last fiscal year.
(b)(3)(i) Production. The following table shows the Company's net
quantities of oil (including condensate and natural gas liquids) and
of gas produced for each of the Company's past three fiscal years:
<TABLE>
<CAPTION>
Net Oil and Gas Production
Year Ended December 31,
1995 1994 1993
<S> <C> <C> <C>
Gas (Mcf) 261,562 309,210 286,162
Oil/Condensate (Barrels) 1,382 2,747 2,783
</TABLE>
The Company has no long-term supply or similar arrangements with
foreign governments or authorities.
(b)(3)(ii) Average Sales Price and Production Costs. The average
sales prices (including transfers) and production costs per barrel of oil
and Mcf of gas received by the Company for the fiscal years ended
December 31, 1995, 1994 and 1993, were as follows. Equivalent barrels
of production were calculated on the basis of 6 Mcf equals 1 Barrel.
<TABLE>
<CAPTION>
Oil (Per Bbl) Gas (Per Mcf) Production (MCF)
------------- ------------- ----------------
Year Ended Sales Sales Costs of
December 31, Price Price Equivalent Bbls
----------- ----- ----- ---------------
<S> <C> <C> <C>
1995 $17.10 $1.45 $4.24
1994 16.97 1.83 6.21
1993 16.73 2.10 5.83
</TABLE>
(b)(4) Productive Wells and Acreage. The following tables set forth
the Company's: (i) total gross and net productive oil and gas wells, and (ii)
total gross and net developed acreage, both as of December 31, 1995:
(i) Productive Oil and Gas Wells. As of December 31, 1995, the
Company owned an interest in 21 oil and/or gas properties, 18 of which are
operated by the Company. The following depicts the number of gross and net oil
and gas wells producing or capable of production in which the Company owned an
interest at the end of the last fiscal period.
Page 7
<PAGE>
<TABLE>
<CAPTION>
Total Wells (Gross)* Total Wells (Net)**
Oil Gas Total Oil Gas Total
<S> <C> <C> <C> <C> <C> <C>
December 31, 1995 2 19 21 1.03 14.64 15.67
</TABLE>
The above numbers reflect a reduction of two (2) gross wells (1.73
net wells) which were plugged and abandoned in 1995.
(*) A "gross well or acre" is a well or acre in which a working
interest is owned. The number of gross wells or acres is the total number of
wells or acres in which a working interest is owned.
(**) A "net well or acre" exists when the sum of the fractional
ownership working interests in gross wells or acres equals one. The number
of net wells or acres is the sum of fractional working interests owned
in gross wells or acres, expressed as whole numbers and fractions thereof.
(ii) Developed Acreage. The following depicts the number of gross
and net developed acres in which the Company owned an interest at the
end of the Company's last fiscal year.
<TABLE>
<CAPTION>
Gross Acres Net Acres
----------- ---------
<S> <C> <C>
December 31, 1995 9,191 6,078
</TABLE>
(b)(5) Undeveloped Acreage. The following table sets forth information
regarding undeveloped acreage in which the Company has an interest.
<TABLE>
<CAPTION>
Location Gross Acres Net Acres
<S> <C> <C>
Kansas 160 105
Texas 28 10
--- ---
Total 188 115
</TABLE>
As of the date of this filing, the Company's total undeveloped acreage is
held by production and is not subject to expiration until the producing
well or wells which it holds is/are non-commercial or plugged and
abandoned.
(b)(6) Drilling Activity. The following summarizes the drilling
activity of the Company during each of the last three fiscal years.
<TABLE>
<CAPTION>
Year Ended Total Development Exploratory
December 31, Wells Oil Gas Dry Oil Gas Dry
------------ ----- ---------------- ------------------
<S> <C> <C> <C> <C> <C> <C> <C>
1995 -
Gross Wells 1 0 1 0 0 0 0
Net Wells .4 0 .4 0 0 0 0
1994 -
Gross Wells 0 0 0 0 0 0 0
Net Wells 0 0 0 0 0 0 0
1993 -
Gross Wells 0 0 0 0 0 0 0
Net Wells 0 0 0 0 0 0 0
</TABLE
Page 8
<PAGE>
(b)(7) Present Activities. The Company participated in the unsuccessful
drilling of one (1) gross well (.4 net well) during the fourth quarter of
1995. Two (2) gross wells (1.73 net wells) in which the Company held an
interest were plugged and abandoned during 1995. No additional oil and/or
gas properties were acquired by the Company during 1995.
(b)(8) Delivery Commitments. As of March 21, 1996, the Company was not
obligated to provide a fixed and determinable quantity of oil or gas in the
future pursuant to existing contracts or agreements, nor has the Company had
any significant delivery commitments since its inception on December 12,
1979.
ITEM 3. LEGAL PROCEEDINGS.
- ------- ------------------
There are no current legal proceedings concerning the Company and there
are none pending.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
- ------- ----------------------------------------------------
There were no shareholder meetings of the Company held during the fiscal
year ended December 31, 1995.
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED
STOCKHOLDER MATTER.
-----------------------------------------------------
(a) Market Information. From October 1980 through November 12, 1984,
Black Dome's common stock was traded on the over-the-counter market under
the symbol "BDEC" and the quotes were carried by NASDAQ during that period of
time. NASDAQ voluntarily withdrew "BDEC" from the system on November 12, 1984
due to the depressed price of the stock. Since that date there has been
sporadic trading in the Company's stock. At the present time, there are no
market makers listed in the "pink sheets".
(b) Holders. The number of holders of record of Black Dome's No Par
Value Common Stock at March 21, 1996 was approximately 1,616.
(c) Dividends. Holders of common stock are entitled to receive such
dividends as may be declared by Black Dome's Board of Directors. No dividends
have been paid with respect to Black Dome's common stock and no dividends
are anticipated to be paid in the foreseeable future.
Page 9
<PAGE>
ITEM 6. SELECTED FINANCIAL DATA.
- ------- ------------------------
</TABLE>
<TABLE>
<CAPTION>
Years Ended December 31,
1995 1994 1993 1992 1991
-------- -------- --------- -------- --------
<S> <C> <C> <C> <C> <C>
Total Revenues $440,661 $762,655 $677,537 $616,351 $265,490
Oil and Gas Sales 402,627 592,513 647,328 537,162 213,732
Other Revenue 38,034 170,172 30,209 79,189 51,758
Net Income (loss) (210,598) (44,498) 6,338 61,208 (37,793)
Net Income (loss)
per share (2.86)* (.61)* .16* .91* (.62)*
Total Assets 411,046 718,918 1,040,364 612,748 466,789
Obligations -- -- 120,000 60,000 --
Deferred Comp. 160,000 100,000 180,000
Bank Debt - LOC 84,987 132,724 223,987 -- --
</TABLE>
* Earnings per share are restated to reflect the 1 for 1001 reverse stock
split approved by shareholders on September 2, 1994.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS.
------------------------------------------------------------
Liquidity and Capital Resources
Working capital (which incorporates current and deferred obligations)
increased slightly by $2,137 during the year ended December 31, 1995. These
results followed a working capital increase of $84,031 in 1994. Lower
received natural gas prices, payment of a portion of the deferred
compensation, declining production without reserve replacement and significant
depreciable and depletable costs resulted in the Company's loss of $210,598
or $2.86/share in 1995. Low natural gas prices, payment of a portion of
the deferred compensation, unsuccessful workover costs of two wells in
Oklahoma, and the costs associated with restructuring the Company contributed
to the loss of $44,498 or $0.61 per share in 1994.
In October, 1992, as a source for additional working capital, the Company
obtained a $300,000 line of credit with a lending institution, secured with
10 producing natural gas wells in Clark County, Kansas. As of December
31, 1994, a total of $132,724 was borrowed from the line of credit. During
1995, the Company reconstructed the debt obligations associated with the
outstanding balance of the line of credit. As of December 31, 1995, the
Company had bank debt obligations of $84,987 tied to an 8.5% note which
matures on March 31, 1997. In addition, the Company holds a $150,000 line
of credit secured with eight (8) Clark County, Kansas producing gas
properties against which no sums were borrowed as of December 31, 1995.
The Company currently has no commitments for capital expenditures. The
Company is utilizing its own cash resources as well as outside capital to
attempt to purchase additional producing oil and gas properties. In
general, the Company's financial condition will not permit the risk of
exploratory or development drilling activities unless outside risk
capital is obtained.
Page 10
<PAGE>
Results of Operations
- ---------------------
During the fiscal year ended December 31, 1995, oil and gas revenues
decreased by $189,886 or 32% as compared to fiscal 1994, primarily as a
result of lower received natural gas prices, decreases in Company net oil
and gas production without reserve replacement and the sale of five (5)
properties in 1994. At December 31, 1995, twenty-one wells were producing
to contribute to this income. Management expects normal production
decline from the presently producing wells during 1996. At December 31,
1995, the Company was operating eighteen wells as opposed to nineteen
producing wells at December 31, 1994. Current markets remain unstable and
it is impossible to predict how these will function. Any price increase
or decrease will have a direct effect on the Company.
The Company experienced a net loss of $210,598 or $2.86/share during
1995 compared to a net loss of $44,498 or $.61/share during 1994. The
decrease in earnings is a direct result of significant operational/rework
expenses associated with properties, significantly lower received natural
gas prices, and declining production without reserve replacement.
Interest income has decreased in the past few years both because of
smaller amounts of invested cash and lower interest rates.
General and administrative costs decreased from $266,603 in 1994 to
$237,918 in 1995, primarily as a result of the elimination of one full time
salaried employee during 1994. However, overall general and administrative
costs remain high relative to the Company's size. Management believes
general and administrative costs cannot be reduced below current levels
while prudently managing the Company's assets.
Oil and gas production costs have decreased to $190,795 in 1995 as
compared to $300,236 in 1994. Both 1995 and 1994 oil and gas production
costs reflect the additional operational and re-work costs associated
with acquired properties.
The acquisition of producing gas properties in 1991, 1992 and 1993
significantly increased Black Dome's reserves during those three years.
During 1994, the Company focused on re-working operations to improve and
maintain production from all properties while recovering costs associated
with the acquisitions. During 1994, the Company disposed of five (5)
producing properties. During 1995, two (2) gas wells (1.73 net wells) in
which the Company held an interest were plugged and abandoned. The
Company was not successful in adding reserves through drilling or
acquisition activity during 1995.
As a result of significant production decline and the Company's
unsuccessful drilling and acquisition activity, net proved remaining
reserves decreased significantly (26% on a Bbl equivalency basis) between
December 31, 1995 and December 31, 1994. The estimated SEC net present
value of total proved reserves decreased from $1,281,621 at December 31,
1994 to $1,196,316 at December 31, 1995. Higher 1995 received year-end oil
and gas prices cushioned the impact of lower 1995 reserve levels on the
estimated SEC net present value of total proved reserves.
Page 11
<PAGE>
All of the foregoing conditions are expected to have a material adverse
impact on the future operations of the Company. The Company's revenues
are currently expected to continuously decrease during the next fiscal year
as properties are sold to pay expenses, and as the remaining producing
properties suffer normal declines in production. The Company does not
currently have sufficient financial resources to purchase new producing
properties to replenish expected production declines, or to replace
properties that have been (and in all likelihood will continue to be)
sold to pay operating expenses. Expenses of operations are not expected
to decrease during the next fiscal year.
During fiscal 1996, the Company intends to continue to explore reasonable
avenues relative to preserving and maximizing shareholder value. The
recurring losses from operations sustained by the Company (primarily as the
result of declining reserves, poor natural gas prices, inadequate reserve
replacement and relatively high fixed costs associated with maintaining
operations) raise substantial doubt about its ability to continue as a going
concern. One of the avenues that management currently intends to explore is
the voluntary liquidation of the Company during the next twelve months. In
the event that the Company is unable to receive significant funding from
some viable outside source or does not voluntarily liquidate substantially
all of its assets during the next twelve months, it currently appears to be
likely that the Company will continue to deplete its assets in order to
meet its ongoing operating expenses (which will ultimately result in little
or nothing being available for distribution to any of the Company's
shareholders upon its eventual liquidation.)
Under Colorado law the Company is not permitted to sell substantially
all of its assets without first obtaining approval from a majority of its
shareholders. The cost of holding such a shareholders' meeting (including
printing, mailing, legal and accounting expenses) is currently estimated
to be approximately $40,000. These costs will reduce the amount that would
otherwise have been available for distribution to shareholders upon
liquidation.
Changes in Prices, Costs and Impact of Inflation
- ------------------------------------------------
Current economic trends still indicate that costs of conducting
business activities will not rise as rapidly as they have during the
preceding inflationary years.
Governmental and foreign decisions over which Management has no control
could impact the prices received for the Company's oil and gas and could
have a very serious effect on profits. It is impossible to predict long
term or even short term trends in pricing.
Page 12
<PAGE>
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
- ------- --------------------------------------------
Page 13
REPORT OF INDEPENDENT CERTIFIED PUBLIC ACCOUNTANTS
--------------------------------------------------
The Board of Directors and Stockholders
Black Dome Energy Corporation
Evergreen, Colorado
We have audited the balance sheet of Black Dome Energy
Corporation as of December 31, 1995 and 1994 and the related
statements of income, stockholders' equity, and cash flows for
the three years ended December 31, 1995, 1994, and 1993. These
financial statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these
financial statements based on our audit.
We conducted our audit in accordance with generally accepted
auditing standards. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether
the financial statements are free of material misstatement. An
audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that
our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above
present fairly, in all material respects, the financial position
of Black Dome Energy Corporation as of December 31, 1995 and 1994
and the results of its operations and its cash flows for the
three years ended December 31, 1995, 1994, and 1993 in conformity
with generally accepted accounting principles.
As discussed in Note 1 to the financial statements, in 1995, the
Company elected to change its method of accounting for
depreciation of lease and well equipment from the straight line
method to the unit of production method and the financial
statements have been restated to reflect the change.
The accompanying financial statements have been prepared assuming
that the Company will continue as a going concern. As discussed
in Note 1 to the financial statements, the Company has suffered
recurring losses from operations which raise substantial doubt
about the Company's ability to continue as a going concern.
Management's plans in regard to these matters are also described
in Note 1. The financial statements do not include any
adjustments that might result from the outcome of this
uncertainty.
Littleton, Colorado Halliburton, Hunter, & Associates, P.C.
March 14, 1996
14
<PAGE>
BLACK DOME ENERGY CORPORATION
Balance Sheet
December 31, 1995 and 1994
15
<PAGE>
BLACK DOME ENERGY CORPORATION
Balance Sheet
-------------
<TABLE>
<CAPTION>
December 31,
-------------------------
1995 1994
---------- ---------
Assets
<S> <C> <C>
Current assets:
Cash $ 63,008 $ 53,429
Accounts receivable:
Joint interest owners 10,158 10,357
Oil and gas sales 69,772 86,273
Other 200 1,556
------- -------
Total current assets 143,138 151,615
------- -------
Property and equipment, at cost:
Oil and gas properties, net (successful
efforts method) 220,994 393,976
Other property and equipment, net of
accumulated depreciation of $58,367
and $51,427, respectively 1,988 7,589
Inventory of well equipment 44,926 53,921
------- -------
267,908 455,486
------- -------
Other assets:
Deposit --- 2,294
------- -------
$ 411,046 $ 609,395
=========== ===========
</TABLE>
See accompanying notes to financial statements
16
<PAGE>
<TABLE>
<CAPTION>
Liabilities and Stockholders' Equity
<S> <C> <C>
Current liabilities:
Notes payable, current portion $ 62,896 $ ---
Line-of-credit --- 132,724
Accounts payable, trade 78,581 79,257
Accounts payable, officer 9,600 9,600
Accrued interest 662 ---
Deferred compensation 160,000 100,000
-------- --------
Total current liabilities 311,739 321,581
-------- --------
Long-term debt, less current portion 22,091 ---
Commitments and Contingencies
Stockholders' equity:
Common stock, no par value. Authorized
75,000,000 shares; issued and outstanding
73,755 shares in 1995 and 73,455 shares
in 1994 292,415 292,415
Additional paid-in capital 1,886,495 1,886,495
Accumulated deficit (2,093,137) (1,882,539)
----------- -----------
85,773 296,371
-------- --------
Less treasury stock 8,557 8,557
-------- --------
77,216 287,814
-------- --------
$ 411,046 $ 609,395
========= =========
</TABLE>
17
<PAGE>
BLACK DOME ENERGY CORPORATION
Statement of Income
-------------------
<TABLE>
<CAPTION>
December 31,
-------------------------------
1995 1994 1993
------- ------- -------
<S> <C> <C> <C>
Revenue:
Oil and gas sales $ 402,627 592,513 647,328
Operating income 38,034 19,879 28,402
Gain (loss) on property disposition --- 142,852 ---
Interest income 366 2,413 1,804
Other income (loss) 357 4,998 3
------- ------- -------
441,384 762,655 677,537
------- ------- -------
Costs and expenses:
Oil and gas production 166,262 300,236 249,814
Production and windfall profit taxes 22,737 37,136 44,461
Depreciation, depletion and amortization 199,519 119,218 130,522
Exploration expense 10,110 216 616
Write-off non-productive wells 15,438 65,955 ---
Interest 14,250 17,739 10,200
General and administrative 223,666 266,603 235,586
------- ------- -------
651,982 807,103 671,199
------- ------- -------
Earnings (loss) before income taxes (210,598) (44,448) 6,338
Provision for income tax --- --- 1,000
----- ----- -----
Net earnings (loss) before income
tax benefit (210,598) (44,448) 5,338
Income tax benefit --- --- 1,000
----- ----- -----
Net earnings (loss) $ (210,598) (44,448) 6,338
============ ======== =======
Earnings (loss) per common and common
equivalent share (1) $ (2.86) (.61) .16
========= ======== =======
</TABLE>
(1) Calculated after one-for-1,001 share reverse split
See accompanying notes to financial statements
18
<PAGE>
BLACK DOME ENERGY CORPORATION
Statement of Stockholders' Equity
---------------------------------
<TABLE>
<CAPTION>
Common Stock Total
------------------- Additional Accumulated Stock-
Stated Paid-in Earnings Holder's
Shares Value Capital (Deficit) Equity
------- -------- --------- ---------- --------
<S> <C> <C> <C> <C> <C>
Balance at December
31, 1992 67,500,000 $283,040 1,886,495 (1,844,429) 325,106
Net earnings for the
year ended December
31, 1993 --- --- --- 6,338 6,338
Balance at December
31, 1993 67,500,000 283,040 1,886,495 (1,838,091) 331,444
Stock issued in lieu
of annual compensation 7,500,000 9,375 --- --- 9,375
Reverse split of stock
one-for-1,001 (74,926,545) --- --- --- ---
Net loss for year --- --- --- ( 44,448) (44,448)
Balance at December
31, 1994 73,455 292,415 1,886,496 (1,882,539) 296,371
Stock issued to employees
for bonus 300 --- --- --- ---
Net loss for year --- --- --- (210,590) (210,590)
Balance at December
31, 1995 73,755 $292,415 1,886,495 (2,093,137) 85,773
====== ======== ========= =========== ======
</TABLE>
See accompanying notes to financial statements
19
<PAGE>
BLACK DOME ENERGY CORPORATION
Statement of Cash Flows
-----------------------
<TABLE>
<CAPTION>
December 31,
1995 1994 1993
---------- ----------- ---------
<S> <C> <C> <C>
Cash flows from operating activities:
Net earnings (loss) $ (210,598) (44,448) 6,338
Depreciation, depletion, amortization 199,519 119,218 130,522
(Gain) loss on property dispositions --- (142,852) ---
Changes in assets and liabilities:
(Increase) decrease in receivables 18,056 16,444 15,011
Increase (decrease) in accounts payable (676) (224,815) 78,863
Increase (decrease) in other liabilities 662 --- ---
(Increase) decrease in other assets 2,294 729 3,024
Increase (decrease) in deferred
compensation 60,000 (80,000) 60,000
------ -------- ------
Net cash provided (used) by
operating activities 69,257 (355,724) 293,758
------ --------- -------
Cash flows from investing activities:
Acquisition of properties --- --- (197,580)
Proceeds from property dispositions --- 164,424 7,193
Purchase of equipment (28,598) (59,698) (222,082)
Purchase of well equipment inventory,
net of transfers to wells 8,995 (20,115) 22,336
Write-off non-producing properties 7,662 65,955 ---
-------- -------- --------
Net cash (used in) provided by
investing activities (11,941) 150,566 (390,133)
-------- ------- ---------
Cash flows from financing activities:
Increase (decrease) in line-of-credit (132,724) --- 223,987
Increase (decrease) in notes payable 132,724 --- 2,800
Payments on note payable (47,737) --- ---
Issuance of common stock --- 9,375 ---
Acquisition of Treasury stock --- (8,557) ---
-------- ------- --------
Net cash (used in) provided by
financing activities (47,737) 818 226,787
Increase (decrease) in cash 9,579 (204,340) 130,412
Cash balance at beginning of year 53,429 257,769 127,357
------- -------- -------
Cash balance at end of year $ 63,008 53,429 257,769
========= ======== =======
</TABLE>
See accompanying notes to financial statements
20
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements
December 31, 1995 and 1994
1. Summary of Significant Accounting Policies:
-------------------------------------------
Operations of the company
-------------------------
Black Dome Energy Corporation was incorporated as a Colorado
corporation on December 12, 1979 and was in the development stage
through 1980. The Company is involved in exploration for oil and gas
and the acquisition, development, and operation of oil and gas leasehold
interests.
Property and equipment and depreciation, depletion, and amortization
--------------------------------------------------------------------
The Company follows the successful-efforts method of accounting
for oil and gas exploration and development costs. Under this method,
lease acquisition costs and exploration and development costs
attributable to the finding and development of proved reserves are
capitalized. Exploratory dry hole costs and other nonproductive
oil and gas activities are expensed. Costs of nonproductive
leases are charged to expense when abandoned or substantially impaired,
based upon a property-by-property evaluation. Capitalized costs relating
to producing properties are depleted or depreciated on the units-of-
production method based on the total of proved reserves. Expenditures for
repairs and maintenance costs and delay rentals are charged to expense
as incurred; renewals and betterments are capitalized. The cost and related
accumulate depreciation, depletion, or amortization of property sold or
otherwise retired are eliminated from the accounts; and gains or losses
on dispositions are reflected in the consolidated statement of operations.
Furniture, office equipment, and an automobile are depreciated using the
straight-line method of depreciation over the estimated useful lives of the
assets.
The Company had previously used the straight line method of
depreciation for lease and well equipment, and in 1995, changed to the
units-of-production method. The change resulted in additional depreciation
of $56,525 ($.77 per share) in 1995; $26,999 ($.37 per share) in 1994;
$55,628 ($.76 per share) in 1993; and $26,302 in prior years. The Company's
financial statements have been restated to reflect the changes. The Company
believes that this better reports income to conform to Financial Accounting
Standards Board Statement of Accounting Standards No. 121.
Inventory
---------
Inventory of lease and well equipment is valued at the lower of cost
or market. Cost is determined by either the specific identification method
or average cost method depending on the nature of the inventory item.
Income taxes
------------
The Company accounts for income taxes using tax-liability method in
accordance with Financial Accounting Standards Board Statement No. 109.
The effect of Statement 109 will not have a material effect on the financial
statements of the Company. The benefit of tax carryforwards has not been
recognized because realization is not assured.
Gain (loss) per share
---------------------
Gain (loss) per common share is computed on the basis of the weighted
average number of shares of common stock and common stock equivalents
outstanding during the year.* There were 73,755 shares outstanding at
December 31,1995 and 73,455 at December 31, 1994.
* after allowing for the one-for 1,001 reverse split during in 1994.
21
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements, Continued
December 31, 1995 and 1994
1. Summary of Significant Accounting Policies:
-------------------------------------------
Basis of presentation and going concern
---------------------------------------
The accompanying financial statements have been prepared on a
going-concern basis which contemplates the realization of assets and the
satisfaction of liabilities in the normal course of business. The
financial statements do not include any adjustments relating to the
recoverability and classification of recorded assets amounts or the
amount and classification of liabilities that might be necessary should
the Company be unable to continue as a going concern. The Company's
continuation as a going concern is dependent upon its ability to
generate sufficient cash flow to meet its obligations on a timely
basis, to obtain additional financing as may be required, and to increase
sales to a level where the Company becomes profitable. The Company's
management believes it will be able to attain these goals.
2. Oil and Gas Operations:
-----------------------
Information related to the Company's oil and gas operations
is summarized as follows:
<TABLE>
<CAPTION>
December 31,
1995 1994 1993
----------------------------
<S> <C> <C> <C>
Capitalized costs:
Unproved properties $ --- --- ---
Proved oil and gas properties 885,006 866,280 958,459
------- ------- -------
885,006 866,280 958,459
Accumulated
depletion, depreciation
and amortization 664,012 362,781 336,943
------- ------- -------
$ 220,994 502,499 621,516
======= ======= =======
Costs incurred in oil and gas
producing activities:
Property acquisition costs --- --- 197,580
Exploration costs 10,110 216 616
Production costs 188,999 337,372 294,275
Depreciation, depletion, and
amortization expense 199,519 119,218 130,522
------- ------- -------
$ 398,628 456,806 622,993
======= ======= =======
Sales of oil and gas, net of
production costs $ 213,678 $ 255,141 $ 353,053
======= ======= =======
</TABLE>
3. Income Taxes:
-------------
At December 31, 1995, net operating losses available for federal income
tax purposes total approximately $1,250,000, of which $189,000, $187,000,
$237,000, $151,000, $250,000, $36,000 and $200,000 will expire in 1996,
1997, 1998, 1999, 2000, 2006, and 2007 respectively. Investment tax
credit carryforwards at December 31, 1995, total $13,800 of which,
$8,900, $2,000, $2,800, and $100 will expire in 1996, 1997, 1998, and
1999, respectively, if not utilized.
22
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements, Continued
December 31, 1995 and 1994
4. Employment Contracts:
--------------------
On May 8, 1991, the Company entered into an employment contract with
E.J. Huff as President of Black Dome for a four-year period beginning
January 1, 1991 and ending December 31, 1994. The contract provides for
annual compensation of $9,600 paid currently and $60,000 to be deferred
to the final year of the contract. At December 31, 1994, $240,000 for
the first four years of deferred compensation had been recognized by the
Company and payment of $140,000 had been made. The deferred compensation
is unfunded.
During 1993 and 1994 in lieu of his $9,600 annual compensation and with
approval of the Board of Directors, Mr. Huff accepted 6,800,000 and
7,500,00 restricted (pre reverse split) shares of the Company's no par
value common stock and cash compensation of $1,100.
On December 31, 1994, the Company entered into an employment contract
with E.J. Huff as President of Black Dome for the three years ending
December 31, 1997 with annual compensation of $100,000 for 1995;
$125,000 for 1996 and $150,000 for 1997.
On July 1, 1991, the Company entered into an employment contract with
J.R. Albi, Jr., as Executive Vice President of Black Dome for a three-year
period beginning July 1, 1991 and ending June 30, 1994. The contract
provides for annual compensation of $60,000. Upon execution of the
agreement, Mr. Albi received 7,256,000 pre-split shares of the Company's
common stock valued at $.00125 per share or $9,070. The shares were
restricted for the term of the contract and were forfeitable as follows:
If Mr. Albi left the employ of the Company prior to June 30, 1992, all of
the shares; prior to June 30, 1993, two-thirds of the shares; and prior
to June 30, 1994, one-third of the shares. The contract has been
fulfilled.
5. Major Customers:
---------------
During the year ended December 31, 1995 sales of oil and gas to two
customers totaled approximately $295,000 and $52,000. During the year
ended December 31, 1994, sales of oil and gas to two major customers were
$336,000 and $154,000. During the year ended December 31, 1993, sales of
oil and gas to two customers totaled approximately $132,000 and $242,000.
6. Supplementary Oil and Gas Information (Unaudited):
--------------------------------------------------
Changes in proved oil and gas reserves:
<TABLE>
<CAPTION>
1995 1994
Oil Gas Oil Gas
(Bbls) (Mcf) (Bbls) (Mcf)
------ ----- ------ -----
<S> <C> <C> <C> <C>
Proved reserves:
Balance at beginning of
year 9,355 2,031,425 34,990 2,669,089
Properties sold --- --- (19,247) (227,135)
Additions to and
revisions of previous
estimates 1,852 (286,289) (3,641) (101,313)
Production (1,382) (261,562) (2,747) (309,216)
------ ------- ----- -------
Balance at end of year 9,825 1,483,574 9,355 2,031,425
===== ========= ===== =========
</TABLE>
23
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements
December 31, 1995 and 1994
6. Supplementary Oil and Gas Information (Unaudited), Continued:
-------------------------------------------------------------
<TABLE>
<CAPTION>
<S> <C> <C>
Proved developed reserves:
Balance at December 31, 1993 25,985 2,664,920
Balance at December 31, 1994 9,355 2,031,425
Balance at December 31, 1995 9,825 1,431,318
</TABLE>
Future net cash flows from proved oil and gas reserves:
<TABLE>
<CAPTION>
Future net cash flows at
December 31, 1995
------------------
Total Proved
Proved Developed
Reserves Reserves
---------------------
<S> <C> <C>
December 31,
-----------
1996 $ 306,423 338,801
1997 290,572 271,754
1998 232,079 217,449
Remainder 853,044 814,673
------- -------
$ 1,682,118 $1,642,677
========= =========
</TABLE>
Present value of future net cash flows (discounted at 10%):
<TABLE>
<CAPTION>
Proved
Proved Developed
------ ---------
<S> <C> <C>
December 31,
-----------
1993 2,739,716 2,720,531
1994 1,281,621 1,281,621
1995 1,196,316 1,175,279
</TABLE>
Changes in present value of estimated future net cash flows
from proved oil and gas reserves:
<TABLE>
<CAPTION>
December 31,
------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Present value at beginning of period $ 1,281,621 $ 2,739,716 $ 2,039,192
Additions and revisions, net of
future estimated development and
productions costs and net of
properties sold 128,323 (1,202,954) 1,053,577
Sales of oil and gas, net of
lifting costs (213,628) (255,141) (353,053)
------- ------- -------
Present value at end of period $ 1,196,316 $ 1,281,621 $ 2,739,716
========= ========= =========
</TABLE>
24
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements
December 31, 1995 and 1994
6. Supplementary Oil and Gas Information (Unaudited), Continued:
-------------------------------------------------------------
Summary of oil and gas producing activities on the basis of
reserve recognition accounting:
<TABLE>
<CAPTION>
1995 1994
________ ________
<S> <C> <C>
Additions and revisions to present value
(discounted at 10%) of estimated future
net revenues of proved oil and gas reserves:
Additions, net of estimated future development
and production costs $ 21,037 $ ---
Revisions to estimates of reserves
proved in prior years:
Changes in prices, net of production
costs and taxes 31,256 (66,517)
Other revisions (10,327) (125,100)
Accretion of discount 86,357 (1,011,337)
---------- -----------
Total additions and revisions 128,323 (1,202,954)
Less evaluated acquisition, exploration
and development costs incurred --- ---
--------- --------
Additions and revisions under evaluated
costs 128,323 (1,202,954)
Provision for income taxes --- ---
------- -----------
Results of oil and gas producing activities
on the basis of reserve recognition
accounting $ 128,323 $ (1,202,954)
============ =============
</TABLE>
The following accounting policies have been used in preparing the
Reserve Recognition Accounting (RRA) presentation. The summary of oil and
gas producing activities on the basis of RRA was prepared based on the
rules of the Securities and Exchange Commission (SEC).
Under RRA, earnings are recognized as proved reserves are found based
on the estimated present value of such reserves, computed as described
below. Subsequent revisions to the RRA valuation of proved reserves are
included in earnings as they occur. Proved reserves are those quantities
of oil and gas which can be expected, with little doubt, to be recoverable
commercially at current prices and costs under existing operating methods.
The proved reserves and related valuations were computed by J.R. Albi,
Jr. and audited by Donald M. Osmus, independent petroleum consulting
individual, in accordance with the rules of the SEC. Estimated future
net revenues were computed by applying current prices received by the
Company to estimated future production of reserves, less estimated future
development and production costs and windfall profit taxes based on current
costs. A discount factor of 10% was applied to the estimated future
revenues to compute the estimated present value of proved oil and gas
reserves. This valuation procedure does not necessarily result in an
estimate of the fair market value of the Company's oil and gas properties.
25
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements, Continued
December 31, 1995 and 1994
6. Supplementary Oil and Gas Information (Unaudited), Continued:
-------------------------------------------------------------
Totals of proved reserves are inherently imprecise estimates and are
continually subject to revision based on production history, results of
additional exploration and development, price changes, and other factors.
The pretax income (loss) reflected in the primary financial statements
for oil and gas producing activities corresponds to the pretax income
(loss) on the basis of RRA of $128,323 in 1995 and $(1,202,954) in 1994
and $1,053,577 in 1993, respectively.
"Additions to reserves" are the result of current acquisitions and
development activities. Increases in prices are the approximate effect on
the RRA valuation of proved reserves due to price changes. Other revisions
represent the net effect of all revisions to estimated quantities of proved
reserves. Accretion of discount was computed by multiplying 10% times the
present value of future net revenues as of the beginning of the year,
adjusted to reflect downward revisions.
Evaluated acquisition, exploration, development, and production costs
include current and estimated future costs associated with the current year
reserve additions. Such expenses include property acquisitions, well
costs, lease rentals, and abandonments. The cost of acquiring unproved
properties and drilling exploratory wells are deferred until the properties
are evaluated and determined to be either productive or nonproductive,
at which time they are charged to expense. There were no deferred
acquisition and exploration costs at December 31, 1995 and 1994.
The provision for income taxes is based on the "liability" method
computed by applying the current statutory income tax rate to the
difference between the year end RRA valuation of proved reserves and the
tax basis in the properties less estimated investment tax credits and
statutory depletion associated with future development costs.
7. Commitments and Contingencies:
------------------------------
There were no commitments or contingencies known to management
at December 31, 1995.
8. Related Party Transactions:
---------------------------
On January 27, 1992, the Company issued its one-year note for $35,000
to Clayton Corporation, a company controlled by E.J. Huff, with interest
at 8% per annum. On January 27, 1993, the not was renewed and interest
paid by issuance of a note for $2,800. On January 27, 1994, an additional
note for $2,800 was issued for interest which was included in accrued
interest at December 31, 1993. The notes were paid in full in 1994.
9. Environmental Liabilities:
--------------------------
The company's oil and gas operations are subject to various federal,
state, and local laws and regulations regarding environmental and
ecological matters. These laws and regulations, among other things,
impose liability on the Company, as a lessee under an oil and gas lease
for the cost of pollution clean-up resulting from operations, subject the
lessee to liability for pollution damages, require suspension
or cessation of operations in affected areas and impose restrictions on
the injection of liquids into subsurface aquifers that may contain
groundwater.
As of December 31, 1995, the Company was not aware of any environmental
claims which would have a material impact upon the Company's financial
position or results of operations.
26
<PAGE>
BLACK DOME ENERGY CORPORATION
Notes to Financial Statements, Continued
December 31, 1995 and 1994
10. Reverse stock split and Treasury Stock
--------------------------------------
During 1994, the Company effected a reverse stock split pursuant to
which one new share of the Company's Common Stock was issued in exchange
for each 1,001 shares of the Company's previously outstanding Common
Stock. To the extent that such reverse stock split resulted in any
shareholder owning less than a single full share of the Company's common
stock, the Company paid cash for each such fractional share in an amount
equal to the appropriate fraction of $5.90 per whole share (which
represents the fair value of a whole share after the consummation of the
proposed reverse stock split as determined by the Company's Board of
Directors). To the extent that the proposed reverse stock split
resulted in fractional shares held by persons who owned one or more full
shares of the Company's common stock after consummation of the reverse
stock split, such fractional shares were rounded up or down to the
nearest full share.
27
<PAGE>
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE.
------------------------------------------------------------
None applicable.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT.
- -------- ---------------------------------------------------
The Company's bylaws provide that the Board of Directors shall consist
of not less than three nor more than five members. All members of the
Board of Directors will hold office until the next Annual Meeting of
Shareholders or until their earlier death, resignation or removal.
Executive Officers are elected at the first meeting of the Board of
Directors following the Annual Meeting of Shareholders. It is anticipated
that all of the current officers and directors of the Company will
continue to serve in their present capacities until such time as the next
annual meeting of shareholders is held.
The following table sets forth the name and age of each Executive
Officer and/or Director, indicating all positions and offices with
the Company presently held by him, and the period during which he has
served as an officer or as a member of the Board of Directors:
<TABLE>
<CAPTION>
Period Served
Other Positions and as Officer
Offices Held with or Director
Name Age the Company of the Company
- ------------- --- ---------------------- ----------------
<S> <C> <C> <C>
Edgar J. Huff 72 Chairman of the Board, President and
President and Director, December
Treasurer 1979 to present;
Treasurer,November
1984 to Present
Joseph R. Albi, Sr. 64 None Director, February
1985 to present
Robert C. Huff 45 None Director, November
1987 to present;
Secretary March 1985
to September 2, 1994
James E. Huff 41 None Director, November
1987 to present
Tish M. Hartman 35 Secretary - N/A
September 2, 1994 to
Present
</TABLE>
The principal occupation and employment during the last five years and
business experience of each Executive Officer and/or Director of Black Dome
Energy Corporation, are set forth below.
Page 28
<PAGE>
Edgar J. Huff: President and Chairman of the Board of Directors of
the Company since December, 1979, and Treasurer since November, 1984. Mr.
Huff is also the President and Chief Executive Officer and is one of the
majority stockholders of Clayton Corporation, a family-owned independent
oil and gas company since January, 1972. Mr. Huff is a graduate of Texas
Tech University with a B.S. degree in Petroleum Engineering, and has been
continuously active in the oil and gas industry as a consulting geologist,
petroleum engineer, independent oil operator, Company President and major
stockholder of several oil and gas companies during the period of time
between 1949 to the present.
Joseph R. Albi, Sr.: Member of the Board of Directors of the Company
since February, 1985. Mr. Albi is a graduate of Regis College with a B.S.
degree in Business Administration. He has owned and operated a Denver real
estate development and corporate financial consulting business from 1965 to
the present. Mr. Albi is a former member of the Colorado House of
Representatives, a past Vice President of the Rocky Mountain Better Business
Bureau and was selected by presidential appointment to be the Federal
Region VIII Administrator for the American Revolution Bicentennial
Administration. Mr. Albi served as a member on the Board of Directors of
the Denver Metro Sewer District #1 from 1979 to 1984, and on the Board
of Directors of Energy Resources of North Dakota, Inc. from 1980 until
1985. Mr. Albi is retired with the rank of Brigadier General USAF Reserve
where his position was Mobilization Assistant to the USAF Chief of Security
Police.
Robert C. Huff: Member of the Board of Directors of the Company since
November 1987. Mr. Huff held the position of Secretary of the Company from
March 1985 to September 2, 1994. From June of 1979 through December of 1991,
he was employed in various capacities (most recently as Manager, Facilities
Operations) for Atlantic Richfield Company. From December, 1991 through
November 1993, Mr. Huff was the President and owner of Clayton Consulting,
Inc., a privately-held facilities management consulting firm. From November
of 1993 to October 1995, Mr. Huff served as Facilities Manager with the Dial
Corporation located in Scottsdale, Arizona. Since October 1995 to the
present time, he has been and currently is employed by Hilti Corporation, an
international company with western hemisphere headquarters in Tulsa,
Oklahoma, as Director of Administrative Operations. He is a Certified
Facilities Manager certified by the International Facilities Management
Association ("IFMA"). Mr. Huff is a 1972 graduate of the University of
Colorado with a degree in business, and a 1974 graduate of Colorado State
University with a degree in Industrial Construction Management.
James E. Huff: Member of the Board of Directors of the Company since
November 1987. Mr. Huff worked continuously and extensively in the oil and
gas industry from 1977 to 1986, first as a landman for a major oil and gas
company, and later as an independent landman, consultant and manager of his
own exploration office in North Dallas, Texas. From June 1986 to February
1990 Mr.Huff was employed by Electronic Data Systems Corporation as a
regional marketing director, southwestern region USA, in Plano, Texas. Since
February 1990 Mr. Huff has been employed by Computer Science Corporation in
the Dallas, Texas area. In September 1994, Mr. Huff accepted a transfer
to Houston, Texas where he opened the CSC Consulting office. At the present
time, he is a partner in CSC Consulting and Manager of the CSC Consulting
Houston, Texas office. Mr. Huff graduated from the University of Colorado
in 1977 with a degree in business administration.
Page 29
<PAGE>
Tish M. Hartman: Ms. Hartman has been employed in the oil and gas
industry with Black Dome Energy Corporation since April 18, 1985 in the
capacity of Administrative Assistant to Edgar J. Huff. Ms. Hartman
held the position of Assistant Corporate Secretary from July 22, 1985
to September 1, 1994, and has held the position of Corporate Secretary from
September 2, 1994 through the present. Ms. Hartman does not perform policy
making or similar functions for the Company.
There is no family relationship between any Director or nominee for
Director of the Company and any other Director or Executive Officer of the
Company, except that Messrs. Robert C. Huff and James E. Huff are brothers
and the children of Edgar J. Huff and Mr. Joseph R. Albi, Sr. is the
father of Mr. Joseph R. Albi, Jr.
DIRECTORS' MEETING
During 1995, there were no Directors' meetings held.
ITEM 11. EXECUTIVE COMPENSATION.
- -------- -----------------------
Executive Compensation
- ----------------------
The following tabular information includes all plan and non-plan
compensation paid to the Company's president and all other executive officers
whose total annual salary and bonus is $100,000 or more for the three fiscal
years ended December 31, 1995:
<TABLE>
<CAPTION>
SUMMARY COMPENSATION
Annual Comp. Long-Term Comp.
--------------------------- -------------------
Awards Payouts
--------------
Other Rest. Securities
Name and Annual Stock underlying LTIP All
Principal Salary Bonus Comp. Awards Options Payouts Other
Position Year ($) ($) ($) ($) (#) ($) Comp.
- --------- ---- ------ ----- ---- ------ ---------- ------- -----
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Edgar J. Huff 1995 100,000* 0 0 0 0 0 0
(President, CEO, 1994 60,000(1) 9,600(2) 0 0 0 0 0
Treasurer and 1993 60,000(1) 225(3) 0 9,375(3) 0 0 0
Chairman of the
Board)
Joseph R. Albi, 1995 0(4) 0 0 0(4) 0 0 0
Jr. (Exec. Vice 1994 35,000(4) 0 0 3,023(4) 0 0 0
President) 1993 60,000(4) 0 0 3,023(4) 0 0 0
</TABLE>
* See Employment Contracts and Termination of Employment and Change
of Control Arrangements (Page 33).
(1) On May 11, 1991, the Company entered into a four-year Employment
Contract with Mr. Edgar J. Huff, which provides for deferred compensation of
$60,000 per year to be payable in July 1994 ($180,000). In July 1994,
$140,000 of the $180,000 deferred compensation was paid and $40,000
of the $180,000 compensation was further deferred until 1995. The
Page 30
<PAGE>
$60,000 deferred salary for 1994, and the $9,600 bonus for 1994 due to be
paid in January 1995 have been further deferred, and are carried on the
books of the Corporation as a liability.
(2) Mr. Huff's Employment Contract dated May 11, 1991, also provides
for the payment of an annual bonus in the amount of $9,600. Mr. Huff's 1993
earned bonus of $9,600 was not paid as of December 31, 1993, however it was
paid during fiscal year 1994. During fiscal 1994, Mr. Huff received the
1993 earned bonus which was paid in stock and cash. The earned bonus of
$9,600 for 1994 due in January 1995 has been further deferred.
(3) In 1994, the Board of Directors of the Company authorized the
issuance of 7,500,000 shares of no par value restricted common stock, plus
a cash payment of $225.00 to Mr. Huff as payment of the contractual bonus of
$9,600 earned by Mr. Huff for the calendar year 1993. The Board of Directors
determined the price of $0.00125 per share to be a fair and reasonable
value to the Company for such shares when considering, among other things,
the current net tangible book value of the Company's assets, its existing debt
obligations, the current lack of any existing trading market for the Company's
shares, the absence of any market makers for the Company's shares, the lack
of any ascertainable market value for the Company's common stock, and the
restricted nature of the shares to be issued.
(4) On July 1, 1991, the Company entered into a three-year Employment
Contract with Mr. Joseph R. Albi, Jr. which provides for annual compensation
of $60,000 per year ($5,000/month) and the issuance of 7,256,000 shares of
the restricted no par value Common Stock of the Company valued at $.00125
per share or $9,070. The shares were restricted for the term of Mr. Albi's
contract which began on July 1, 1991 and ended on June 30, 1994 and were
forfeitable as follows: If Mr. Albi left the employ of the Company prior to
June 30, 1992, all of the shares would be forfeited; prior to June 30, 1993,
two-thirds of the shares would be forfeited; and prior to June 30, 1994,
one-third of the shares would be forfeited. Mr. Albi left the employ of the
Company on June 30, 1994 and became vested in the entire 7,256,000 shares
of restricted no par value common stock of the Company.
Page 31
<PAGE>
Compensation of Directors
-------------------------
Standard Arrangements. Directors of the Company receive a fee of $100 per
meeting for their attendance at meetings of the Company's Board of Directors,
and are entitled to reimbursement for reasonable travel expenses. During
1995, no payments were made to the Directors of the Company.
Other Arrangements. There are no other arrangements pursuant to which
the Company's Directors receive compensation from the Company for services
as Directors.
<TABLE>
<CAPTION>
OPTIONS/SAR GRANTS IN LAST FISCAL YEAR
Individual Grants Pot. Realizable
-------------------------------------------- Value at
Number of Assumed Rates of
Securities % of Total Stock Price App.
Underlying Options for Opt. Term.
Options Granted to Exercise Exp. ----------------
Name Granted Employees Price Date 5%($) 10%($)
- -------------- --------- ---------- -------- ---- ----- ------
<S> <C> <C> <C> <C> <C> <C>
Edgar J. Huff 0(1) 0 0 0 0 0
</TABLE>
(1) No stock options have been issued by the Company during 1995. As
of December 31, 1995, the Company does not have a stock option plan
available to any employee and/or director of the Company.
AGGREGATED OPTION EXERCISES IN LAST FISCAL YEAR
AND FISCAL YEAR-END OPTION VALUES
<TABLE>
<CAPTION>
Number of
Securities Value of
Underlying Unexercised
Unexercised In-the-Money
Options at Options at
Shares 12/31/95 12/31/95
Acquired on Value Exercisable/ Exercisable/
Name Exercise(#) Realized($) Unexercisable Unexercisable
- ------------- ----------- ----------- ------------- -------------
<S> <C> <C> <C> <C>
Edgar J. Huff 0(1) 0 0 0
</TABLE>
(1) No stock options were exercised during fiscal year 1995. As of
December 31, 1995, the Company does not have a stock option plan
available to any employee and/or director of the Company.
As of December 31, 1995, the Company does not have an Incentive Stock
Option Plan available to its employees and/or directors.
Page 32
<PAGE>
LONG TERM INCENTIVE PLAN ("LTIP") AWARDS TABLE
The following table sets forth each award made to a named executive
officer in the last completed fiscal year under any LTIP:
LONG-TERM INCENTIVE PLANS - AWARDS IN LAST FISCAL YEAR
<TABLE>
<CAPTION>
Estimated Future Payouts
under Non-Stock Price-Based Plans
---------------------------------
(a) (b) (c) (d) (e) (f)
Number of Performances or
Shares,Units Other Period Until
or Other Maturation or Threshold Target Maximum
Name Rights (#) Payout ($ or #) ($ or #) ($ or #)
- ---- ------------ ------------------ --------- -------- --------
<S> <C> <C> <C> <C> <C>
Edgar J. Huff -0- N/A -0- -0- -0-
</TABLE>
On May 1, 1993, the Board of Directors of the Company adopted an IRS
approved (Model Form 5035-A) Salary Deferred Simplified Employee Pension
Plan (SAR-SEP) allowing eligible salaried employees to contribute (through
elective deferrals) a portion of their salary on a before tax basis to
individual IRA accounts set up on behalf of the Company. Should employee
contributions be such that the Plan is deemed "top-heavy" for any Plan year
(as defined by the IRS), the Company will be required to contribute an
amount to non-key employees (not to exceed 3% of their annual compensation)
for that plan year. During fiscal year ended December 31, 1995, the Company
contributed $666 to the IRA accounts of non-key employees to satisfy "top-
heavy" Plan requirements for the year 1995.
Other Compensation
- ------------------
No other compensation (not covered by the above categories) was paid
or distributed during the last fiscal year to any executive officer of
the Company.
Employment Contracts and Termination of Employment and Change of Control
Arrangements
Effective December 31, 1994, the Board of Directors approved a new
three-year employment agreement with the President of the Company, Mr. Edgar
J. Huff, for his continued services. The Agreement became effective January
1, 1995. It is a standard employment agreement with standard disability,
death and term clauses, providing for a deferred salary of $100,000 for
the year 1995 to be paid on January 5, 1996; a deferred salary of $125,000
for the year 1996 to be paid on January 5, 1997 and a deferred salary of
$150,000 for the year 1997 to be paid on January 5, 1998. The agreement
further provides for the Company to carry insurance on the life of Mr. Huff
in the amount of $250,000. Premiums are to be paid by the Company and
such sum shall be payable to the Company in the event of Mr. Huff's demise
during the term of the Employment Agreement. The Employment Agreement
further provides that, should there not be sufficient cash each year as
provided in the agreement so that the lump sum is not available, then Mr.
Huff may be paid with any class of the Company's stock as may be mutually
agreed between Mr. Huff and the Company; provided, however, that there
shall be deducted from all compensation paid to Mr. Huff, such sums,
including, but without limitation to, social security, income tax withholding
and unemployment insurance, as the Company is by law obligated to do.
Page 33
<PAGE>
The Employment Agreement may be mutually terminated prior to the
maximum period of three (3) years whereupon Mr. Huff shall be entitled to all
current and deferred compensation earned by him to the date of termination.
The Company has no compensatory plan or arrangement, including payments
to be received from the Company, with respect to any individual named
above for the latest or the next preceding fiscal year, if such plan or
arrangement results or will result from the resignation, retirement or any
other termination of such individual's employment with the Company, or
from a change in control of the Company or a change in the individual's
responsibilities following a change in control.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT.
---------------------------------------------------
The following table sets forth as of March 21, 1996, information with
respect to the ownership of the Company's No Par Value Common Stock by each
person, including any "group" as that term is defined in Section 13(d) (3)
of the Securities Exchange Act of 1934, known by the Company to own
beneficially more than five percent of its outstanding equity securities, and
by its Directors and Officers individually and by its Officers and Directors
as a group. Information as to beneficial ownership is based upon statements
furnished to the Company by such persons.
Page 34
<PAGE>
<TABLE>
<CAPTION>
Amount and
Nature of
Name and Address Beneficial Percent
of Beneficial Owner Title of Class Ownership (1) of Class
- ------------------- -------------- ------------- --------
<S> <C> <C> <C>
Edgar J. Huff(2) Common Stock 43,698 59.25%
1536 Cole Blvd., Ste 325 (No Par Value)
Golden, CO 80401
James E. Huff(3) Common Stock 1,099 1.49%
2414 Briar Ridge Dr. (No Par Value)
Houston, TX 77057
Robert C. Huff(3) Common Stock 999 1.35%
9930 S. 87th E. Ave. (No Par Value)
Tulsa OK 74133
Joseph R. Albi, Sr.(3) Common Stock 300 .41%
P.O. Box 5271, T.A. (No Par Value)
Denver, CO 80217
Tish M. Hartman (4) Common Stock 400 .54%
1536 Cole Blvd., Ste 325 (No Par Value)
Golden, CO 80401
Officers and/or Common Stock 46,496 63.04%
Directors as a (No Par Value)
Group (5 persons)
</TABLE>
(1) All beneficial owners have sole voting and investment power
over shares indicated in the table.
(2) President, Treasurer and Director of the Company.
(3) Director of the Company
(4) Corporate Secretary
Edgar J. Huff currently controls the Company by virtue of his ownership
of 59.25% of the Company's outstanding Common Stock. There is no arrangement
known to the Company, including any pledge by any person of securities
of the Company or any of its parents, the operation of which may at a
subsequent date result in a change in control of the Company.
Page 35
<PAGE>
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
- -------- -----------------------------------------------
Transactions with Management and Others
- ---------------------------------------
No Director or Executive Officer of the Company, nominee for election
as a Director, security holder who is known to the Company to own of record
or beneficially more than 5% of any class of the Company's voting securities,
or any relative or spouse of any of the foregoing persons, or any member
of the immediate family of any such persons, has had any transaction, or
series of similar transactions, since the beginning of the Company's last
fiscal year, or has any currently proposed transaction, or series of
similar transactions, to which the Company was or is to be a party, in which
the amount involved exceeds $60,000 and in which any of such persons had or
will have any direct or indirect material interest.
Related Party Transactions
- --------------------------
All cash and note obligations to Clayton Corporation, a company
controlled by Edgar J. Huff, from Black Dome Energy Corporation were paid to
Clayton Corporation in fiscal 1994.
Certain Business Relationships
- ------------------------------
No director or nominee for director is, or during the last fiscal year
has been, an executive officer of, or owns, or during the last fiscal year
has owned, of record or beneficially in excess of ten percent equity
interest in, any business or professional entity that has made during
the Company's current fiscal year, payments to the Company or its subsidiary
for property or services in excess of five percent of (i) the Company's
consolidated gross revenues for its last full fiscal year, or (ii) the other
entity's consolidated gross revenues for its last full fiscal year.
No director or nominee for director is, or during the last fiscal year
has been, an executive officer of or owns, or during the last fiscal year
has owned, of record or beneficially in excess of ten percent equity
interest in, any business or professional entity to which the Company or its
subsidiary has made during the Company's last full fiscal year, or proposes
to make during the Company's current fiscal year, payments for property or
services in excess of five percent of (i) the Company's consolidated
gross revenues for its last full fiscal year, or (ii) the other entity's
consolidated gross revenues for its last full fiscal year.
No director or nominee for director is, or during the last fiscal year
has been, an executive officer of, or owns, or during the last fiscal year
has owned, of record or beneficially, in excess of ten percent equity
interest in, any business or professional entity to which the Company was
indebted at the end of the Company's last full fiscal year in the aggregate
amount in excess of five percent of the Company's total consolidated assets
at the end of such fiscal year.
No director or nominee for director is, or during the last fiscal year
has been, a member of, or of counsel to, a law firm that the Company has
retained during the last fiscal year or proposes to retain during the
current fiscal year where the dollar amount of such fees paid to such law
firm exceeded five percent of such law firm's gross revenues for its past
fiscal year.
Page 36
<PAGE>
No director or nominee for director is, or during the last fiscal year
has been, a partner or executive officer of any investment banking firm that
has performed services for the Company, other than as a participating
underwriter in a syndicate, during the last fiscal year or that the
Company proposes to have performed during the current year.
There are no other relationships that the Company is aware of between
a director or nominee for director and the Company that are substantially
similar in nature and scope to those relationships listed above.
Indebtedness of Management
- --------------------------
No director or executive officer of the Company, nominee for election
as a director, any member of the immediate family of such persons,
corporation or organization (other than the Company or a majority-owned
subsidiary of the Company) of which any of such persons is an executive
officer or partner or is, directly or indirectly, the beneficial owner of
10% or more of any class of equity securities, or any trust or other estate
in which any of such persons has a substantial beneficial interest or as to
which such person serves as a trustee or in a similar capacity, has been
indebted to the Company at any time since the beginning of the Company's
last fiscal year in an amount in excess of $60,000.
Page 37
<PAGE>
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON
FORM 8-K.
------------------------------------------------------
a)(1) The following financial statements are filed as part of this
report:
Report of Independent Certified Public Accountants
Financial Statements:
Balance Sheets, December 31, 1995 and 1994
Statements of Operations for the years ended December 31,
1995, 1994 and 1993
Statement of Shareholders' Equity for the years ended
December 31, 1995, 1994 and 1993
Statement of Cash Flows for the years ended December 31,
1995, 1994 and 1993
Notes to financial statements
Schedule V - Property, Plant and Equipment
Schedule VI - Accumulated Depreciation, Depletion and
Amortization of Property, Plant and Equipment
Schedules other than those listed above have been omitted
since they either are not required or are not applicable.
Form EX-27 - Financial Data Scheudule
Sequential
(a)(3) Exhibits: Page Number
--------- -----------
3 Articles of Incorporation and
Bylaws (incorporated by
reference to Registration
Statement on Form S-1, SEC
File No. 2-67734) --
24 Consent of Joseph R. Albi, Jr. 40
25 Consent of Donald M. Osmus 41
(b) No reports on Form 8-K were filed by Black Dome during the
last quarter of the period covered by this report.
Page 38
<PAGE>
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Company has duly caused this report to be
signed on its behalf by the undersigned, thereunto duly authorized.
(Registrant) BLACK DOME ENERGY CORPORATION
BY (Signature) /s/ Edgar J. Huff
(Date) March 22, 1996
(Name and Title) Edgar J. Huff, President,
Chief Executive Officer,
Chief Financial Officer and
Principal Accounting Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed by the following persons on behalf of the Company
and in the capacities and on the dates indicated.
Name and Capacity
BY (Signature) /s/ Edgar J. Huff, Director
(Date) March 22, 1996
BY (Signature) /s/ Joseph R. Albi, Sr., Director
(Date) March 22, 1996
BY (Signature) /s/Robert C. Huff, Director
(Date) March 22, 1996
BY (Signature) /s/ James E. Huff, Director
(Date) March 22, 1996
Page 39
<PAGE>
Joseph R. Albi, Jr.
P.O. Box 260022
Highlands Ranch, Colorado 80163-0022
March 9, 1996
I, Joseph R. Albi Jr., hereby consent to the use of and/or reference to my
report estimating Black Dome Energy Corporation's reserves and revenues as of
January 1, 1996 in the Annual Report on Form 10-K of Black Dome Energy
Corporation. I also consent to the reference to my name in the Annual Report
on Form 10-K. The estimated reserves and revenues attributable to certain
Black Dome Energy Corporation leasehold presented in my report were based on
an engineering evaluation utilizing data supplied by Black Dome Energy
Corporation.
Sincerly,
/s/ Joseph R. Albi Jr.
Joseph R. Albi Jr.
B.S. Petroleum Engineering
Colorado School of Mines, 1982
M.S. Mineral Economics
Colorado School of Mines, 1986
<PAGE>
Donald M. Osmus
9330 S. Meredith Court
Littleton, Colorado 80124
March 10, 1996
I, Donald M. Osmus, hereby consent to the use of and/or reference to my
report auditing Black Dome Energy Corporation's reserves and revenues as of
January 1, 1996 in the Annual Report on Form 10-K of Black Dome Energy
Corporation. I also consent to the reference to my name in the Annual
Report on Form 10-K. The estimated reserves and revenues attributable to
certain Black Dome Energy Corporation leasehold presented in my audit report
were based on an engineering evaluation prepared by Black Dome Energy
Corporation.
Sincerely,
/s/ Donald M. Osmus
Donald M. Osmus
Petroleum Engineer Consulant
<TABLE> <S> <C>
<PAGE>
<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1995
<PERIOD-END> DEC-31-1995
<CASH> 63,008
<SECURITIES> 0
<RECEIVABLES> 80,130
<ALLOWANCES> 0
<INVENTORY> 44,926
<CURRENT-ASSETS> 143,138
<PP&E> 222,982
<DEPRECIATION> 58,367
<TOTAL-ASSETS> 411,046
<CURRENT-LIABILITIES> 311,739
<BONDS> 0
<COMMON> 73,755
0
0
<OTHER-SE> 0
<TOTAL-LIABILITY-AND-EQUITY> 411,046
<SALES> 402,627
<TOTAL-REVENUES> 441,384
<CGS> 428,316
<TOTAL-COSTS> 651,982
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 14,250
<INCOME-PRETAX> (210,598)
<INCOME-TAX> 0
<INCOME-CONTINUING> 0
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> (210,598)
<EPS-PRIMARY> (2.86)
<EPS-DILUTED> (2.86)
</TABLE>
