UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-KSB/A
(Amendment No. 1)
(Mark One)
[X] Annual Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the fiscal year ended June 30, 2002 or
[ ] Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
Commission File No: 0-9261
KESTREL ENERGY, INC.
(Exact name of registrant as specified in its charter)
State of Incorporation: Colorado I.R.S. Employer Identification No.
84-0772451
999 - 18th Street, Suite 2490
Denver, Colorado 80202
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (303) 295-0344
Securities registered pursuant to Section 12(b) of the Act:
None
Securities registered pursuant to Section 12(g) of the Act:
Title of Each Class
COMMON STOCK, NO PAR VALUE
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.
|X|.... YES .....|_| .....NO
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of the registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-KSB or any
amendment to this Form 10-KSB. [ ]
At August 31, 2002, 9,115,200 common shares (the registrant's only class of
voting stock) were outstanding. The aggregate market value of the 2,773,769
common shares of the registrant held by nonaffiliates on that date (based upon
the mean of the closing bid and asked price on the NASDAQ system) was
$1,164,983.
Documents Incorporated by Reference
Certain portions of the registrant's Proxy Statement relating to the 2002 Annual
Meeting of Shareholders are incorporated by reference into Part III.
1
TABLE OF CONTENTS
PART I.................................................................3
Item 1. Description of Business.......................................3
General Description of Business......................................3
Recent Activities....................................................3
Operations and Policies..............................................4
Risk Factors.........................................................4
Forward-Looking Statements...........................................4
Item 2. Description of Property.......................................7
Oil and Gas Interests................................................7
Royalty Interests Under Producing Properties.........................7
Drilling Activities..................................................7
Farmout Agreements...................................................8
Oil and Gas Production, Prices and Costs.............................8
Customers............................................................8
Office Facilities....................................................8
Item 3. Legal Proceedings.............................................9
Item 4. Submission of Matters to a Vote of Security Holders...........9
PART II................................................................9
Item 5. Market for Registrant's Common Equity and Related Stockholder
Matters.......................................................9
Outstanding Shares of Common Stock...................................9
Stock Price..........................................................9
Dividend Policy.....................................................10
Item 6. Management's Discussion and Analysis of Financial Condition
and Results of Operations....................................10
Liquidity and Capital Resources.....................................10
Results of Operations...............................................12
Item 7. Financial Statements and Supplementary Data..................13
Item 8. Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure.........................................13
PART III..............................................................14
Item 9. Directors and Executive Officers of the Registrant...........14
Item 10. Executive Compensation......................................14
Item 11. Security Ownership of Certain Beneficial Owners and
Management.......................................................14
Item 12. Certain Relationships and Related Transactions..............14
PART IV...............................................................14
Item 13. Exhibits, Financial Statement Schedules and Reports on
Form 8-K.........................................................14
SIGNATURES............................................................17
2
PART I
ITEM 1. DESCRIPTION OF BUSINESS.
GENERAL DESCRIPTION OF BUSINESS
Kestrel Energy, Inc. (the "Company") was incorporated under the laws of the
State of Colorado on November 1, 1978. The Company's principal business is the
acquisition, either alone or with others, of interests in proved developed
producing oil and gas leases, and exploratory and developmental drilling.
At June 30,2002 the Company owned oil and gas interests in the states of
Louisiana, New Mexico, Oklahoma, Texas, South Dakota and Wyoming
RECENT ACTIVITIES
On February 21, 2000, the Company entered into a Line of Credit agreement with
Wells Fargo Bank West N.A., which provided the Company a borrowing base of
$600,000 with interest at Wells Fargo prime rate plus 2.5%. On September 27,
2000, the Company and Wells Fargo amended the Line of Credit Agreement to
provide the Company a borrowing base of $2,000,000 and reduced the interest rate
to 1.5% over prime. In May 2001, the Company restructured its line of credit
agreement with Wells Fargo. Under the prior terms the Company had a borrowing
base of $2,000,000 with interest paid monthly. The new agreement lowered the
borrowing base to $1,400,000 and required the Company to reduce the principal
balance on the line of credit to $1,400,000 by October 31, 2001 with interest on
the outstanding balance paid monthly. The Company reduced the outstanding
balance to $1,396,000 by October 31, 2001. The Company finalized the
restructuring of the line of credit with Wells Fargo in November 2001, which
called for principal payments of $1,340,000 by October 31, 2002. As of June 30,
2002, $516,000 was outstanding on the line of credit. The line of credit was
secured by deeds of trust on various oil and gas producing properties held by
us. On August 6, 2002 the Company entered into a promissory agreement with
Samson Exploration N.L. and borrowed $500,000. Under the terms of the agreement
the Company is required to pay interest at 12% per annum and a financing fee of
10% of the borrowed funds. The duration of the loan is 120 days and is due on
December 4, 2002. The proceeds from the loan were used to retire and satisfy the
outstanding debt to Wells Fargo.
In September 2001, we announced the appointment of Barry D. Lasker as President,
Chief Executive Officer and Director. Mr. Lasker brings to the Company 21 years
of experience in the oil and gas industry. Timothy L. Hoops, our former
President and Chief Executive Officer, now serves as our operations manager, on
a part-time basis and remains a Director of the Company.
In April 2002, the Company completed a private placement of 1,409,000 units at a
price of $0.70 per unit. Each unit consisted of one common share and one common
share purchase warrant. Each of the common share purchase warrants sold in that
offering entitles the holder to acquire an additional common share of the
Company at a price of $1.25 on or before March 10, 2003. The net proceeds of
approximately $950,000 were used for debt consolidation and for general
corporate purposes.
On April 3, 2002, the Company sold, at auction, its over-riding royalty
interests in 20 wells for gross proceeds of $59,700. After expenses of $6,104
the Company received net proceeds of $53,596. On April 30, 2002, the Company
sold, at auction, its interest in 16 wells within the Kinta field, Grady County,
Oklahoma for gross proceeds of $170,000. After expenses of $16,748, the Company
paid all net proceeds of $153,252 directly to Wells Fargo Bank, N.A. on the
previously mentioned line of credit. On June 30, 2002, the Company sold its 36%
working interest in the La Ward North field, Jackson County, Texas for total
proceeds of $50,000. The proceeds from this sale were not received until July,
2002 but were accrued into the year ended June 30, 2002 The aggregate net
proceeds of approximately $257,000 from these asset sales were used for debt
consolidation and for general corporate purposes.
By letter dated February 14, 2002, The Nasdaq Stock Market, Inc. informed
the Company that it did not meet all of the requirements for continued listing
on the SmallCap Market because, as of that date, the Company's stock had traded
below the minimum $1.00 per share requirement for 30 consecutive
3
trading days. The Company was provided 180 calendar days, or until August 13,
2002, to regain compliance with the minimum trading price standard. If
compliance could not be achieved by that date, but the Company met the initial
listing criteria for the SmallCap Market on that date, the Company would receive
an additional 180 calendar day grace period to demonstrate compliance with the
$1.00 per share requirement. On August 14, 2002, Nasdaq informed the Company
that, even though it had not complied with the minimum $1.00 per share trading
requirement by August 13, 2002, because the Company satisfied the initial
listing requirements as of March 31, 2002, it was granted the additional 180
calendar day grace period, or until February 10, 2003, to regain compliance with
the minimum trading price standard. While the Company's stock continues to trade
on the SmallCap Market today, even if the stock price does go above $1.00 for
the minimum 10 consecutive trading days before February 10, 2003 and thereby
eliminates the threat of delisting, the Company cannot guarantee that its stock
will continue to be traded on Nasdaq in the future. If delisting occurs, the
Company's stock could be traded on the OTC Bulletin Board as long as the Company
continues to file its reports with the SEC. Such a change, if it occurs, would
probably reduce the liquidity of the Company's stock which, in turn, may result
in a lower trading price for the stock.
OPERATIONS AND POLICIES
The Company currently is focusing its exploration, acquisition and development
opportunities in areas where it has gained historical knowledge, specifically
within its current project inventory. However, the acquisition, development,
production and sale of oil and gas acreage are subject to many factors outside
the Company's control. These factors include worldwide and domestic economic
conditions; proximity to pipelines; existing oil and gas sales contracts on
properties being evaluated; the supply and price of oil and gas as well as other
energy forms; the regulation of prices, production, transportation and marketing
by federal and state governmental authorities; and the availability of, and
interest rates charged on, borrowed funds.
Historically, in attempting to acquire, explore and drill wells on oil and gas
leases, the Company has often been at a competitive disadvantage since it had to
compete with many companies and individuals with greater capital and financial
resources and larger technical staffs. The Company has in the past sought to
mitigate some of these problems by forming acquisition joint ventures with other
companies. These joint ventures allow the Company access to more acquisition
candidates and enable the Company to share the evaluation and other costs among
the venture partners.
The Company's operations are also subject to various provisions of federal,
state and local laws regarding environmental matters. The impact of these
environmental laws on the Company may necessitate significant capital outlays,
which may materially affect the earnings potential of the Company's oil and gas
business in particular, and could cause material changes in the industry in
general. The Company strongly encourages the operators of the Company's oil and
gas wells to do periodic environmental assessments of potential liabilities. To
date, environmental laws have not materially hindered nor adversely affected the
Company's business. Please see Item 3, Legal Proceedings, however, for a
discussion of potential environmental litigation involving the Company.
The Company has three full-time employees, including the Company's President,
Barry D. Lasker. The Company also hires outside professional consultants to
handle certain additional aspects of the Company's business. Management believes
this type of contracting for professional services is the most economical and
practical means for the Company to obtain such services at this time.
RISK FACTORS
WE MUST CONTINUE TO EXPAND OUR OPERATIONS
Our long term success is ultimately dependent on our ability to expand our
revenue base through the acquisition of producing properties and, to a much
greater extent, by successful results in our exploration efforts. We will need
to continue to raise capital to make additional acquisitions and to make further
investments in our current portfolio of exploration properties. We have made
significant investments in exploration properties in the Western Green River
Basin in Wyoming. There is no assurance that any of these acquisitions or other
acquisitions will be as successful as originally projected. In fact, while we
have
4
already had some measure of success with these acquisitions, we have also
had some disappointments. All of our exploration projects are subject to failure
and the loss of our investment.
PRICES OF OIL AND NATURAL GAS FLUCTUATE WIDELY BASED ON MARKET CONDITIONS AND
ANY DECLINE WILL ADVERSELY AFFECT OUR FINANCIAL CONDITION
Our revenues, operating results, cash flow and future rate of growth are very
dependent upon prevailing prices for oil and gas. Historically, oil and gas
prices and markets have been volatile and not predictable, and they are likely
to continue to be volatile in the future. Prices for oil and gas are subject to
wide fluctuations in response to relatively minor changes in the supply of and
demand for oil and gas, market uncertainty and a variety of additional factors
that are beyond our control, including:
o the strength of the United States and global economy;
o political conditions in the Middle East and elsewhere;
o the supply and price of foreign oil and gas;
o the level of consumer product demand;
o the price and availability of alternative fuels;
o the effect of federal and state regulation of production and
transportation; and
o the proximity of our natural gas to pipelines and their capacity.
WE MUST REPLACE THE RESERVES WE PRODUCE
A substantial portion of our oil and gas properties contain proved undeveloped
reserves. Successful development and production of those reserves cannot be
assured. Additional drilling will be necessary in future years both to maintain
production levels and to define the extent and recoverability of existing
reserves. There is no assurance that our present oil and gas wells will continue
to produce at current or anticipated rates of production, that development
drilling will be successful, that production of oil and gas will commence when
expected, that there will be favorable markets for oil and gas which may be
produced in the future or that production rates achieved in early periods can be
maintained.
THERE ARE MANY RISKS IN DRILLING OIL AND GAS WELLS
The cost of drilling, completing and operating wells is often uncertain.
Moreover, drilling may be curtailed, delayed or canceled as a result of many
factors, including title problems, weather conditions, shortages of or delays in
delivery of equipment, as well as the financial instability of well operators,
major working interest owners and well servicing companies. Our gas wells may be
shut-in for lack of a market until a gas pipeline or gathering system with
available capacity is extended into our area. Our oil wells may have production
curtailed until production facilities and delivery arrangements are acquired or
developed for them.
WE FACE INTENSE COMPETITION
The oil and natural gas industry is highly competitive. We compete with others
for property acquisitions and for opportunities to explore or to develop and
produce oil and natural gas. We have previously formed acquisition joint
ventures with several other companies, including Victoria Petroleum N.L. and
other affiliates, which have allowed us more access to acquisition candidates
and to share the evaluation costs with them. We face strong competition from
many companies and individuals with greater capital, financial resources and
larger technical staffs. We also face strong competition in procuring services
from a limited pool of laborers, drilling service contractors and equipment
vendors.
THE AMOUNT OF INSURANCE WE CARRY MAY NOT BE SUFFICIENT TO PROTECT US
We, our partners, co-venturers and well operators maintain general liability
insurance but it may not cover all future claims. If a large claim is
successfully asserted against us, we might not be covered by insurance, or it
might be covered but cause us to pay much higher insurance premiums or a large
deductible or co-payment. Furthermore, regardless of the outcome, litigation
involving our operations or even insurance companies disputing coverage could
divert management's attentions and energies away from operations. The nature of
the oil and gas business involves a variety of operating hazards such as
5
fires, explosions, cratering, blow-outs, adverse weather conditions, pollution
and environmental risks, encountering formations with abnormal pressures, and,
in horizontal wellbores, the increased risk of mechanical failure and collapsed
holes, the occurrence of any of which could result in substantial losses to us.
OUR SUCCESS MAY BE DEPENDENT ON OUR ABILITY TO RETAIN BARRY LASKER AND BOB PETT
AS KEY PERSONNEL
We believe that the oil and gas exploration and development and related
management experience of our key personnel is important to our success. The
active participation in the Company of our president, Barry Lasker and Robert J.
Pett, our chairman is a necessity for our continued operations. We do not have
any employment contracts with these individuals and we do not carry key person
life insurance on their lives. We compete with bigger and better financed oil
and gas exploration companies for these individuals. Our future success may
depend on whether we can attract, retain and motivate highly qualified
personnel. We cannot assure you that we will be able to do so.
OUR RESERVES ARE UNCERTAIN
Estimating our proved reserves involves many uncertainties, including factors
beyond our control. Our annual report on Form 10-KSB for fiscal year 2002
contains estimates of our oil and natural gas reserves and the future cash flow
to be realized from those reserves for fiscal years 2002, 2001 and 2000, as
prepared by our independent petroleum engineers, Sproule Associates Inc. There
are uncertainties inherent in estimating quantities of proved oil and natural
gas reserves since petroleum engineering is not an exact science. Estimates of
commercially recoverable oil and gas reserves and of the future net cash flows
from them are based upon a number of variable factors and assumptions including:
o historical production from the properties compared with production from
other producing properties;
o the effects of regulation by governmental agencies;
o future oil and gas prices; and
o future operating costs, severance and excise taxes, abandonment costs,
development costs and workover and remedial costs.
GOVERNMENTAL REGULATION, ENVIRONMENTAL RISKS AND TAXES COULD ADVERSELY AFFECT
OUR OIL AND GAS OPERATIONS IN THE UNITED STATES
Our oil and natural gas operations in the United States are subject to
regulation by federal and state government, including environmental laws. To
date, we have not had to expend significant resources in order to satisfy
environmental laws and regulations presently in effect. However, compliance
costs under any new laws and regulations that might be enacted could adversely
affect our business and increase the costs of planning, designing, drilling,
installing, operating and abandoning our oil and gas wells and other facilities.
Additional matters that are, or have been from time to time, subject to
governmental regulation include land tenure, royalties, production rates,
spacing, completion procedures, water injections, utilization, the maximum price
at which products could be sold, energy taxes and the discharge of materials
into the environment.
FORWARD-LOOKING STATEMENTS
This prospectus contains forward-looking statements. We use words such as
"anticipate", "believe", "expect", "future", "may", "will", "should", "plan",
"intend", and similar expressions to identify forward-looking statements. These
statements are based on our beliefs and the assurances we made using information
currently available to us. Because these statements reflect our current views
concerning future events, these statements involve risks, uncertainties and
assumptions. Our actual results could differ materially from the results
discussed in the forward-looking statements. Some, but not all, of the factors
that may cause these differences include those discussed in the risk factors in
this prospectus. You should not place undue reliance on these forward-looking
statements. You should also remember that these statements are made only as of
the date of this prospectus and future events may cause them to be less likely
to prove to be true.
6
ITEM 2. DESCRIPTION OF PROPERTY.
OIL AND GAS INTERESTS
The following table describes the Company's leasehold interests in developed and
undeveloped oil and gas acreage at June 30, 2002:
Total Total
----- -----
Developed Acreage (1)(2) Undeveloped Acreage (1)(2)
State Gross Net Gross Net
----- ----- --- ----- ---
Louisiana 480 365 -0- -0-
New Mexico 240 91 320 87
Oklahoma 1,567 451 -0- -0-
South Dakota 160 20 -0- -0-
Texas 993 13 -0- -0-
Wyoming 10,863 3,226 33,654 33,654
------ ----- ------ ------
TOTAL 14,303 4,166 33,974 33,741
Canada -0- -0- -0- -0-
(1) Gross acres are the total acreage involved in a single lease or group of
leases. Net acres represent the number of acres attributable to an owner's
proportionate working interest in a lease (e.g., a 50% working interest in a
lease covering 320 acres is equivalent to 160 net acres).
(2) The acreage figures are stated on the basis of applicable state oil and gas
spacing regulations.
ROYALTY INTERESTS UNDER PRODUCING PROPERTIES
At June 30, 2002, the Company held overriding royalty interests ranging from
1.5% to 9.26% in 23 producing oil and gas wells located on 3,034 gross developed
acres in the United States. This compares with overriding royalty interest
ranging from .013% to 9.26% in 124 producing oil and gas wells located on 6,019
gross developed acres in the U.S at June 30, 2001. The net production for the
royalty interests for the year ended June 30, 2002 were 329 Bbls and 640 Mcf for
oil and gas respectively. The net production for the Company's royalty interests
for the fiscal year ended June 30, 2001 was, 502 Bbls and 558 Mcf for oil and
gas respectively. The royalty interests are considered to be immaterial by the
Company.
DRILLING ACTIVITIES
The Company has not participated in drilling any wells in the year ended June
30, 2002.
Kestrel Energy, Inc. owned interests in net exploratory and net development
wells for the years ended June 30, 2002, and 2001 as set forth below. This
information does not include wells drilled under farmout agreements.
United States
-------------
6/30/02 6/30/01
Net Exploratory Wells: (1)
Dry (2) - -
Productive (3) - -
----- -----
- -
===== =====
Net Development Wells: (1)
Dry (2) - -
Productive (3) 1.76
----- -----
- 1.76
=============
7
(1) A net well is deemed to exist when the sum of fractional ownership working
interests in gross wells equals one. The number of net wells is the sum of
the fractional working interests owned in gross wells expressed as whole
numbers and fractions thereof.
(2) A dry well (hole) is a well found to be incapable of producing either oil
or natural gas in sufficient quantities to justify completion as an oil or
natural gas well.
(3) Productive wells are producing wells and wells capable of production,
including wells that are shut-in.
FARMOUT AGREEMENTS
Under a farmout agreement, outside parties undertake exploration activities
using prospects owned by Kestrel. This enables the Company to participate in the
exploration prospects without incurring additional capital costs, although with
a substantially reduced ownership interest in each prospect.
During the year ended June 30, 2002, no wells were drilled under farmout
agreements.
OIL AND GAS PRODUCTION, PRICES AND COSTS
As of June 30, 2002, the Company had a royalty and/or working interest in 93
gross (3.5 net) wells that produce oil only, 36 gross (9.7 net) wells that
produce gas only, and 22 (1.3 net) wells that produce both oil and gas. All
wells that produced gas are connected to pipelines. As of June 30, 2001, the
Company had a royalty and/or working interest in 74 gross (10.06 net) wells that
produce oil only, 51 gross (11.21 net) wells that produce gas only, and 229
(6.62 net) wells that produce both oil and gas. All wells that produced gas are
connected to pipelines.
For information concerning the Company's oil and gas production, estimated oil
and gas reserves, and estimated future cash inflows relating to proved oil and
gas reserves, see Note 8 to the consolidated financial statements included in
Item 7 of this Report. The reserve estimates for the reporting year were
prepared by Sproule Associates Inc., an independent petroleum engineering firm.
The Company did not file any oil and gas reserve estimates with any federal
authority or agency during its fiscal year ended June 30, 2002.
For the year ended June 30, 2002, the Company's average operating cost
(including taxes and marketing) per barrel of oil equivalent (BOE) (converting
gas to oil at 6:1) was $9.42. The average operating cost per BOE on an
equivalent basis for fiscal years 2001 was $11.96. The average sales price per
barrel of oil sold was $19.99 for 2002, $28.18 for 2001 and $24.78 for 2000. The
average sales price per mcf of gas sold was $2.16 for 2002, $4.75 for 2001 and
$2.59 for 2000.
CUSTOMERS
During fiscal year 2002, the Company had two major customers: Kaiser Francis Oil
Company and Duke Energy. Sales to these customers accounted for 27% and 13%,
respectfully, of oil and gas sales in 2002. The Company does not believe that it
is dependent on a single customer. The Company has the option at most properties
to change purchasers if conditions so warrant.
OFFICE FACILITIES
The Company's executive offices are located at 999 18th Street, Suite 2490,
Denver, Colorado 80202, which is comprised of approximately 3,953 square feet,
at an annual rate of $73,900. The Company's current lease obligation expires
February 28, 2003. The Company also has, under sublease, approximately 781
square feet of office space located at 1502 Augusta Drive, Suite 316, Houston,
Texas 77057, at a monthly rate of $781. The current sublease obligation expires
June 30, 2003.
8
ITEM 3. LEGAL PROCEEDINGS.
In the ordinary course of conducting its business, the Company becomes involved
in litigation, administrative proceedings and governmental investigations,
including environmental matters.
In May of 2000, the Company received a notice letter from the U.S. Environmental
Protection Agency (EPA) stating that the Company is a potentially responsible
party under the federal Comprehensive Environmental Response, Compensation and
Liability Act of 1980 ("CERCLA") for the Casmalia Waste Disposal Site in Santa
Barbara County, California. If the Company is ultimately determined to be a
responsible party, it may be obligated to conduct remedial investigations,
feasibility studies, remediation and/or removal of alleged releases of hazardous
substances or to reimburse the EPA for such activities.
The Company does not believe that it has any liability under CERCLA for wastes
disposed at Casmalia and believes that the EPA's notice was issued in error. The
Company has responded to the EPA, explaining that the Company did not arrange to
dispose of any waste at Casmalia. The Company's involvement with Casmalia is
limited to the purchase of assets from another entity, which disposed of waste
at Casmalia. The Company intends to defend allegations of its responsibility, if
any, and will also rely upon an indemnification given by the previous owner of
the properties at Casmalia, which previous owner has confirmed that the
indemnification would apply to any such allegations.
The Company is unable to estimate the dollar amount of exposure to loss in
connection with the above-referenced matter; however, the ultimate site-wide
clean up costs, which could be borne by the persons or entities found to be
responsible parties, have been estimated by the EPA at approximately $271.9
million.
It is the opinion of Company's management that the outcome of these proceedings,
individually or in the aggregate, will not have a material adverse effect on the
Company's financial position, results of operations, or cash flows.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.
None.
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS.
OUTSTANDING SHARES OF COMMON STOCK
The Company's common stock trades over-the-counter on the NASDAQ SmallCap Market
under the symbol "KEST." At June 30, 2002, the Company had 9,115,200 shares
outstanding. At June 30, 2002, the Company had approximately 1,323 shareholders
of record, although the Company believes that there are more beneficial owners
of its stock, the number of which is unknown.
STOCK PRICE
These quotations reflect inter-dealer prices, without retail mark-up, markdown
or commission and may not necessarily represent actual transactions.
9
FISCAL YEAR JUNE 30, 2001 Sales Price
-----------
High Low
---- ---
First Quarter $3.43 $1.38
Second Quarter 2.41 1.56
Third Quarter 2.00 1.06
Fourth Quarter 1.89 .75
FISCAL YEAR JUNE 30, 2002 Sales Price
-----------
High Low
---- ---
First Quarter $1.58 $0.69
Second Quarter 1.02 0.64
Third Quarter .80 0.56
Fourth Quarter 1.24 0.17
DIVIDEND POLICY
While there are no covenants or other aspects of any finance agreements or
bylaws that restrict the declaration or payment of cash dividends, the Company
has not paid any dividends on its common stock and does not expect to do so in
the foreseeable future.
ITEM 6. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS.
LIQUIDITY AND CAPITAL RESOURCES
Working Capital and Cash Flows: Net working capital deficit at June 30,
2002, was $631,012 compared to a working capital deficit of $1,750,853 at June
30, 2001. The reduction in working capital of $1,119,841 resulted from issuance
of stock and sales of securities in Victoria Petroleum, NL. In April 2002, the
Company completed a private placement of 1,409,000 units at a price of $0.70 per
unit. Each unit consisted of one common share and one common share purchase
warrant. Each of the common share purchase warrants sold in that offering
entitles the holder to acquire an additional common share of the Company at a
price of $1.25 on or before March 10, 2003. The Company also sold 41,900,000
shares of common stock of Victoria Petroleum, NL during fiscal 2002. The common
stock was acquired as part of the merger with Victoria Petroleum, NL in May of
2000. The Company received $603,824 in proceeds from the sale and recorded a
loss of $561,282.
The decrease in working capital of $1,002,021 for the year ended 2001 resulted
from short term borrowings on the Company's line of credit which allowed the
Company to re-complete the Greens Canyon 27-3 well and to fund the drilling of
two development wells in Oklahoma and six development wells in Wyoming.
Net cash used by operating activities was $444,362 for fiscal 2002 as compared
to cash used by operating activities of $994,010 for fiscal 2001, a decrease of
$549,648. The decrease in operating cash flows is primarily attributable to a
loss on the sale of the Victoria Petroleum shares, a higher accounts payable and
lower receivable position at the end of fiscal 2002. The decrease in operating
cash flows for fiscal 2001 was primarily attributable to the reduction of
accounts payable from fiscal 2000 levels.
Net cash provided by investing activities was $564,959 in fiscal 2002 as
compared to net cash used $1,270,999 in fiscal 2001. For the year ended June 30,
2002, $92,461 was used for capital expenditures including $50,954 on completion
of coalbed methane wells in Campbell County, Wyoming. A work-over was completed
on the Pierce Waterflood Unit also in Campbell County, Wyoming, in the amount of
$19,025. The Company also received $603,824 from the sale of 41,900,000 Victoria
Petroleum, NL shares during the fiscal year ended June 30, 2002. The shares were
acquired in May 2000 as part of the
10
merger agreement between the Company and Victoria Petroleum, NL. The sale
resulted in a loss of $561,282. The unrealized gain or loss on the Company's
investment in Victoria Petroleum, NL shares is recorded as Other Accumulated
Comprehensive Income or Loss on the Company's balance sheet as of June 30, 2002.
Proceeds from the sale of several non-core assets during the year netted the
Company approximately $257,000. Of this amount, $53,596 was accounted for under
Investing Activities, $153,252 was accounted for as repayment of debt and
$50,000 was accrued as accounts receivable.
Net cash used by financing activities was $183,074 for fiscal 2002 versus
$1,882,000 provided by financing activities a year ago. Of the cash used during
the fiscal year 2002, $1,212,748 repaid a portion of the Company's line of
credit with Wells Fargo Bank. Under the terms of the agreement, the Company had
a revolving line of credit with a borrowing base of $1,400,000. The Company
restructured the line of credit with Wells Fargo Bank in November 2001, which
required the Company to make scheduled principal payments to reduce the amount
outstanding by $1,400,000 by the October 31, 2002 due date with interest on the
outstanding balance paid monthly. The Company reduced the outstanding balance to
$1,396,000 by October 31, 2001. The Company finalized the restructuring of the
line of credit with Wells Fargo in November 2001, which called for principal
payments of $1,340,000 by October 31, 2002. As of June 30, 2002, $516,000 was
outstanding on the line of credit. In April 2002, the Company closed one private
offering of 1,409,000 units of its common stock at $0.70 per unit. Each unit
consisted one share of common stock and one warrant to purchase one share at
$1.25 for a period of 12 months. This offering netted proceeds to the Company of
$963,624 after offering and related expenses of $22,676. Of this, the Company
issued 515,000 shares of stock to a unrelated party in exchange for previously
recorded advances and accrued interest of $360,500 by Victoria Petroleum, N.L.,
an affiliated company ("VP"), which had transferred the debt to the unrelated
party. The Company also issued 20,000 shares of stock to an officer for $14,000.
Of the total net proceeds from this placement of $611,800 was accounted for as
cash proceeds and $350,000 was accounted for as debt converted to common stock.
The shares sold in the offering were sold to both US and offshore purchasers in
accordance with SEC Regulation S and Regulation D. The Company is seeking to
register the shares for resale in the United States by a Form S-3 registration
statement.
The Company was advanced $97,940 for working capital from VP in February, 2002.
The Company also borrowed $255,382 for working capital from a non-affiliated
party in February, 2002, which was repaid in full. The Company borrowed $350,000
from VP during the year. The debt was transferred to an unrelated party and
subsequently converted to stock in the private placement.
Stockholders' Equity: Stockholders' equity decreased $7,690,466 to
$3,066,167 from $10,756,633 a year ago. The decrease is largely attributable to
an increase in impairment to $6,589,695 which was significantly attributable to
a write down in the value of Greens Canyon gas reserves primarily due to
significantly lower gas prices received at Greens Canyon at the end of fiscal
2002. At June 30, 2002 gas prices were $1.45 per Mcf as compared to gas prices
at the end of fiscal 2001 of $2.55 per Mcf.
Debt Obligations: The Company had no long-term debt at June 30, 2002 or
2001.
Reserves and Future Cash Flows: For the fiscal year ended June 30, 2002,
the Company's proved oil reserves decreased approximately 82,600 bbls. to
273,400 bbls., or 23%, from 356,000 in 2001. The Company's proved gas reserves
decreased 1,315 Mmcf to 12,069 Mmcf, or 10%, from 13,384 Mmcf in 2001. The
decrease in proved reserves is attributable primarily to production during the
year, the sale of several non-core producing assets and lower oil and natural
gas prices for the fiscal year ended June 30, 2002.
The Company's undiscounted net future cash flows have been estimated by Sproule
Associates Inc., an independent petroleum engineering firm, to be approximately
$18,641,000 as of June 30, 2002. This compares to $27,647,000 as of June 30,
2001. The decrease in the current year is the result of revisions of previous
quantity estimates and lower oil and natural gas prices.
Gas Balancing: At June 30, 2002, the Company held no under-produced or
over-produced properties. The Company at June 30, 2001 was under-produced by
approximately 22,245 Mcf.
11
Natural Gas Sales Contracts: The Company's gas production is generally
sold under short term contracts with pricing set on current spot markets with
adjustments for marketing and transportation costs. All contracts are cancelable
within 30-90 days notice by the Company. The Company has no contracts that are
based on a fixed natural gas price.
Net Operating Loss and Tax Credit Carryforwards: At June 30, 2002, the
Company estimated that, for United States federal income tax purposes, it had
net operating loss carryforwards of approximately $9,794,000. The utilization of
approximately $496,000 of these carryforwards are limited to an estimated
$80,000 annually. Of the balance of the loss carryforwards, $9,298,000 is
available to offset any future taxable income of the Company. If not utilized,
the net operating loss carry forwards will expire during the period from 2003
through 2022.
RESULTS OF OPERATIONS
FISCAL 2002 VS. FISCAL 2001
Net Earnings: The Company reported a net loss of $8,111,561 in fiscal 2002
compared to a net loss of $104,371 in fiscal 2001, which was a increase of
$8,007,190. The net loss in fiscal 2002 is attributable to abandonment and
impaired expenses of $6,589,695, depreciation and depletion expenses of $327,353
and significantly lower oil and gas revenues. The abandonment and impairment
expenses of $6,589,695 was attributable to a write down in value of Greens
Canyon gas reserves primarily due to significantly lower gas prices received at
Greens Canyon at the end of 2002. At June 30, 2002 gas prices were $1.45 per Mcf
as compared to gas prices at the end of fiscal 2001 of $2.55 per Mcf.
Revenue: Revenue from oil and gas sales decreased in fiscal 2002 by
$1,046,463, or 48%, to $1,149,356 versus higher sales volumes for oil and gas.
Average prices per barrel of oil decreased 29% to $19.99 from $28.18 a year ago.
Average prices received per Mcf of gas decreased 54% to $2.16 from $4.75 a year
ago. Sales volumes for oil increased 19% to 22,320 barrels from 18,688 barrels a
year ago. Sales volumes for gas decreased 9% to 320 Mmcf from 350 Mmcf a year
ago.
The Company recorded a gain on sale of property and equipment of $20,278. On
April 3, 2002, the Company sold, at auction, its over-riding royalty interests
in 20 wells for gross proceeds of $59,700. After expenses of $6,104 the Company
received net proceeds of $53,596. On April 30, 2002, the Company sold, at
auction, its interest in 16 wells within the Kinta Field, Grady County, Oklahoma
for gross proceeds of $170,000. After expenses of $16,748 the Company paid all
net proceeds of $153,252 directly to Wells Fargo Bank, N.A. on the previously
mentioned line of credit. On June 30, 2002, the Company sold its 36% working
interest in the La Ward North field, Jackson County, Texas for total proceeds of
$50,000. The proceeds from this sale were not received until July, 2002 but were
accrued into the year ended June 30, 2002. The net proceeds of approximately
$257,000 from these asset sales were used for debt consolidation and for general
corporate purposes.
The Company also sold 41,900,000 shares of common stock of Victoria Petroleum,
NL during fiscal 2002. The common stock was acquired as part of the merger with
Victoria Petroleum, NL in May of 2000. The Company received $603,824 in proceeds
from the sale and recorded a loss of $561,282.
Other income rose $70,897 to $182,038 from $111,141 a year ago. The increase is
attributable to overhead charges to a related party for the use of the Company's
office space and personnel, transportation and gas gathering income, and
adjustment of over-accrued severance taxes.
Lease Operating Expenses: Lease operating expenses decreased $208,317, or
23%, to $712,375 from $920,692 a year ago. The caption "Lease Operating
Expenses" includes not only the direct costs of operating a well, but workover
costs and production taxes. Direct lease expense increased 3% to $590,083 from
$575,296 a year ago. Workover costs decreased 95% to $8,282 from $151,390 last
year. Production taxes decreased 41% to $114,040 from $194,006 a year ago. The
increase in direct lease expenses is attributable to higher lease expenses at
the Pierce Water-flood project in Campbell County, Wyoming. The decrease in
workover expenses is attributable to lower workover costs in the Company's
Greens Canyon Field. The decrease in production taxes was a result of lower oil
and gas revenues. Lease operating costs on a BOE (barrel of oil equivalent)
basis decreased 21% to $9.42 from $11.96 a year ago.
12
Exploration Expenses: Exploration expenses decreased $4,530, or 7%, to
$96,601 from $101,131 in 2001. The decrease in exploration expense continued the
slower pace of the Company's exploration program during fiscal 2002 as the
Company's emphasis has been on reducing the outstanding debt obligation.
Dry Holes, Abandoned and Impaired Properties: Dry holes, abandoned
and impaired property costs were $6,589,695 in fiscal 2002 as compared to
$101,459 a year ago, an increase of $6,488,236. No dry hole costs were recorded
for fiscal 2002 or 2001. No wells were abandoned during fiscal 2002. During
fiscal year 2001, the Company abandoned the Pinon Ridge Prospect in Colorado.
Impairment expenses increased $6,517,226 to $6,589,695 from $72,459 a year ago.
The impairment was a result of the analysis of the Company's Greens Canyon
properties as required by SFAS 121. The impairment of $6,589,695, was
attributable to a write down in value of Greens Canyon gas reserves primarily
due to significantly lower gas prices received at Greens Canyon at the end of
fiscal 2002. At June 30, 2002 gas prices were $1.45 per Mcf as compared to gas
prices at the end of fiscal 2001 of $2.55 per Mcf.
General and Administrative Expense: General and administrative expenses
increased $108,688, or 12%, to $1,007,118 as compared to $898,430 a year ago.
The increase in general and administrative expenses is attributable to higher
legal, accounting, insurance, investor relations and taxation expenses offset by
lower company personnel costs. The Company continues to review ways to reduce
overhead expenses.
Interest Expense: Interest expense totaled $121,655 for the fiscal year
ended June 30, 2002 versus $126,907 a year ago. The interest is attributable to
the line of credit the Company had with Wells Fargo Bank and short term
borrowings from Lakes Oil N.L and Victoria Petroleum, N.L. The Lakes loan has
been satisfied in full, however $53,369 remains owed to VP.
ITEM 7. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
See pages F-1 through F-18 for this information.
ITEM 8. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE.
KPMG LLP was previously the principal accountants for Kestrel Energy, Inc.
On August 22, 2002, that firm's appointment as principal accountants was
terminated and we have engaged Wheeler Wasoff P.C. as principal accountants. The
decision to change accountants was recommended and approved by the audit
committee of the board of directors and the board of directors.
In connection with the audits of the two fiscal years ended June 30, 2001
and the subsequent period through August 22, 2002, there were no disagreements
with KPMG LLP on any matter of accounting principles or practices, financial
statement disclosure, or auditing scope or procedures, which disagreements if
not resolved to their satisfaction would have caused them to make reference in
connection with their opinion to the subject matter of the disagreement.
During the two most recent fiscal years and the subsequent period through
August 22, 2002, we have not consulted with Wheeler Wasoff P.C. regarding (i)
the application of accounting principles to a specified transaction, either
completed or proposed, or the type of audit opinion that might be rendered on
our financial statements.
The audit reports of KPMG LLP on the financial statements of Kestrel
Energy, Inc. as of and for the years ended June 30, 2001 and 2000 did not
contain any adverse opinion or disclaimer of opinion, nor were they qualified or
modified as to uncertainty, audit scope, or accounting principles.
13
PART III
ITEM 9. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT.
The information required herein is incorporated by reference from the
Company's definitive proxy statement for the 2002 annual meeting of
shareholders.
ITEM 10. EXECUTIVE COMPENSATION.
The information required herein is incorporated by reference from the
Company's definitive proxy statement for the 2002 annual meeting of
shareholders.
ITEM 11. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.
The information required herein is incorporated by reference from the
Company's definitive proxy statement for the 2002 annual meeting of
shareholders.
ITEM 12. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
The information required herein is incorporated by reference from the
Company's definitive proxy statement for the 2002 annual meeting of
shareholders.
PART IV
ITEM 13. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K.
(a) Exhibits
Exhibit No. Description
----------- -----------
3.1 Amended and Restated Articles of Incorporation, as filed
with the Secretary of State of Colorado on March 16, 1995,
filed as Exhibit (3)1 to the Annual Report on Form 10-K/A
for the fiscal year ended June 30, 1994 and incorporated
herein by reference.
3.2 Amended and Restated Bylaws, as adopted by the Board of
Directors on January 16, 1995, filed as Exhibit (3)2 to
the Annual Report on Form 10-K/A for the fiscal year ended
June 30, 1994 and incorporated herein by reference.
4.1 The form of common stock share certificate filed as
Exhibits 5.1 to the Registrant's Form S-2 Registration
Statement (No. 2-65317) and Article II of the Registrant's
Articles of Incorporation filed as Exhibit 4.1 thereto, as
amended on March 4, 1994 and filed with the Annual Report
on Form 10-K for the fiscal year ended June 30, 1994 are
incorporated herein by reference.
4.2 Warrant Agreement dated January 18, 2000 with American
Securities Transfer & Trust, Inc. filed as Exhibit 4.1
to the Registrant's Form 8-A Registration Statement
filed January 20, 2000 and incorporated herein by
reference.
14
4.3 Form of Warrant Certificate filed as Exhibit 4.2 to the
Registrant's Form 8-A Registration Statement filed January
20, 2000 and incorporated herein by reference.
10.1 Amended and Restated Incentive Stock Option Plan as
amended March 14, 1995 and filed as Exhibit 10.7 with the
Annual Report on Form 10-K for the fiscal year ended June
30, 1995 and incorporated herein by reference.
10.2 Kestrel Energy, Inc. Stock Option Plan effective as of
December 6, 2001 filed as Exhibit 10.14 to the
Registrant's Form 10-Q for the quarter ended December 31,
2001, and incorporated herein by reference.
10.3 Line of Credit with Norwest Bank, Colorado National
Association dated February 21, 2000 filed as Exhibit 10.1
to the Registrant's Form 10-Q for the period ended March
31, 2000 and incorporated herein by reference.
10.4 Articles of Merger for Kestrel Energy California, Inc.
and Victoria Petroleum USA, Inc. filed as Exhibit 10.2
to the Registrant's Form 10-Q for the period ended
March 31, 2000 and incorporated herein by reference.
10.5 Letter Amendment to Wells Fargo Bank West, N.A. Agreement
dated September 27, 2000 filed as Exhibit 10 to the
Registrant's Form 10-Q for the period ended September 30,
2000 and incorporated herein by reference.
10.6 Articles of Merger for Victoria Exploration, Inc. filed
as Exhibit 10.6 to the Registrant's Form 10-K for the
fiscal year ended June 30, 2001 and incorporated herein
by reference.
10.7 Wells Fargo Bank, N.A. Term Loan Agreement dated
November 29, 2001 filed as Exhibit 10.2 to the
Registrant's Form 10-Q for the period ended December
31, 2001 and incorporated herein by reference
10.8 Promissory Note with Samson Exploration N.L. dated
August 6, 2002 filed as Exhibit 99 to the Registrant's
Form S-3 registration Statement (No. 333-99151) and
incorporated herein by reference.
23.1 Consent of KPMG LLP
23.2 Consent of Wheeler Wasoff, P.C.
23.3 Consent of Sproule Associates Inc.
99.1 Certification of President and Principal Financial
Officer
(b) Financial Statements.
Independent Auditors' Report F-1
Balance Sheets F-3
Statements of Operations and Comprehensive Loss F-4
Statements of Stockholders' Equity F-5
Statements of Cash Flows F-6
Notes to Financial Statements F-7
(c) Reports on Form 8-K.
None
15
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the Registrant has duly caused this report to be signed on its
behalf by the undersigned thereunto duly authorized.
KESTREL ENERGY, INC.
(Registrant)
Date: January 28, 2003 By:/s/Barry D. Lasker
-------------------------------
Barry D. Lasker, President,
Chief Executive Officer,
Principal Financial Officer and
Director
Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following persons on behalf of the Registrant and
in the capacities and on the dates indicated.
Date: January 28, 2003 By:/s/Barry D. Lasker
--------------------------------
Barry D. Lasker, President,
Chief Executive Officer,
Principal Financial Officer and
Director
Date: January 28, 2003 By:/s/Robert J. Pett
--------------------------------
Robert J. Pett, Chairman of
the Board
Date: January 28, 2003 By:/s/Kenneth W. Nickerson
--------------------------------
Kenneth W. Nickerson, Director
Date: January 28, 2003 By:/s/John T. Kopcheff
--------------------------------
John T. Kopcheff, Director
Date: January 28, 2003 By:/s/Mark A. E. Syropoulo
--------------------------------
Mark A. E. Syropoulo, Director
Date: January 28, 2003 By:/s/Timothy L. Hoops
--------------------------------
Timothy L. Hoops, Director
Date: By:
--------------------------------
Neil T. MacLachlan, Director
16
CERTIFICATION
I, Barry D. Lasker, certify that:
1. I have reviewed this annual report on Form 10-KSB/A of Kestrel Energy,
Inc.;
2. Based on my knowledge, this annual report does not contain any untrue
statement of a material fact or omit to state a material fact necessary to make
the statements made, in light of the circumstances under which such statements
were made, not misleading with respect to the period covered by this annual
report;
3. Based on my knowledge, the financial statements, and other financial
information included in this annual report, fairly present in all material
respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this annual report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in
Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:
a) designed such disclosure controls and procedures to ensure that material
information relating to the registrant, including its consolidated subsidiaries,
is made known to us by others within those entities, particularly during the
period in which this annual report is being prepared;
b) evaluated the effectiveness of the registrant's disclosure controls and
procedures as of a date within 90 days prior to the filing date of this annual
report (the "Evaluation Date"); and
c) presented in this annual report our conclusions about the effectiveness of
the disclosure controls and procedures based on our evaluation as of the
Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based on
our most recent evaluation, to the registrant's auditors and the audit committee
of registrant's board of directors (or persons performing the equivalent
function):
a) all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to record,
process, summarize and report financial data and have identified for the
registrant's auditors any material weaknesses in internal controls; and
b) any fraud, whether or not material, that involves management or other
employees who have a significant role in the registrant's internal controls; and
6. The registrant's other certifying officers and I have indicated in this
annual report whether or not there were significant changes in internal controls
or in other factors that could significantly affect internal controls subsequent
to the date of our most recent evaluation, including any corrective actions with
regard to significant deficiencies and material weaknesses.
Date: February 24, 2003
/s/Barry D. Lasker
--------------------------------------
Barry D. Lasker, President,
Chief Executive Officer, Principal
Financial Officer and Director
17
KESTREL ENERGY, INC.
Financial Statements
June 30, 2002 and 2001
(With Independent Auditors' Report Thereon)
INDEPENDENT AUDITORS' REPORT
The Board of Directors and Stockholders
Kestrel Energy, Inc.
We have audited the accompanying balance sheet of Kestrel Energy, Inc. as of
June 30, 2002, and the related statements of operations and comprehensive
(loss), stockholders' equity and cash flows for the year then ended. 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 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 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 audit provides 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 Kestrel Energy, Inc. as of June
30, 2002, and the results of its operations and its cash flows for the year then
ended, in conformity with accounting principles generally accepted in the United
States of America.
Wheeler Wasoff, P.C.
Denver, Colorado
October 3, 2002
F-1
INDEPENDENT AUDITORS' REPORT
The Board of Directors and Stockholders
Kestrel Energy, Inc.:
We have audited the accompanying consolidated statements of operations and
comprehensive income (loss), stockholders' equity and cash flows of Kestrel
Energy, Inc. and subsidiaries for the year ended June 30, 2001. 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 audit.
We conducted our audit 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 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 audit provides a
reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present
fairly, in all material respects, the results of operations and cash flows of
Kestrel Energy, Inc. and subsidiaries for the year ended June 30, 2001, in
conformity with accounting principles generally accepted in the United States of
America.
KPMG LLP
Denver, Colorado
September 14, 2001
F-2
KESTREL ENERGY, INC.
BALANCE SHEET
JUNE 30, 2002
ASSETS
Current assets
Cash and cash equivalents $ 56,548
Accounts receivable 209,016
Other current assets 1,268
------------
Total current assets 266,832
------------
Property and equipment, at cost
Oil and gas properties, successful efforts method of
accounting (note 9)
Unproved 215,892
Proved 11,062,848
Pipeline and facilities 807,851
Furniture and equipment 135,387
------------
12,221,978
Accumulated depreciation and depletion (8,880,924)
------------
Net property and equipment 3,341,054
------------
Investment in related party (note 2) 356,125
------------
$ 3,964,011
============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Line of credit, bank (note 3) $ 516,000
Note payable-related party (note 4) 58,369
Accounts payable-trade 242,207
Accrued liabilities 81,268
------------
Total current liabilities 897,844
------------
Commitments and contingencies (notes 3 and 7)
Stockholders' equity (note 5)
Preferred stock, $1 par value. 1,000,000 shares
authorized; none issued --
Common stock, no par value. 20,000,000 shares
authorized; 9,115,200 shares outstanding 20,043,907
Accumulated other comprehensive (loss) (523,358)
Accumulated (deficit) (16,454,382)
------------
Total stockholders' equity 3,066,167
------------
$ 3,964,011
============
The accompanying notes are an integral part of the financial statements.
F-3
KESTREL ENERGY, INC.
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS)
YEARS ENDED JUNE 30, 2002 AND 2001
2002 2001
------------ -----------
Revenue
Oil and gas sales $ 1,149,356 $ 2,195,819
------------ -----------
Costs and expenses
Lease operating expenses 712,375 920,692
Dry holes, abandoned and impaired properties 6,589,695 101,459
Exploration expenses 96,601 101,131
Depreciation and depletion 327,353 284,710
General and administrative 1,007,118 898,430
Interest expense 121,655 126,907
------------ -----------
Total costs and expenses 8,854,797 2,433,329
------------ -----------
Other income (expense)
Gain on sale of property and equipment 20,278 12,719
Gain (loss) on sale of available-for-sale securities (561,282) 3,440
Interest income 3,728 5,839
Foreign currency exchange (loss) (50,882) --
Other, net 182,038 111,141
------------ -----------
(406,120) 133,139
------------ -----------
Net (loss) (8,111,561) (104,371)
Other comprehensive income (loss) -
Unrealized gain (loss) from available-for-sale securities (549,789) 26,431
------------ -----------
Comprehensive (loss) $ (8,661,350) $ (77,940)
============ ===========
(Loss) per share - basic and diluted $ (1.00) $ (0.01)
============ ===========
Weighted average number of common
shares outstanding - basic and diluted 8,100,292 7,684,110
============ ===========
The accompanying notes are an integral part of the financial statements.
F-4
KESTREL ENERGY, INC.
STATEMENTS OF STOCKHOLDERS' EQUITY
YEARS ENDED JUNE 30, 2002 AND 2001
Accumulated
Common Stock Other
------------------------ Accumulated Comprehensive
Shares Amount (Deficit) Income (Loss)
--------- ------------ ------------- -------------
Balance June 30, 2000 7,680,000 $ 19,044,885 $ (8,238,450) $ --
Adjustment for previously issued and
unrecorded shares (note 5) 200 -- -- --
Common shares issued (note 5) 20,000 24,800 -- --
Stock options issued as compensation -- 3,338
Unrealized gain on securities classified
as available for sale -- -- -- 26,431
Net (loss) -- -- (104,371) --
--------- ------------ ------------- -----------
Balance June 30, 2001 7,700,200 19,073,023 (8,342,821) 26,431
Common shares issued (note 5) 1,415,000 993,560 -- --
Offering costs -- (22,676) -- --
Unrealized (loss) on securities classified
as available for sale -- -- -- (549,789)
Net (loss) -- -- (8,111,561) --
--------- ------------ ------------- -----------
Balance June 30, 2002 9,115,200 $ 20,043,907 $ (16,454,382) $ (523,358)
========= ============ ============= ===========
The accompanying notes are an integral part of the financial statements.
F-5
STATEMENTS OF CASH FLOWS
YEARS ENDED JUNE 30, 2002 AND 2001
2002 2001
------------ -----------
Cash flows from operating activities
Net (loss) $ (8,111,561) $ (104,371)
Adjustments to reconcile net (loss) to net cash
(used) by operating activities
Depreciation and depletion 327,353 284,710
Abandoned and impaired properties 6,589,695 101,459
(Gain) loss on sale of available-for-sale securities 561,282 (3,440)
(Gain) on sale of property and equipment (20,278) (12,719)
Noncash compensation expense for stock options -- 3,338
Stock issued for services and interest 31,760 --
Foreign exchange loss 50,882 --
Other (48,808) --
Changes in operating assets and liabilities, net of dispositions
(Increase) decrease in accounts receivable 119,818 (97,759)
(Increase) decrease in related party receivables -- 524
(Increase) decrease in other current assets 4,689 25,603
Increase (decrease) in accounts payable - trade 120,743 (1,297,965)
Increase (decrease) in accounts payable - related party (26,397) 16,998
Increase (decrease) in accrued liabilities (43,540) 89,612
------------ -----------
Net cash (used) by operating activities (444,362) (994,010)
------------ -----------
Cash flows from investing activities
Capital expenditures (92,461) (1,384,692)
Proceeds from sale of securities 603,824 91,096
Proceeds from sales of property and equipment 53,596 22,597
------------ -----------
Net cash provided (used) by investing activities 564,959 (1,270,999)
------------ -----------
Cash flows from financing activities
Net proceeds from line of credit -- 1,882,000
Repayments to line of credit (1,212,748) --
Proceeds from borrowings 703,322 --
Repayments of borrowings (262,772) --
Proceeds from issuance of common stock 611,800 --
Payment of offering costs (22,676) --
------------ -----------
Net cash (used) provided by financing activities (183,074) 1,882,000
------------ -----------
Net (decrease) in cash and cash equivalents (62,477) (383,009)
Cash and cash equivalents, beginning of year 119,025 502,034
------------ -----------
Cash and cash equivalents, end of year $ 56,548 $ 119,025
============ ===========
Supplemental cash flow information - cash paid for interest $ 104,325 $ 113,084
============ ===========
Supplemental disclosure of noncash investing and financing activities
Common stock issued for property and equipment $ -- $ 24,800
============ ===========
Repayment of debt from sale of properties $ 153,252 $ --
============ ===========
Debt converted to common stock $ 350,000 $ --
============ ===========
Unrealized holding gain (loss) in available-for-sale securities $ (549,789) $ 26,431
============ ===========
The accompanying notes are an integral part of the financial statements.
F-6
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
(A) ORGANIZATION
Kestrel Energy, Inc. (the Company) was incorporated under the laws of
the State of Colorado on November 1, 1978. The Company's principal
business is the acquisition, either alone or with others, of interests
in proved developed producing oil and gas leases, and exploratory and
development drilling.
The Company presently owns oil and gas interests in the states of
Louisiana, New Mexico, Oklahoma, South Dakota, Texas and Wyoming.
Victoria Petroleum N. L. (VP) owns 15% of the common shares of the
Company and the Company owns 4% of VP at June 30, 2002.
(B) PRINCIPLES OF CONSOLIDATION
Up until June 22, 2001, the financial statements included the accounts
of the Company and its wholly-owned subsidiary, Victoria Exploration,
Inc. (Victoria). All significant intercompany accounts and transactions
have been eliminated in consolidation.
On June 22, 2001 (the Effective Date), the Company filed Articles of
Merger of Victoria Exploration, Inc. into Kestrel Energy, Inc. pursuant
to Section 7-111-104 of the Colorado Revised Statutes. In accordance
with the agreement, on the Effective Date, Victoria ceased to exist and
Kestrel Energy, Inc. became the surviving corporation.
(C) 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.
(D) CASH EQUIVALENTS
Cash equivalents consist of certificates of deposit. At June 30, 2002,
$50,000 of the cash equivalent balance is pledged as security in lieu
of posting oil and gas performance bonds in the state of Wyoming. The
funds are restricted as to their use and cannot be accessed by the
Company without the written release by the appropriate jurisdictional
authority. For purposes of the statements of cash flows, the Company
considers all highly liquid investments with original maturities of
three months or less to be cash equivalents.
(E) PROPERTY AND EQUIPMENT
The Company follows the successful efforts method of accounting for its
oil and gas activities. Accordingly, costs associated with the
acquisition, drilling and equipping of successful exploratory wells are
capitalized. Geological and geophysical costs, delay and surface
rentals and drilling costs of unsuccessful exploratory wells are
charged to expense as incurred. Costs of drilling development wells,
both successful and unsuccessful, are capitalized. Upon the sale or
retirement of oil and gas properties, the cost thereof and the
accumulated depreciation or depletion are removed from the accounts and
any gain or loss is credited or charged to operations.
F-7
Depreciation and depletion of capitalized oil and gas properties is
computed on the units-of-production method by individual fields as the
related proved reserves are produced. A reserve is provided for
estimated future costs of site restoration, dismantlement, and
abandonment activities, net of residual salvage value, as a component
of depletion.
Pipeline and facilities are stated at original cost. Depreciation of
pipeline and facilities is provided on a straight-line basis over the
estimated useful life of the pipeline of twenty years.
Furniture and equipment are depreciated using the straight-line method
over estimated lives ranging from three to seven years.
Management periodically evaluates capitalized costs of unproved
properties and provides for impairment, if necessary, through a charge
to operations.
Proved oil and gas properties are assessed for impairment on a
field-by-field basis. If the net capitalized costs of proved properties
exceeds the estimated undiscounted future net cash flows from the
property, a provision for impairment is recorded to reduce the carrying
value of the property to its estimated fair value. The Company recorded
a provision for impairment of its proved oil and gas properties of
approximately $6,558,000 and $101,000 for the years ended June 30, 2002
and 2001, respectively.
(F) GAS BALANCING
The Company uses the sales method of accounting for gas balancing of
gas production. Under this method, all proceeds from production
credited to the Company are recorded as revenue until such time as the
Company has produced its share of related reserves. Thereafter,
additional amounts received are recorded as a liability.
As of June 30, 2002, the Company's gas production is in balance.
(G) INCOME TAXES
The Company accounts for income taxes under the provisions of Statement
of Financial Accounting Standards No. 109 (SFAS 109), Accounting for
Income Taxes. Under the asset and liability method of SFAS 109,
deferred tax assets and liabilities are recognized for the future tax
consequences attributable to differences between the financial
statement carrying amounts of existing assets and liabilities and their
respective tax bases and operating loss and tax credit carryforwards.
Deferred tax assets and liabilities are measured using enacted income
tax rates expected to apply to taxable income in the years in which
those differences are expected to be recovered or settled. Under SFAS
109, the effect on deferred tax assets and liabilities of a change in
income tax rates is recognized in the results of operations in the
period that includes the enactment date.
(H) STOCK-BASED COMPENSATION
In October 1995, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 123, Accounting for
Stock-Based Compensation (SFAS 123), effective for fiscal years
beginning after December 15, 1995. This statement defines a fair value
method of accounting for employee stock options and encourages entities
to adopt that method of accounting for its stock compensation plans.
SFAS 123 allows an entity to continue to measure compensation costs for
these plans using the intrinsic value based method of accounting as
prescribed in Accounting Pronouncement Bulletin Opinion No. 25,
Accounting for Stock Issued to Employees (APB 25). The Company has
elected to continue to account for
F-8
its employee stock compensation plans as prescribed under APB 25. The
pro forma disclosures of net loss and loss per share required by SFAS
123 are included in note 5.
(I) (LOSS) PER SHARE
Basic (loss) per share is based on the weighted average number of
common shares outstanding during the period.
Diluted (loss) per share is computed by adjusting the weighted average
number of common shares outstanding for the dilutive effect, if any, of
stock options and warrants.
At June 30, 2002 and 2001, all outstanding options were excluded from
the computation of diluted loss per share for the years then ended. The
effect of the assumed exercises of these options was antidilutive.
(J) REVENUE RECOGNITION
Sales of oil and gas production are recognized at the time of delivery
of the product to the purchaser.
(K) TRANSLATION OF FOREIGN CURRENCIES
Monetary items are translated at the rate of exchange in effect at the
balance sheet date. Non-monetary items are translated at average rates
in effect during the period in which they were earned or incurred.
Gains and losses resulting from the fluctuation of foreign exchange
rates have been included in the determination of income.
(L) MARKETABLE SECURITIES
The Company accounts for investments in marketable securities under
SFAS 115, "Accounting for Certain Investments in Debt and Equity
Securities." The Company determines the appropriate classification at
the time of purchase. Securities are classified as held-to-maturity
when the Company has the positive intent and ability to hold the
securities to maturity. Held-to-maturity securities are stated at cost,
adjusted for amortization of premiums and discounts to maturity.
Marketable securities not classified as held-to-maturity are classified
as available-for-sale. Available-for-sale securities are carried at
fair value, which is based on quoted prices. Unrealized gains and
losses, net of tax, are reported as a separate component of
shareholders' equity. The cost of securities available-for-sale is
adjusted for amortization of premiums and discounts to maturity.
Interest and amortization of premiums and discounts for all securities
are included in interest income. Realized gains and losses are included
in other income. Cost of securities sold is determined on a specific
identification basis.
(M) FAIR VALUE
The carrying amount reported in the balance sheet for cash, accounts
receivable, accounts payable and accrued liabilities approximates fair
value because of the immediate or short-term maturity of these
financial instruments.
(N) CONCENTRATION OF CREDIT RISK
Financial instruments which potentially subject the Company to
concentrations of credit risk consist of cash. The Company maintains
cash accounts at two financial institutions. The Company periodically
evaluates the credit worthiness of financial institutions, and
maintains cash accounts only in large high quality financial
institutions, thereby minimizing exposure for
F-9
deposits in excess of federally insured amounts. The Company believes
that credit risk associated with cash is remote.
(O) RECENT ACCOUNTING PRONOUNCEMENTS
In June 2001, the Financial Accounting Standards Board ("FASB"), issued
SFAS 143, Accounting for Asset Retirement Obligations. SFAS 143
addresses financial accounting and reporting for obligations associated
with the retirement of tangible long-lived assets and the associated
asset retirement costs. SFAS 143 generally requires obligations
associated with asset retirements to be recognized earlier and
displayed as liabilities rather than as contra-assets. The
pronouncement is effective for financial statements issued for fiscal
years beginning after June 15, 2002. Management does not believe that
the adoption of SFAS 143 will have any impact on its financial position
or results of operations.
In August 2001, FASB issued SFAS 144, Accounting for the Impairment or
Disposal of Long-Lived Assets. SFAS 144 addresses financial accounting
and reporting for the impairment or disposal of long-lived assets. SFAS
144 establishes a single accounting model for long-lived assets to be
disposed of by sale. The pronouncement is effective for financial
statements issued for fiscal years beginning after December 15, 2001.
Management does not believe that the adoption of SFAS 144 will have any
impact on its financial position or results of operations.
In June 2002, FASB issued SFAS 146, Accounting for Costs Associated
with Exit or Disposal Activities. SFAS 146 addresses financial
accounting and reporting for costs associated with exit or disposal
activities and nullifies Emerging Issues Task Force Issue No. 94-3,
Liability Recognition for Certain Employee Termination Benefits and
Other Costs to Exit an Activity. SFAS 146 generally requires a
liability for a cost associated with an exit or disposal activity to be
recognized and measured initially at its fair value in the period in
which the liability is incurred. The pronouncement is effective for
exit or disposal activities initiated after December 31, 2002.
Management does not believe that the adoption of SFAS 146 will have any
impact on its financial position or results of operations.
(P) RECLASSIFICATION
Certain amounts in the 2001 financial statements have been reclassified
to conform to the 2002 financial statement presentation.
(2) INVESTMENT IN RELATED PARTY
On May 5, 2000, the Company sold six international permits, with a net book
value of $143,179, for petroleum drilling in Western Australia and New
Guinea to Victoria Petroleum USA, Inc. (VP/USA), a Colorado corporation and
wholly owned subsidiary of VP, in exchange for 8,250,000 shares of VP
Common Stock. The stock was valued at $0.029 per share and resulted in a
gain on the sale of $97,721. The investment is recorded at cost.
Also, on May 5, 2000, KEC, VP and VP/USA entered into an Agreement and Plan
of Merger (Merger Agreement). Pursuant to the Merger Agreement, on May 12,
2000, the Company, as sole shareholder of KEC, acquired 66,750,000 shares
of VP common stock and VP/USA acquired all of the issued and outstanding
shares of KEC through a merger of KEC into VP/USA, with KEC as the
surviving corporation. The stock was valued at $0.029 per share and
resulted in a gain on the sale of $1,497,208, based upon sales of other
assets totaling $242, accounts payable totaling $2,000, and property and
equipment with a net book value of $454,899. The investment is recorded at
cost.
During the year ended June 30, 2002, the Company sold a total of 41,900,000
shares of VP stock and recorded a loss on the sale of $561,282.
F-10
As a result of the above transactions, the Company owns 4% of VP at June
30, 2002.
(3) LINE OF CREDIT
On February 21, 2000, the Company entered into a $2,000,000 Line of Credit
agreement with Wells Fargo Bank, formerly Norwest Banks Colorado, N.A.,
which provided the Company with an initial borrowing base of $600,000,
based on reserves with interest at Wells Fargo's prime rate plus 2.5%. On
September 27, 2000, the Company and Wells Fargo amended the Line of Credit
Agreement to provide the Company with a borrowing base of $2,000,000 and
reduced the interest rate to 1.5% over the Wells Fargo prime rate. On May
31, 2001, Wells Fargo reduced the borrowing base to $1,400,000. On October
31, 2001, Wells Fargo and the Company amended the Term Loan Agreement to
extend the maturity date by 30 days to November 30, 2001. On November 30,
2001, the Company entered into a new Term Loan Agreement with Wells Fargo
in the amount of the existing balance of the old Line of Credit,
$1,396,000, with interest at Wells Fargo's prime rate plus 1.75%. Terms of
the Agreement require periodic payments of varying amounts to pay off the
entire balance by the maturity of the Agreement, November 30, 2002. The
line of credit is secured by Deeds of Trust on various oil and gas
producing properties held by the Company. As of June 30, 2002, $516,000 was
outstanding on the line of credit.
Subsequent to June 30, 2002, the line of credit was paid in full and
retired by applying proceeds of $50,000 from the sale of oil and gas
properties and obtaining a new loan in the amount of $500,000 (See note
10).
(4) NOTES PAYABLE
On February 14, 2002, the Company borrowed $97,940 from VP and $255,382
from Lakes Oil N.L. ("Lakes") due May 15, 2002 with interest at 8%. The
loans were secured by shares of VP and seismic data owned by the Company.
As of June 30, 2002, an aggregate $294,953 had been repaid by the Company
and VP is owed $58,369.
VP advanced an additional $350,000 to the Company with interest at 7.5%.
The loan of $350,000 was assigned to an unrelated company and subsequent
converted, including interest of $10,500, to 515,000 shares of the
Company's common stock.
(5) STOCKHOLDERS' EQUITY
(A) PREFERRED STOCK
The Company is authorized to issue up to 1 million shares of $1 par
value preferred stock, the rights and preferences of which are to be
determined by the Board of Directors at or prior to the time of
issuance.
(B) COMMON STOCK
On January 18, 2000, the Board of Directors of the Company declared a
dividend distribution of 10 Warrants for every 100 shares of
outstanding common stock of the Company held of record by the
shareholders at the close of business on February 4, 2000 (record
date). The Warrant Certificates were only issued in increments of 10
Warrants based upon a rounding of individual shareholders' record
holdings. No Warrants were issued to shareholders holding less than 100
shares as of the Record Date.
Each Warrant entitled the registered holder to purchase from the
Company one share of Common Stock at a price of $3.125 per share,
subject to adjustment. The Warrants were to expire on February 4, 2001.
On January 24, 2001 the Board of Directors reduced the exercise
F-11
price to $2.50 and extended the exercise period to September 4, 2002.
On January 24, 2002, the Board of Directors reduced the exercise price
to $1.25 and extended the exercise period to March 10, 2003.
In April 2001, the Company paid $6,000 and issued 20,000 shares of its
common stock at $1.24 per share to an unrelated third party in exchange
for geophysical data.
During 2001, certificates for previously issued shares of the Company's
common stock, representing 200 shares were presented for transfer.
Prior to presentment, such shares had not been recorded as issued by
the Company.
In July 2001, the Company issued 6,000 shares of its common stock at
$1.21 per share to an unrelated third party in exchange for geophysical
services.
In April 2002, the Company completed a private offering of 1,409,000
units at $.70 per unit. Each unit consisted of one share of common
stock and one warrant to purchase an additional share of common stock
for a period of 12 months, at $1.25 per share. Net cash proceeds to the
Company from the sale of 874,000 units was $589,124 after offering and
related expenses of $22,676. Additionally, 20,000 units were issued to
the Company's President in exchange for $14,000 due for unreimbursed
expenses and 515,000 units were issued in exchange for debt and related
interest in the aggregate amount of $360,500 (See note 4).
(C) STOCK OPTION PLANS
The Company has reserved 36,000 shares of its no par common stock for
key employees of the Company under its 1993 Amended Restated Stock
Incentive Plan (the Incentive Plan). Under the terms of the Incentive
Plan, no stock options are exercisable more than ten years after the
date of grant (five years after date of grant for 10% shareholders). As
of June 30, 1998, all 36,000 options had been granted under the
Incentive Plan.
The Company has reserved 75,000 shares of its no par common stock for
employees, officers, directors, consultants and advisors of the Company
under its 1993 Nonqualified Stock Option Plan (the Nonqualified Plan).
Under the terms of the Nonqualified Plan, no stock options are
exercisable more than ten years after the date of grant (five years
after date of grant for 10% shareholders).
During fiscal 1998, the Company merged the Incentive Plan and the
Nonqualified Plan into the Stock Option Plan (the Plan). The Company
has reserved 1,200,000 shares of its no par common stock for employees,
officers, directors, consultants and advisors of the Company under the
Plan. Under the terms of the Plan, no stock options are exercisable
more than ten years after the date of grant (five years after date of
grant for 10% shareholders).
During fiscal 2002 and 2001, the Board of Directors granted options to
purchase shares of common stock to key employees and directors pursuant
to the Plan. The exercise prices of the options range from $.68 to
$1.15 per share. The options granted are exercisable upon issuance.
On December 1, 1998, the Board of Directors reduced the number of
options outstanding and repriced certain options. The exercise prices
of the repriced options range from $1.875 to $2.00 per share. The
options are immediately exercisable.
On December 6, 2001, the Plan was amended to increase the number of
shares reserved under the Plan to 2,233,000.
The Company applies APB Opinion 25 and related interpretations in
accounting for its plan. Accordingly, no compensation cost has been
recognized for stock options granted at or above
F-12
market value at the date of the grant to key employees and directors.
Compensation expense of $3,338 has been recorded during fiscal 2001,
for options granted below the market value, based on the difference
between the option price and the quoted market price at the date of
grant. Had compensation cost for the Company's stock-based
compensation plans been determined based on the fair value at the
grant dates for awards under those plans consistent with the method
prescribed in SFAS 123, the Company's net (loss) and (loss) per share
would have been increased to the pro forma amounts indicated below:
Years ended June 30,
--------------------------
2002 2001
------------ -----------
Net (loss)
As reported $ (8,111,561) $ (104,371)
Pro forma (8,558,645) (346,240)
(Loss) per share
As reported (1.00) (0.01)
Pro forma (1.06) (0.05)
The fair value of each option grant is estimated on the date of grant
using the Black-Scholes option-pricing model with the following
assumptions used for grants in fiscal 2002 and 2001 respectively: no
dividend yield for all years; expected volatility of 83% and 146%;
weighted average risk-free interest rates of 4.35% and 5.36%; and
expected lives of ten and seven years.
A summary of the status of the Company's fixed stock options plan as of
June 30, 2002 and 2001, and changes during the years then ended is
presented below:
2002 2001
------------------ ------------------
Weighted Weighted
Average Average
Exercise Exercise
Fixed Options Shares Price Shares Price
-------- -------- --------- --------
Outstanding at
beginning of
year 1,148,964 $ 1.58 1,133,964 $ 1.60
Granted 545,000 .99 135,000 1.85
Exercised -- -- -- --
Cancelled -- -- -- --
Expired -- -- (120,000) 2.14
--------- ------ --------- ------
Outstanding at end
of year 1,693,96 $ 1.39 1,148,964 $ 1.58
========= =========
Options exercisable
at year end 1,688,964 1,123,964
Weighted average
fair value of
options granted
during the year $ .82 $ 1.79
Weighted average
remaining contractual life 6.6 6.3
(6) INCOME TAXES
At June 30, 2002 and 2001, the Company's significant deferred tax assets
and liabilities are as follows:
F-13
2002 2001
----------- -----------
Deferred tax assets:
Net operating loss carryforwards $ 3,820,000 $ 3,383,000
Depletion carryforwards 203,000 225,000
Oil and gas properties, principally due
to differences in depreciation,
depletion and impairment 2,850,000 30,000
----------- -----------
6,873,000 3,638,000
Deferred liabilities:
Oil and gas properties, principally due
to differences in depreciation,
depletion and impairment (570,000) (564,000)
----------- -----------
(570,000) (564,000)
----------- -----------
Valuation allowance (6,303,000) (3,074,000)
----------- -----------
Net deferred tax assets $ -- $ --
=========== ===========
The valuation allowance for deferred tax assets as of June 30, 2002 was
$6,303,000. The net change in the valuation allowance for the year ended
June 30, 2002 was an increase of $3,229,000.
At June 30, 2002, the Company had net operating loss carryforwards of
approximately $9,794,000. The utilization of approximately $496,000 of
these loss carryforwards is limited to an estimated $80,000 per year as a
result of a change of ownership which occurred June 30, 1994. Of the
balance of the net operating loss carryforwards, $9,298,000 is available to
offset future taxable income of the Company. If not utilized, the tax net
operating losses will expire during the period from 2003 through 2022.
Income tax expense is different from amounts computed by applying the
statutory federal income tax rate due primarily to the change in valuation
allowance for net deferred tax assets and the expiration of tax
carryforwards.
(7) LEASE COMMITMENTS
The Company has noncancelable operating leases, primarily for rent of
office facilities that expire over the next five years. Rental expense for
operating leases was $83,377 and $73,903 for the years ended June 30, 2002
and 2001, respectively.
F-14
Future minimum rental commitments under noncancelable operating leases as
of June 30, 2002 are as follows:
Fiscal year:
2003 $ 55,704
2004 1,929
---------
$ 116,320
=========
(8) CONTINGENCIES
In the ordinary course of conducting its business, the Company becomes
involved in litigation, administrative proceedings and governmental
investigations, including environmental matters.
In May 2000, the Company received a notice letter from the U.S.
Environmental Protection Agency (EPA) stating that the Company is a
potentially responsible party under the federal Comprehensive Environmental
Response, Compensation and Liability Act of 1980 (CERCLA) at the Casmalia
Waste Disposal Site in Santa Barbara County, California. If the Company is
ultimately determined to be a responsible party, it may be obligated to
conduct remedial investigations, feasibility studies, remediation and/or
removal of alleged releases of hazardous substances or to reimburse the EPA
for such activities.
The Company does not believe that it has any liability under CERCLA for
wastes disposed at Casmalia and believes that the EPA's notice was issued
in error. The Company has responded to the EPA, explaining that the Company
did not arrange to dispose of any waste at Casmalia. The Company's
involvement with Casmalia is limited to the purchase of assets from another
entity, which disposed of waste at Casmalia. The Company intends to defend
allegations of its responsibility, if any, and will also reply upon an
indemnification given by the previous owner of the properties at Casmalia,
which previous owner has confirmed that the indemnification would apply to
any such allegations.
The Company is unable to estimate the dollar amount of exposure to loss in
connection with the above-referenced matter; however, it has been estimated
that the ultimate site-wide clean up costs will be approximately $271.9
million.
It is the opinion of Company's management that the outcome of these
proceedings, individually or in the aggregate, will not have a material
adverse effect on the Company's financial position, results of operations
or cash flows.
F-15
(9) DISCLOSURES ABOUT CAPITALIZED COSTS, COSTS INCURRED AND MAJOR CUSTOMERS
Capitalized costs related to oil and gas producing activities are as
follows:
June 30,
2002 2001
Unproved - Domestic $ 215,892 217,941
Proved 11,062,848 12,398,775
-------------------------
11,278,740 12,616,716
Accumulated depletion and impairment (8,685,589) (3,039,413)
-------------------------
$ 2,593,151 9,577,303
=========================
Costs incurred in oil and gas producing activities for the years ended June
30, 2002 and 2001 were approximately as follows:
2002 2001
------- -------
Unproved property acquisition costs $ -- 13,557
Proved property acquisition costs 257 38,594
Development costs 87,087 523,668
Exploration costs 96,601 654,035
During fiscal 2002, the Company had two major customers. Sales to those
customers accounted for approximately 27% and 13% of fiscal 2002 oil and
gas sales. During fiscal 2001, the Company had two major customers. Sales
to these customers accounted for approximately 26% and 15% of fiscal 2001
oil and gas sales.
During fiscal 2002, the Company spent approximately $51,000 converting
proved undeveloped reserves at Amber field (1 well) into proved producing
reserves. During fiscal 2001, the Company spent approximately $514,000
converting proved undeveloped reserves at Amber field (2 wells) and
Wagensen Waterflood field (4 wells) into proved producing reserves.
(10) SUBSEQUENT EVENT
On August 6, 2002, the Company borrowed $500,000 from Samson Exploration
N.L. ("Samson"), due December 4, 2002, or at any other date agreed to by
the parties, with interest at 10%. The Company agreed to pay $50,000 as a
financing fee to Samson. Proceeds from the loan were used to repay the
Company's outstanding balance on its line of credit to Wells Fargo (See
note 3).
Samson owns 15% of the common shares of the Company.
(11) INFORMATION REGARDING PROVED OIL AND GAS RESERVES (UNAUDITED)
The information presented below regarding the Company's oil and gas
reserves were prepared by independent petroleum engineering consultants.
All reserves are located within the continental United States.
Proved oil and gas reserves are the estimated quantities of crude oil,
natural gas and natural gas liquids which geological and engineering data
demonstrate with reasonable certainty to be recoverable in future years
from known reservoirs under existing economic and operating conditions.
F-16
Proved developed oil and gas reserves are those expected to be recovered
through existing wells with existing equipment and operating methods. The
determination of oil and gas reserves is highly complex and interpretive.
The estimates are subject to continuing changes as additional information
becomes available.
Estimated net quantities of proved developed and undeveloped reserves of
oil and gas for the years ended June 30, 2002 and 2001, are as follows:
2002 2001
--------------------- ---------------------
OIL GAS OIL GAS
(BBLS) (MCF) (BBLS) (MCF)
------- ---------- ------- -----------
Beginning of year 356,000 13,384,000 388,000 24,517,000
Revisions of previous
quantity estimates (17,000) (611,000) (13,000) (12,739,000)
Extensions, discoveries
and improved recovery -- -- -- 1,956,000
Sales of reserves in place (42,000) (351,000) -- --
Production (24,000) (353,000) (19,000) (350,000)
------- ---------- ------- -----------
End of year 273,000 12,069,000 356,000 13,384,000
======= ========== ======= ===========
Proved developed
reserves - end of year 201,000 4,992,000 283,000 6,189,000
======= ========== ======= ===========
STANDARDIZED MEASURE OF DISCOUNTED FUTURE
NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES
Future net cash flows presented below are computed using year-end prices
and costs. Future corporate overhead expenses and interest expense have not
been included.
2002 2001
------------ ------------
Future cash inflows $ 32,752,000 $ 46,149,000
Future costs:
Production (9,386,000 (13,843,000)
Development (4,725,000) (4,659,000)
------------ ------------
Future net cash flows 18,641,000 27,647,000
10% discount factor (9,743,000) (13,822,000)
------------ ------------
Standardized measure of discounted
future net cash flows $ 8,898,000 $ 13,825,000
============ ============
To achieve the 2003 future cash inflows, the capital expenditure of
approximately $1.7 mm in fiscal 2003 and $1.7 mm in fiscal 2004 will be
required to develop existing proved undeveloped reserves.
The principal sources of changes in the standardized measure of discounted
future net cash flows during the years ended June 30, 2002 and 2001, are as
follows:
F-17
2002 2001
------------ ------------
Beginning of year $ 13,825,000 $ 36,003,000
Sales of oil and gas produced during
the period, net of production costs (437,000) (1,275,000)
Net change in prices and production
costs (3,688,000) (16,108,000)
Changes in estimated future
development costs (66,000) 3,319,000
Extensions, discoveries and improved
recovery -- 1,852,000
Revisions of previous quantity
estimates and other (864,000) (13,566,000)
Sales of reserves in place (1,255,000) --
Purchase of reserves in place -- --
Accretion of discount 1,383,000 3,600,000
------------ ------------
End of year $ 8,898,000 $ 13,825,000
============ ============
The standardized measure of discounted future net cash flows relating to
proved oil and gas reserves and the changes in standardized measure of
discounted future net cash flows relating to proved oil and gas reserves
were prepared in accordance with the provisions of SFAS 69. Future cash
inflows were computed by applying current prices at year-end to estimated
future production. Future production and development costs are computed by
estimating the expenditures to be incurred in developing and producing the
proved oil and gas reserves at year-end, based on year-end costs and
assuming continuation of existing economic conditions. Future income tax
expenses are calculated by applying appropriate year-end tax rates to
future pretax net cash flows relating to proved oil and gas reserves, less
the tax basis of properties involved and tax credits and loss carryforwards
relating to oil and gas producing activities. Future net cash flows are
discounted at a rate of 10% annually to derive the standardized measure of
discounted future net cash flows. This calculation procedure does not
necessarily result in an estimate of the fair market value or the present
value of the Company's oil and gas properties.
The complete definition of proved oil and gas reserves appears at
Regulation S-X 4-10(a)(2), 17 CFR 210.4-10(a)(2). The complete definition
of proved developed oil and gas reserves appears at Regulation S-X
4-10(a)(3), 17 CFR 210.4-10(a)(3). The complete definition of proved
undeveloped reserves appears at Regulation S-X 4-10(a)(4), 17 CFR
210.4-10(a)(4).
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