FIRST CALGARY PETROLEUMS LTD - Final Results First Calgary
Petroleums Ltd. Reports Year End Results TSX: FCP LSE: FPL CALGARY,
March 31 /CNW/ - First Calgary Petroleums Ltd. ("FCP" or the
"Company") is pleased to report the financial results of the
Company for the year ended December 31, 2004. A press release
regarding the Company's December 31, 2004 reserves estimates will
be issued later today. Management's Discussion and Analysis The
discussion and analysis that follows is intended to provide a
summary of First Calgary Petroleums Ltd.'s (FCP or the Company)
activities and results over the past two years as well as its
financial position and future prospects. It should be read in
conjunction with the audited financial statements for the years
ended December 31, 2004 and 2003. All numbers in this discussion
and analysis are expressed in U.S. dollars unless otherwise
indicated. Additional information is available on FCP's website at
www.fcpl.ca or on SEDAR's website at www.sedar.com. Background
First Calgary Petroleums Ltd. is an international oil and gas
exploration company with operations in the Ledjmet Block 405b and
the Rhourde Yacoub Block 406a, both of which are situated in the
prolific hydrocarbon bearing Berkine Basin of Algeria. FCP's
Algerian hydrocarbon agreements provide the Company five year
periods to explore the blocks. Following the exploration periods,
the Company will have exploitation rights for any commercial oil
and gas discoveries that extend from 15 to 30 years. With FCP being
in the fourth and fifth years of its Block 405b and Block 406a
exploration periods, respectively, the Company's primary objective
has been to grow its reserves by exploring the blocks as
extensively as possible. Since acquiring the blocks, the Company
has: - Acquired approximately 2,000 km(2) of 3D seismic data
providing complete coverage of FCP's lands; - Drilled six
successful exploration wells; - Drilled six successful appraisal
wells; and - Assembled a portfolio of exploration and appraisal
drilling targets. Success of an exploration company is measured by
the growth in its reserves. FCP's success with the drill bit has
resulted in exponential reserves growth. Given the Company's
drilling success and early stage of reserves development, FCP has
retained Lehman Brothers Europe Limited and Canaccord Capital
Corporation to assist the Company in seeking and evaluating
strategic alternatives. Hydrocarbon Agreements FCP operates in
Algeria where it has the rights to explore and appraise two large
acreage blocks, Ledjmet Block 405b and Rhourde Yacoub Block 406a.
The Company's rights and obligations are set out in hydrocarbon
agreements with Sonatrach, the national oil company of Algeria,
which represents the interest of the state. The hydrocarbon
agreements require FCP to conduct certain drilling and seismic
activities over periods of time. The exploration and appraisal
phases of the agreements that extend for five years are divided
into two periods with each period containing a minimum work
commitment. In each agreement, the first period was for three
years, and the Company then had the option to enter a second
exploration period of two years. Following the exploration and
appraisal phase of each agreement, the Company and Sonatrach will
obtain exploitation permits for any reserves determined to be
commercial and all lands not subject to an exploitation permit will
be returned to the government. Ledjmet Block 405b On Block 405b,
FCP is party to a Production Sharing Contract (PSC) with Sonatrach.
The PSC allocates hydrocarbon production between FCP and Sonatrach
in accordance with a sliding scale formula based on such factors as
production levels, product prices and project investment. Pursuant
to the formula, the Company's annual share of production may range
from 27.72 percent to 8.16 percent. All Algerian state royalties
and income taxes are paid by Sonatrach from its share of
hydrocarbon production. The first exploration period ended in
December 2004 with the Company having completed all of its work
commitments. FCP has committed to the two year second exploration
period of the PSC. The remaining work commitment for the second
exploration period includes drilling one exploration well prior to
December 2006, estimated to cost $9 million. If the Company fails
to satisfy this work obligation, the rights, other than for which
an exploitation permit has been granted or requested, will be
returned and FCP will be liable to pay Sonatrach a penalty of $6.25
million. At the end of the first exploration period, the Company
was required by the PSC to relinquish 30 percent of the Block's
acreage back to Sonatrach. Rhourde Yacoub Block 406a On Block 406a,
FCP has a Joint Venture Agreement (JVA) with Sonatrach. The JVA
allocates 49 percent of the hydrocarbon production or equivalent
volume thereof to the Company. FCP is responsible for paying
Algerian state royalties and income taxes on its share of
production. A portion of the total recoverable natural gas reserves
above a certain threshold will be considered strategic reserves and
excluded by Algerian law from the JVA. The Company is in the second
exploration period of the JVA, which will end in November 2005. The
remaining second exploration period work commitment is the drilling
of two exploration wells prior to November 2005. The cost of this
commitment is estimated at $18 million. If the Company fails to
satisfy this work obligation, the rights, other than for which an
exploitation permit has been granted or requested, will be returned
and the Company will be liable to pay Sonatrach a penalty of $12.75
million. Operations and Capital Expenditures Ledjmet Block 405b To
date, FCP has acquired 3D seismic data over the entire Block (1,100
km(2)), drilled eleven wells and completed preliminary
commercialization studies on the MLE field. The work completed to
date on Block 405b far exceeded the first exploration period
minimum work obligation. This level of activity was undertaken
based upon the drilling success realized and to enable the Company
to fully evaluate the exploration potential of the entire Block
within the five year exploration window provided by the PSC. During
2003, FCP's activity focused on appraising the MLE discovery and
investigating the exploration potential of the Block's acreage to
the west of the MLE discovery with 3D seismic. The Company: -
Completed and tested the MLE-2 appraisal well; - Drilled, completed
and tested the MLE-3 appraisal well; - Commenced drilling
operations on the MLE-4 and MLE-5 appraisal wells; and - Acquired
600 km(2) of 3D seismic immediately adjacent to and west of the MLE
field. During 2004, FCP undertook an aggressive exploration
drilling programme and further 3D seismic acquisition over the
remainder of the Block's western acreage. The Company: - Completed
and tested the MLE-4 and MLE-5 appraisal wells; - Drilled,
completed and tested five exploration wells; LEC-1, MZLN-1, LES-1,
MZLS-1 and LEW-1; - Drilled the LES-2 appraisal well and commenced
drilling operations on the MLE-6 appraisal well; and - Acquired 550
km(2) of 3D seismic. Subsequent to December 31, 2004, FCP completed
testing the LES-2 appraisal well and completed drilling the MLE-6
appraisal well. Readers are referred to the map of Ledjmet Block
405b which is available on the Company's website at www.fcpl.ca.
FCP's 2005 capital programme for Block 405b currently includes
completion and testing of the LES-2 well and drilling the MLE-6
well, projected to cost approximately $9 million. Following
completion of the strategic alternatives assessment, the Company
will review its capital programme for the remainder of 2005. FCP
has identified a number of exploration and appraisal drilling
locations that could be pursued during 2005. Rhourde Yacoub Block
406a In 2004, FCP drilled its first discovery on the Rhourde Yacoub
Block 406a, ZCH-1. Encouraged by the ZCH-1 results, FCP commenced a
613 km(2) 3D seismic programme on the Block to delineate the size
of the structure and define both appraisal and further exploration
drilling locations. Readers are referred to the map of Yacoub Block
406a which is available on the Company's website at www.fcpl.ca.
For 2005, the capital programme currently includes completion of
the 2004 3D seismic programme and the drilling of at least two
exploration wells. The two exploration locations have been
confirmed, site preparation is in progress and drilling operations
are scheduled to commence in April. The 2005 capital expenditure
budget for the Block is estimated at $20 million. Capital
Expenditures The Company's 2004 capital expenditures, excluding
non-cash acquisitions, on Blocks 405b and 406a totaled $108.6
million compared to $46.2 million in 2003 reflecting the increased
number of wells drilled and seismic data acquired. CAPITAL
EXPENDITURES (000's) 2004 2003
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Drilling, completion and testing $ 91,595 $ 36,971 Geological and
geophysical 10,690 7,466 In-country management and administration
5,193 1,400 MLE commercialization 823 42 Training bonuses 308 328
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$ 108,609 $ 46,207
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A number of factors impact the Company's capital costs. Factors
affecting the drilling costs include the well location and access,
surface condition, well depth and availability of services and
supplies. Ongoing drilling costs are expected to range between $6
and $8 million per well for well depths ranging from 3800 to 4500
metres. Testing and completion costs have averaged $2 to $3 million
per well due to multiple zones being tested and to maximize the
data collected. Seismic costs are impacted by the size of the
programme, location, surface condition and availability of
services. Reserves Independent reservoir engineers have estimated
the Company's December 31, 2004 recoverable proved, probable and
possible petroleum and natural gas reserves as follows: December
31, 2004 ----------------------------------------------------------
Gross Recoverable FCP Net Recoverable Reserves Reserves
---------------------------------------------------------- Oil,
Oil, Condensate Total Gas Condensate Total Gas Gas and LPG
Equivalent Gas and LPG Equivalent --- ------- ---------- ---
------- ---------- (Bcf) (MMBbls) (Bcfe) (Bcf) (MMBbls) (Bcfe)
Proved Undeveloped 609 77 1,073 152 22 284 Probable 1,556 249 3,050
201 49 496
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Proved and Probable 2,165 326 4,123 353 71 780 Possible 4,825 676
8,880 567 128 1,335
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Proved, Probable and Possible 6,990 1,002 13,003 920 199 2,115
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December 31, 2003
---------------------------------------------------------- Gross
Recoverable FCP Net Recoverable Reserves Reserves
---------------------------------------------------------- Oil,
Oil, Condensate Total Gas Condensate Total Gas Gas and LPG
Equivalent Gas and LPG Equivalent --- ------- ---------- ---
------- ---------- (Bcf) (MMBbls) (Bcfe) (Bcf) (MMBbls) (Bcfe)
Proved Undeveloped 441 52 753 110 13 187 Probable 1,192 148 2,080
153 19 269
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Proved and Probable 1,633 200 2,833 263 32 456 Possible 2,218 326
4,177 288 43 547
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Proved, Probable and Possible 3,851 526 7,010 551 75 1,003
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Notes: (1) The gross and net recoverable reserves volumes are
estimated under the constant price case. (2) FCP's net reserves
allocations are based upon the terms of the contracts relating to
each block. The Ledjmet Block 405b reserves allocation is
calculated annually based upon a sliding scale formula that
considers capital investment, production levels and product prices.
Accordingly, the net allocation can vary annually and will be
dependent upon the costs, production levels and product prices
realized. For Rhourde Yacoub Block 406a, FCP is allocated the
equivalent of 49% of the gross production on an equivalent barrel
basis. (3) Gas equivalent units have been calculated by the Company
at one barrel (Bbl) for six thousand cubic feet of natural gas
equivalent. Using gas equivalent units may be misleading,
particularly if used in isolation. A conversion ratio of one barrel
to six thousand cubic feet of natural gas is based on an energy
equivalency conversion method primarily applicable at the burner
tip and does not represent a value equivalency at the wellhead. (4)
Bcf means billion cubic feet of natural gas, Bcfe means billion
cubic feet of natural gas equivalent and MMBls means millions of
barrels of liquid. Liquidity and Capital Resources FCP continues to
rely upon equity to fund its operations and capital programmes. In
December 2004, FCP raised $70 million, net of issue costs, from the
sale of 6,000,000 common shares. Additional funding is derived
periodically from the exercise of stock options and common share
purchase warrants. In 2004, 3,879,989 common shares were issued,
resulting in $9 million in proceeds, from the exercise of options
and warrants. In October 2004 FCP issued 10,150,000 common shares
to acquire an overriding five per cent net profit interests that
previously encumbered Blocks 405b and 406a. The fully-diluted
number of shares outstanding at March 28, 2005 and December 31,
2004 were as follows: March 28, December 31, FULLY-DILUTED SHARES
OUTSTANDING 2005 2004
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Common shares 183,591,052 183,086,675 Employee stock options
7,629,501 7,629,501 Common share purchase warrants 14,408 68,785
Non-employee stock options 450,000 900,000
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191,684,961 191,684,961
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FCP had working capital of $52.1 million at December 31, 2004.
Changes in the Company's working capital are primarily a function
of the timing and magnitude of its equity financings and capital
expenditures, as detailed below: WORKING CAPITAL (000's)
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Working capital at December 31, 2003 $ 83,111 Equity issues 69,922
Proceeds from exercise of options and warrants 8,996 Capital
expenditures (108,609) To fund operations (net) (1,305)
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Working capital at December 31, 2004 $ 52,115
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The Company has sufficient working capital at December 31, 2004 to
fund its 2005 capital programme and work commitments. Beyond the
current planned expenditures and obligations, it is expected the
Company will require additional capital to fund future operations
and capital spending. In addition, the development of the Company's
reserves through to commercial production will require significant
funding that is expected to be in the form of equity, debt, joint
ventures or some combination thereof. Operating Results Selected
Annual Information (000's) 2004 2003 2002
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Interest income $ 1,290 $ 638 $ 170
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Expenses General and administrative 4,027 2,604 2,089 Stock-based
compensation 5,181 4,679 405 Foreign exchange loss (gain) (1,542)
578 (21) Write-off Yemen investment - 1,035 - Algerian earthquake
relief donation - 1,000 - Other expenses 189 392 17
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7,855 10,288 2,490
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Net loss (6,565) (9,650) (2,320) Net loss per share (0.04) (0.07)
(0.03) Share capital 377,288 165,181 40,351 Working capital 52,115
83,111 6,640 Capital assets 310,053 68,708 18,862 Other liabilities
(339) (124) (22)
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Shareholders' equity $ 361,829 $ 151,695 $ 25,480
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Interest income increased $0.7 million in 2004 as a result of
higher interest rates and cash and term-deposit balances from the
public share offerings of $99.6 million in October 2003 and $70
million in December 2004. General and administrative expenses
increased $1.4 million in 2004 as a result of higher overall
operational activity in Algeria, employee levels, insurance
coverage and professional fees. General and administrative expenses
increased in the fourth quarter of 2004 as a result of higher
employee levels and professional fees. Stock-based compensation
expense increased $0.5 million in 2004 primarily from the
amortization of costs associated with the vesting of options
granted in the fourth quarter of 2003. The Company has recorded a
foreign exchange gain of $1.5 million during 2004, due primarily to
the effect of a weakening U.S. dollar on Canadian dollar and
British pound cash and term-deposits held during the year. Selected
Quarterly Information 2004 (000's) Q4 Q3 Q2 Q1
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Interest income $ 386 $ 251 $ 238 $ 415
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Expenses General and administrative 1,165 904 1,048 910 Stock-based
compensation 1,442 975 1,375 1,389 Foreign exchange loss (gain)
(820) (2,151) 1,137 292 Write-off Yemen investment - - - -
Earthquake donation - - - - Other expenses (recovery) (102) 109 92
90
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1,685 (163) 3,652 2,681
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Net income (loss) (1,299) 414 (3,414) (2,266) Net loss per share
(0.01) 0.00 (0.02) (0.01) Share capital 377,288 172,895 172,376
171,897 Working capital (deficiency) 52,115 19,858 48,664 74,659
Capital assets 310,053 137,911 107,267 82,886 Other liabilities
(339) (239) (174) (151)
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Shareholders' equity $361,829 $157,530 $155,757 $157,394
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2003 (000's) Q4 Q3 Q2 Q1
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Interest income $ 315 $ 81 $ 118 $ 124
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Expenses General and administrative 962 660 539 443 Stock-based
compensation 3,579 233 214 653 Foreign exchange loss (gain) (283)
(192) 633 421 Write-off Yemen investment 1,035 - - - Earthquake
donation - - 1,000 - Other expenses (recovery) 253 34 97 7
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5,546 735 2,483 1,524
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Net income (loss) (5,231) (654) (2,365) (1,400) Net loss per share
(0.03) (0.01) (0.02) (0.01) Share capital 165,181 62,463 62,295
62,194 Working capital (deficiency) 83,111 (1,150) 10,383 19,947
Capital assets 68,708 52,106 41,061 29,085 Other liabilities (124)
(92) (91) (61)
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Shareholders' equity $151,695 $ 50,864 $ 51,353 $ 48,971
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In 2004, fluctuations in the quarterly net loss were primarily
driven by foreign currency gains and losses. General and
administrative expenses have trended higher on a quarterly basis,
consistent with supporting higher operational activity in Algeria.
Stock-based compensation expense was lower in the third quarter of
2004 due to the effect of stock option cancellations and higher in
the fourth quarter of 2003 due to option grants. The increase in
share capital in the fourth quarter of 2004 is primarily due to the
December equity issue of six million shares and the acquisitions of
the carried five per cent net profits interest for shares. The
increase in capital assets in the fourth quarter of 2004 is the
result of capital expenditures incurred on the Algerian projects
and the value ascribed to the carried five per cent net profits
interest acquisitions. Business Risks and Uncertainties The
Company's business is subject to risks inherent in oil and gas
exploration and development operations. In addition, there are
risks associated with the Company's development stage of operations
and the foreign jurisdiction in which it operates. The Company has
identified certain risks pertinent to its business including:
exploration and reserve risks, drilling and operating risks, costs
and availability of materials and services, capital markets and the
requirement for additional capital, loss of or changes to
production sharing, joint venture or related agreements, economic
and sovereign risks, possibility of less developed legal systems,
reliance on strategic relationships, market risk, volatility of
future oil and gas prices and foreign currency risk. FCP attempts
to monitor, assess and mitigate certain of these risks by retaining
an experienced team of professionals and using modern technology.
Further, the Company has focused its activities in a known
hydrocarbon basin in a jurisdiction that has previously established
long-term oil and gas ventures with foreign oil and gas companies,
existing infrastructure of services and oil and gas transportation
facilities, and reasonable proximity to markets. The Company also
retains consultants resident in Algeria to monitor economic and
political developments and to assist with operating, administrative
and legal matters. There are certain risks, however, over which the
Company has little or no control. Outlook As previously announced,
FCP is working with its advisers identifying and considering
strategic alternatives. It is not expected that any decisions with
respect to the result of this process will be made prior to late
April, at the earliest. The Company is moving forward with the
drilling of two exploration wells on Block 406a. Further drilling
and development work on Block 405b will be reviewed upon completion
of the strategic alternatives assessment. Critical Accounting
Policies and Estimates Petroleum and Natural Gas Operations FCP
follows the full cost method to account for its petroleum and
natural gas operations, whereby all costs of exploring for and
developing petroleum and natural gas reserves are capitalized and
accumulated in country-by-country cost centres. These capitalized
costs will be depleted using the unit-of- production method based
on estimates of proved reserves. The costs in cost centres from
which there has been no commercial production are not subject to
depletion until commercial production commences. These capitalized
costs are assessed to determine whether it is likely such costs
will be recovered in the future. Costs which are not likely to be
recovered in the future are written-off. Petroleum and natural gas
reserves form the basis for a number of accounting estimates and
support for the carrying amount of petroleum and natural gas
properties. The estimation of reserves is a subjective process.
Forecasts are based on engineering data, projected future rates of
production, estimated commodity price forecasts and the timing of
future expenditures, all of which are subject to numerous
uncertainties and various interpretations. The Company expects that
its estimates of reserves will change to reflect updated
information. Reserve estimates can be revised upward or downward
based on the results of future drilling, testing, production levels
and economics of recovery based on cash flow forecasts. Advisory
Regarding Forward-Looking Statements This discussion and analysis
contains forward-looking statements. Forward-looking statements are
subject to numerous known and unknown risks and uncertainties, some
of which are beyond FCP's control, including the impact of general
economic conditions, industry conditions, volatility of commodity
prices, currency exchange rate fluctuations, reserve estimates,
environmental risks, competition from other explorers, stock market
volatility and ability to access sufficient capital. FCP's actual
results could differ materially from those anticipated in the
forward-looking statements. Readers are cautioned not to place
undue reliance on these forward-looking statements. March 28, 2005
FIRST CALGARY PETROLEUMS LTD. Consolidated Balance Sheets December
31 (Expressed in thousands of U.S. dollars)
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2004 2003
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Assets Current assets: Cash and short-term deposits (note 4) $
81,874 $ 95,185 Accounts receivable 357 144 Deposits and prepaid
expenses 758 326
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82,989 95,655 Property, plant and equipment (note 5) 310,053 68,708
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$ 393,042 $ 164,363
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Liabilities and Shareholders' Equity Current liabilities: Accounts
payable and accrued liabilities (note 6) $ 30,874 $ 12,544 Asset
retirement obligations (note 7) 339 124 Shareholders' equity:
Capital stock (note 8) 377,288 165,181 Contributed surplus (note 8)
9,441 4,849 Cumulative translation adjustment 6,502 6,502 Deficit
(31,402) (24,837)
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361,829 151,695 Operations and commitments (note 3)
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$ 393,042 $ 164,363
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See accompanying notes to consolidated financial statements. FIRST
CALGARY PETROLEUMS LTD. Consolidated Statements of Operations and
Deficit Years ended December 31 (Expressed in thousands of U.S.
dollars)
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2004 2003
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Revenue: Interest $ 1,290 $ 638
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Expenses: General and administrative 4,027 2,604 Stock-based
compensation (note 8) 5,181 4,679 Foreign exchange loss (gain)
(1,542) 578 Capital taxes 110 347 Depreciation 67 38 Accretion of
asset retirement obligations 12 7 Write-off of Yemen petroleum and
natural gas properties (note 5) - 1,035 Algerian earthquake relief
donation - 1,000
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7,855 10,288
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Loss for the year (6,565) (9,650) Deficit, beginning of year
(24,837) (15,187)
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Deficit, end of year $ (31,402) $ (24,837)
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Loss per share (note 8) $ (0.04) $ (0.07)
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See accompanying notes to consolidated financial statements. FIRST
CALGARY PETROLEUMS LTD. Consolidated Statements of Cash Flows Years
ended December 31 (Expressed in thousands of U.S. dollars)
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2004 2003
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Operating activities: Loss for the year $ (6,565) $ (9,650) Items
not involving cash: Stock-based compensation 5,181 4,679 Foreign
exchange loss (gain) (1,612) - Depreciation 67 38 Accretion of
asset retirement obligations 12 7 Write-off of Yemen petroleum and
natural gas properties - 1,035
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(2,917) (3,891) Change in non-cash working capital 1,430 1,549
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(1,487) (2,342) Financing activities: Proceeds from issuance of
shares 74,242 129,372 Proceeds from exercise of warrants 6,602
2,403 Proceeds from exercise of options 2,394 1,273 Issue costs
(4,320) (8,453)
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78,918 124,595 Investing activities: Capital expenditures (108,609)
(46,207) Change in non-cash working capital 16,255 3,723
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(92,354) (42,484)
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Increase (decrease) in cash and short-term deposits (14,923) 79,769
Effect of exchange rate fluctuations on cash and short-term
deposits 1,612 2,994 Cash and short-term deposits, beginning of
year 95,185 12,422
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Cash and short-term deposits, end of year $ 81,874 $ 95,185
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See accompanying notes to consolidated financial statements. FIRST
CALGARY PETROLEUMS LTD. Notes to Consolidated Financial Statements
Years ended December 31, 2004 and 2003 (Expressed in thousands of
U.S. dollars unless otherwise indicated)
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First Calgary Petroleums Ltd. (the "Company") is incorporated in
Alberta under the Business Corporations Act (Alberta) and its
primary business activity is the exploration for and development of
petroleum and natural gas in Algeria. 1. Significant accounting
policies: (a) Basis of presentation: The consolidated financial
statements include the accounts of the Company and its wholly owned
subsidiaries. (b) Petroleum and natural gas operations: The Company
follows the full cost method of accounting for petroleum and
natural gas operations, whereby all costs of exploring for and
developing petroleum and natural gas reserves are capitalized and
accumulated in country-by-country cost centres. Such costs include
land acquisition costs, geological and geophysical costs, carrying
charges on non-producing properties, costs of drilling both
productive and non-productive wells, interest costs on major
development projects and overhead charges directly related to
acquisition, exploration and development activities. The costs
(including exploratory dry holes) in cost centres from which there
has been no commercial production are not subject to depletion
until commercial production commences. The capitalized costs are
periodically assessed to determine whether it is likely such costs
will be recovered in the future. To the extent there are costs
which are not likely to be recovered in the future, they are
written-off. The costs in cost centres from which there will be
production, together with the cost of production equipment, will be
depleted and depreciated on the unit-of-production method based on
the estimated proved reserves after royalties. Petroleum and
natural gas reserves and production will be converted into
equivalent units based upon estimated relative energy content.
Costs of acquiring and evaluating significant unproved properties
are excluded from the depletion calculations. These unproved
properties are assessed periodically to ascertain whether
impairment in value has occurred. When proved reserves are assigned
or the value of the property is considered to be impaired, the cost
of the property or the amount of the impairment is added to costs
subject to depletion. Petroleum and natural gas properties are
subject to a ceiling test in each reporting period to determine
that the costs are recoverable and do not exceed the fair value of
the properties. The costs are assessed to be recoverable if the sum
of the undiscounted cash flows expected from the production of
proved reserves and the lower of cost and market of unproved
properties exceed the carrying values of the petroleum and natural
gas properties. If the carrying value of the petroleum and natural
gas properties is not assessed to be recoverable, an impairment
loss is recognized to the extent that the carrying value exceeds an
estimated fair value. The fair value estimate is normally based on
the sum of the discounted cash flows expected from the production
of proved and probable reserves and the lower of cost and market of
unproved properties. The cash flows are estimated using forecast
product prices and costs and are discounted using a risk-free
interest rate. Proceeds from the sale of petroleum and natural gas
properties are applied against capitalized costs, with no gain or
loss recognized, unless such a sale would alter the depletion rate
by more than twenty per cent. Substantially all of the Company's
exploration, development and production activities are conducted
jointly with others and accordingly these financial statements
reflect only the Company's proportionate interest in such
activities. (c) Asset retirement obligations: The Company
recognizes the estimated fair value of legal obligations associated
with the retirement of petroleum and natural gas properties in the
period in which they are incurred. The obligation is recorded as a
liability with a corresponding increase in the carrying amount of
the petroleum and natural gas properties. The incremental
capitalized amount will be depleted on a unit-of-production basis
over the life of the proved reserves. The obligation is increased
each period, or accretes, due to the passage of time and is
recorded in the statement of operations. Revisions to the estimated
fair value would result in an adjustment to the obligation and
carrying amount of the petroleum and natural gas properties. (d)
Foreign currency: All operations are considered financially and
operationally integrated. Results of operations are translated to
the functional currency, using average rates for revenues and
expenses, except depreciation which is translated at the rate of
exchange applicable to the related assets. Monetary items
denominated in foreign currencies are translated to the functional
currency at exchange rates in effect at the balance sheet date and
non-monetary items are translated at rates of exchange in effect
when the assets were acquired or obligations incurred. Foreign
exchange gains and losses are recorded in the statement of
operations. (e) Stock-based compensation: The Company accounts for
all stock options and warrants granted using the fair value method.
Under this method, compensation expense is measured at fair value
at the grant date using the Black-Scholes option pricing model and
recognized over the vesting period with a corresponding increase to
contributed surplus. Consideration received upon the exercise of
stock options together with the amount of non-cash compensation
expense recognized in contributed surplus is recorded as share
capital. (f) Income taxes: The Company uses the asset and liability
method of accounting for income taxes. Under this method current
income taxes are recognized for the estimated income taxes payable
for the current year. Future income taxes are recognized for
temporary differences between the tax and accounting bases of
assets and liabilities and for the benefit of losses available to
be carried forward for tax purposes that are likely to be realized.
Future tax assets and liabilities are measured using enacted or
substantively enacted tax rates expected to apply to taxable income
in the years in which those temporary differences are expected to
be recovered or settled. The effect on future tax assets and
liabilities of a change in tax rates is recognized in income in the
period that includes the date of enactment or substantive
enactment. (g) Use of estimates: The preparation of financial
statements in conformity with generally accepted accounting
principles requires management to make estimates and assumptions
that affect the reported amounts of assets, liabilities, revenues
and expenses including depreciation and asset retirement
obligations. The ceiling test is based upon estimates of market
values of unproved properties, reserves, petroleum and natural gas
prices, future costs and other assumptions. (h) Per share amounts:
Basic per share amounts are computed by dividing the earnings or
loss by the weighted average shares outstanding during the
reporting period. Diluted amounts are computed using the treasury
stock method. The treasury stock method assumes that proceeds
received from the exercise of in-the-money options and warrants are
used to repurchase shares at the average market price for the
period. The difference between the number of shares that could have
been purchased at market prices in the period and the number of
in-the-money options and warrants is added to the weighted average
shares outstanding. 2. Changes in accounting policies and
restatement of prior periods: In the fourth quarter of 2003, the
Company adopted three new accounting policies which resulted in the
retroactive restatement of the previously reported 2003 interim
financial statements. The new accounting policies were the change
to the U.S. dollar as the Company's reporting currency, the
recognition of compensation expense for stock options granted to
employees after January 1, 2003 and the new accounting standard for
asset retirement obligations. 3. Operations and commitments: The
Company's operations are in Algeria where it has the rights to
explore, appraise and develop two blocks, Yacoub Block 406a ("Block
406a") and Ledjmet Block 405b ("Block 405b"). The Company's rights
and obligations in each block are set out in agreements with
Sonatrach, the national oil company of Algeria. These agreements
are structured such that the Company has committed to conduct
certain minimum exploration activities over a period of time and in
return earns an interest in commercial discoveries. (a) Block 406a:
In 2000 the Company entered into a joint venture agreement with
Sonatrach to explore Block 406a in the Berkine Basin. The Company
is currently in the second exploration period which expires in
November 2005. The remaining work obligation for the second
exploration period is to drill two exploration wells, estimated to
cost $18 million. If the Company fails to satisfy the work
obligations, the rights, other than for areas for which an
exploitation permit has been granted or requested, could be
forfeited and the Company will be liable to pay Sonatrach a penalty
of $12.75 million. In addition to the work commitments, the Company
is obligated to pay an annual training bonus in the amount of $150
thousand for the duration of the contract. (b) Block 405b: In 2001
the Company entered into a production sharing contract with
Sonatrach to explore and appraise Block 405b in the Berkine Basin.
The Company is in the second exploration period which expires in
December 2006. The remaining work obligation for the second
exploration period is to drill one exploration well. The estimated
cost of this work is $9.0 million. Should the Company fail to
satisfy the work obligation of the second exploration period, the
rights, other than for areas for which an exploitation permit has
been granted or requested, could be forfeited and the Company will
be liable to pay Sonatrach a penalty of $6.25 million. In addition
to the work commitments, the Company is obligated to pay an annual
training bonus in the amount of $150 thousand for the duration of
the contract. The contract provides the Company with the right to
appraise and develop the MLE reserves discovered with the MLE-1
well. As compensation for the right to access the MLE discovery,
the Company is committed to pay Sonatrach a reserve-based access
fee of $0.25 per barrel of oil equivalent calculated on the total
estimated recoverable proved MLE reserves. The access fee will be
determined at the time the MLE reserves are declared commercial by
Sonatrach and will be payable as a deduction from Sonatrach's share
of the MLE development expenditures. While the Company currently
has sufficient resources to meet its required work commitments,
these resources may be directed to other, optional capital
programmes depending on the success of expenditures and other
opportunities which become available to the Company. In addition,
the development of the Company's existing reserves through to
commercial production will require additional funding in the form
of equity, debt, joint ventures or some combination thereof. The
Company has retained Lehman Brothers Europe Limited and Canaccord
Capital Corporation to assist the Company in seeking and evaluating
strategic alternatives. 4. Cash and short-term deposits: The
Company considers deposits in banks, certificates of deposit and
short-term investments with original maturities of three months or
less as cash and short-term deposits. The components of cash and
short-term deposits are as follows:
---------------------------------------------------------------------
2004 2003
---------------------------------------------------------------------
Cash on deposit: U.S. dollars $ 1,833 $ 50,911 British pounds 1,574
286 Algerian dinars 577 51 Canadian dollars 482 791 Bank term
deposits: British pounds 54,823 - Canadian dollars 22,079 42,644
U.S. dollars 506 502
---------------------------------------------------------------------
$ 81,874 $ 95,185
---------------------------------------------------------------------
---------------------------------------------------------------------
5. Property, plant and equipment:
---------------------------------------------------------------------
Accumulated Net book 2004 Cost depreciation value
---------------------------------------------------------------------
Petroleum and natural gas properties - Algeria $ 309,751 $ - $
309,751 Office furniture and equipment 504 202 302
---------------------------------------------------------------------
$ 310,255 $ 202 $ 310,053
---------------------------------------------------------------------
---------------------------------------------------------------------
Included in Algerian petroleum and natural gas properties is $132.6
million representing the value attributable to the 10,150,000
common shares of the Company issued in October 2004 to acquire an
overriding five per cent net profits interest that previously
encumbered Blocks 405b and 406a.
---------------------------------------------------------------------
Accumulated Net book 2003 Cost depreciation value
---------------------------------------------------------------------
Petroleum and natural gas properties - Algeria $ 68,409 $ - $
68,409 Office furniture and equipment 440 141 299
---------------------------------------------------------------------
$ 68,849 $ 141 $ 68,708
---------------------------------------------------------------------
---------------------------------------------------------------------
The Company held a ten per cent interest in a production sharing
contract to explore Block 43 in Yemen. At December 31, 2003 the
Company determined it was not prepared to fund any further
activities on the block, and given the absence of a commercial
discovery, wrote-off $1.0 million of costs related to the block.
During the year, the Company capitalized $5.2 million (2003 - $1.4
million) of overhead charges relating directly to the exploration
and development activities in Algeria. 6. Accounts payable and
accrued liabilities:
---------------------------------------------------------------------
2004 2003
---------------------------------------------------------------------
Trade payables: U.S. dollars $ 13,004 $ 8,311 Algerian dinars 3,746
711 Canadian dollars 2,151 536 British pounds 423 55 Capital
accrual: U.S. dollars 11,550 2,931
---------------------------------------------------------------------
$ 30,874 $ 12,544
---------------------------------------------------------------------
---------------------------------------------------------------------
7. Asset retirement obligations: The Company has an obligation to
abandon and remediate its wells at the end of their useful lives
provided Sonatrach does not elect to continue production after the
hydrocarbon contracts expire. The present value of this obligation
has been projected using estimates of the future costs and the
timing of abandonment. At December 31, 2004 the Company estimated
the present value of its asset retirement obligations to be $0.3
million (2003 - $0.1 million) based on a future liability of $1.6
million (2003 - $0.5 million). These costs are expected to be
incurred near the end of the exploitation phase of the Algerian
production sharing contract, being after 2030. A credit-adjusted
risk-free discount rate of seven per cent and an inflation rate of
two per cent were used to calculate the present value. 8. Capital
stock: (a) Authorized share capital: Unlimited number of common
shares without nominal or par value Unlimited number of preferred
shares without nominal or par value (b) Issued share capital:
---------------------------------------------------------------------
Number of Shares Amount
---------------------------------------------------------------------
Common shares:
---------------------------------------------------------------------
Balance, December 31, 2002 108,629,726 $ 40,351 Issued on public
offering (i) 14,893,620 23,121 Issued on public offering (ii)
35,000,000 106,251 Issued on exercise of share purchase warrants
(iii) 2,448,408 2,403 Issued on exercise of stock options 2,084,932
1,273 Transfer from contributed surplus on exercise of stock
options and warrants - 235 Issue costs - (8,453)
---------------------------------------------------------------------
Balance, December 31, 2003 163,056,686 165,181 Issued on
acquisition of net profits interest (iv) 10,150,000 132,600 Issued
on public offering (v) 6,000,000 74,242 Issued on exercise of share
purchase warrants (vi) 1,844,424 6,602 Issued on exercise of stock
options 2,035,565 2,394 Transfer from contributed surplus on
exercise of stock options and warrants - 589 Issue costs - (4,320)
---------------------------------------------------------------------
Balance, December 31, 2004 (vii) 183,086,675 $ 377,288
---------------------------------------------------------------------
---------------------------------------------------------------------
(i) In February 2003 the Company issued 14,893,620 common shares
for gross proceeds of $23.1 million (10,807,620 common shares at
C$2.35 per share and 4,086,000 common shares at pnds stlg 0.95 per
share). The issue costs were $1.7 million. In conjunction with the
offering, the Company issued the agents 893,617 common share
purchase warrants exercisable at a purchase price of C$2.60 per
share until February 12, 2004. (ii) In October 2003 the Company
issued 35,000,000 common shares for gross proceeds of $106.3
million (13,838,500 common shares at C$4.00 per share and
21,161,500 common shares at pnds stlg 1.79 per share). The issue
costs were $6.7 million. In conjunction with the offering, the
Company issued the agents 1,750,000 common share purchase warrants
exercisable at a purchase price of C$5.00 per share until April 20,
2005. (iii) In 2003 the Company issued 2,448,408 common shares
pursuant to the exercise of the following common share purchase
warrants: 1,368,000 at C$0.56 per share, 231,472 at C$1.11 per
share and 848,936 at C$2.60 per share. (iv) In October 2004, the
Company issued 10,150,000 common shares to acquire an overriding
five per cent net profits interest that previously encumbered
Blocks 405b and 406a. (v) In December 2004, the Company issued
6,000,000 common shares for gross proceeds of $74.2 million
(4,637,192 common shares at pnds stlg 6.50 per share and 1,362,808
common shares at C$14.46 per share). The issue costs were $4.2
million. (vi) In 2004, the Company issued 1,844,424 common shares
pursuant to the exercise of the following common share purchase
warrants: 85,764 at C$1.11 per share, 44,681 at C$2.60 per share
and 1,713,979 at C$5.00 per share. (vii) Subsequent to December 31,
2004, the Company issued 504,377 common shares pursuant to the
exercise of 450,000 non-employee stock options at C$0.70 per share,
32,764 common share purchase warrants at C$1.11 per share and
21,613 common share purchase warrants at C$5.00 per share. (c)
Employee stock options: Pursuant to the Stock Option Plan, the
Company has 12,176,230 common shares reserved for issuance. Stock
options granted under the plan have a term of five years and
vesting terms are determined at the discretion of the Board,
ranging between two and three years. The exercise price of each
option is equal to the closing market price of the shares on the
date preceding the date of the grant. The following table
summarizes the changes in stock options outstanding:
-----------------------------------------------------------------
Weighted Average Number of Exercise Options Price
-----------------------------------------------------------------
Outstanding, December 31, 2002 7,110,033 C$ 0.88 Granted 4,180,000
4.29 Exercised (2,084,932) 0.82 Cancelled (186,700) 1.04
-----------------------------------------------------------------
Outstanding, December 31, 2003 9,018,401 2.47 Granted 880,000 9.83
Exercised (2,035,565) 1.45 Cancelled (233,335) 6.55
-----------------------------------------------------------------
Outstanding, December 31, 2004 7,629,501 C$ 3.47
-----------------------------------------------------------------
-----------------------------------------------------------------
The following table summarizes information about the options
outstanding and exercisable at December 31, 2004:
-------------------------------------------------------------------------
Options Outstanding Options Exercisable
-------------------------------------------------------------------------
Weighted Average Weighted Weighted Remaining Average Average Range
of Contractual Exercise Exercise Exercise Price Options Life Price
Options Price
-------------------------------------------------------------------------
C$0.50-0.95 2,173,500 1.7 years C$ 0.63 2,173,500 C$ 0.63
C$1.25-1.90 930,334 2.4 years 1.26 930,334 1.26 C$2.36-2.95
1,030,334 3.1 years 2.60 637,001 2.59 C$4.72-4.72 2,518,333 3.8
years 4.72 1,680,556 4.72 C$7.45-7.81 518,000 4.1 years 7.67
248,334 7.67 C$10.95-15.77 459,000 4.1 years 11.68 123,333 11.15
-------------------------------------------------------------------------
7,629,501 3.0 years C$ 3.47 5,793,058 C$ 2.66
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(d) Common share purchase warrants: The following table summarizes
the changes in common share purchase warrants outstanding:
-----------------------------------------------------------------
Weighted Average Number of Exercise Warrants Price
-----------------------------------------------------------------
Outstanding, December 31, 2002 1,718,000 C$ 0.67 Granted in
connection with public offerings 2,643,617 4.19 Exercised
(2,448,408) 1.32
-----------------------------------------------------------------
Outstanding, December 31, 2003 1,913,209 4.70 Exercised (1,844,424)
4.76
-----------------------------------------------------------------
Outstanding, December 31, 2004 68,785 C$ 3.15
-----------------------------------------------------------------
-----------------------------------------------------------------
At December 31, 2004, all of the 68,785 common share purchase
warrants outstanding are exercisable; 36,021 expire on April 19,
2005 and the remaining 32,764 expire on June 9, 2007. (e)
Non-employee stock options: In 2002 the Company granted consultants
options to acquire 900,000 common shares at a price of C$0.70 per
share. At December 31, 2004, all of these options remain
outstanding, are fully vested and expire January 24, 2007. (f)
Stock-based compensation expense: For the year ended December 31,
2004, the Company recorded $5.2 million (2003 - $4.7 million) as
stock-based compensation expense with a corresponding increase in
contributed surplus. The fair value of the options granted in 2004
was estimated to be C$5.34 per option (2003 - C$3.02) and was
determined using the Black-Scholes option pricing model with the
following weighted average assumptions: expected volatility of 81
per cent (2003 - 88 per cent) , risk-free interest rate of 3.7 per
cent (2003 - 4.35 per cent) and expected lives of 3 years (2003 - 5
years). No compensation expense was recorded on options granted to
employees prior to January 1, 2003. Had options granted to
employees in 2002 been accounted for using the fair value method,
net loss for the year ended December 31, 2004 would have been
higher by $0.1 million (2003 - $0.3 million). The pro forma fair
values were determined using the Black-Scholes option pricing model
with the following assumptions: expected volatility of 95 per cent,
risk-free interest rate of 5 per cent and expected lives of 5
years. (g) Contributed surplus: The changes in contributed surplus
balance are as follows:
-----------------------------------------------------------------
2004 2003
-----------------------------------------------------------------
Balance, beginning of year $ 4,849 $ 405 Options granted 5,181
4,679 Options and warrants exercised (589) (235)
-----------------------------------------------------------------
Balance, end of year $ 9,441 $ 4,849
-----------------------------------------------------------------
-----------------------------------------------------------------
(h) Per share amounts: The loss per share is based on the weighted
average shares outstanding for the year. The weighted average
shares outstanding for 2004 was 167,749,193 (2003 - 130,088,467).
The effect upon conversion of outstanding options and warrants is
anti-dilutive. 9. Income taxes: Income tax expense differs from the
amount that would be computed by applying the Canadian federal and
provincial statutory income tax rates to the loss for the year as
follows:
---------------------------------------------------------------------
2004 2003
---------------------------------------------------------------------
Loss for the year $ (6,565) $ (9,650) Statutory tax rate 38.6%
40.6% Expected income tax recovery at statutory rate (2,534)
(3,918) Increase (decrease) resulting from: Non-deductible
stock-based compensation 2,000 1,900 Increase in valuation
allowance 1,811 2,624 Share issue costs (1,313) (923) Other 36 317
---------------------------------------------------------------------
$ - $ -
---------------------------------------------------------------------
---------------------------------------------------------------------
The components of the potential future income tax asset at December
31 are summarized below:
---------------------------------------------------------------------
2004 2003
---------------------------------------------------------------------
Operating losses $ 4,115 $ 2,304 Property, plant and equipment
3,211 3,405 Share issue costs 3,255 3,061
---------------------------------------------------------------------
10,581 8,770 Less: valuation allowance (10,581) (8,770)
---------------------------------------------------------------------
$ - $ -
---------------------------------------------------------------------
---------------------------------------------------------------------
10. Financial instruments: The Company is exposed to foreign
currency fluctuations as it holds Canadian dollar and British pound
cash and short-term deposits and accounts payable. In addition, a
portion of the Company's operating activities are conducted in
Canadian dollars. There are no exchange rate contracts in place.
The fair value of the Company's financial instruments, including
cash and short-term deposits, accounts receivable and accounts
payable and accrued liabilities approximate their carrying values
due to their short terms to maturity. 11. Leases: The Company is
committed to office and equipment leases over the next five years
as follows: 2005 $ 389 2006 277 2007 232 2008 17 2009 2 12.
Segmented information: The Company's activities are conducted in
two geographic segments: Canada and Algeria. All activities relate
to exploration and development of petroleum and natural gas in
Algeria. 2004 Canada Algeria Yemen Total
---------------------------------------------------------------------
Revenue $ 1,290 $ - $ - $ 1,290 Expenses 7,855 - - 7,855
---------------------------------------------------------------------
Loss for the year (6,565) - - (6,565)
---------------------------------------------------------------------
---------------------------------------------------------------------
Capital expenditures $ 67 $ 241,142 $ - $ 241,209
---------------------------------------------------------------------
---------------------------------------------------------------------
Assets $ 81,991 $ 311,051 $ - $ 393,042
---------------------------------------------------------------------
---------------------------------------------------------------------
2003 Canada Algeria Yemen Total
---------------------------------------------------------------------
Revenue $ 638 $ - $ - $ 638 Expenses 8,183 1,070 1,035 10,288
---------------------------------------------------------------------
Loss for the year (7,545) (1,070) (1,035) (9,650)
---------------------------------------------------------------------
---------------------------------------------------------------------
Capital expenditures $ 94 $ 45,881 $ 232 $ 46,207
---------------------------------------------------------------------
---------------------------------------------------------------------
Assets $ 95,506 $ 68,857 $ - $ 164,363
---------------------------------------------------------------------
---------------------------------------------------------------------
Capital expenditures in 2004 include the non-cash acquisitions of
the overriding five per cent net profits interest of $132.6
million. For further information: contact Kenneth C. Rutherford,
Vice President, Finance & Chief Financial Officer, FIRST
CALGARY PETROLEUMS LTD., Suite 900, 520 - 5 Avenue SW, Calgary, AB,
T2P 3R7, tel: (403) 264-6697, fax: (403) 264-3955, email:
info(at)fcpl.ca, web site: www.fcpl.ca; European contacts: Jim
Joseph, COLLEGE HILL, Tel: +44 (0) 207 457 2020; Carina Corbett, 4C
COMMUNICATIONS LTD., Tel: +44 (0) 207 907 4761 (FCP.) END
DATASOURCE: FIRST CALGARY PETROLEUMS LTD
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