Zargon Oil & Gas Ltd. (TSX:ZAR) ("Zargon" or the "Company") today announced its
operating and financial results for the fourth quarter and year ended December
31, 2010.
At year end 2010, Zargon completed its conversion to a corporation with an
exclusive focus on oil exploitation across its asset base. As a dividend paying
corporation, and in the current climate of low natural gas prices, Management
believes that oil exploitation projects provide greater profitability and are
the best strategy to meet the Company's objective of delivering sustainable
returns to shareholders. During 2010, Zargon completed an active program of
property acquisitions/dispositions, which consolidated land holdings and
strengthened its portfolio of oil projects. In the final year in a trust format,
Zargon maintained an $0.18 per unit per month distribution in addition to
executing a $72.0 million oil exploitation focused capital program, which
delivered a 12 percent increase in oil and liquids production and a six percent
gain in proved and probable oil and liquid reserves.
Highlights from the fourth quarter and year ended December 31, 2010
-- On December 31, 2010, Zargon Energy Trust (the "Trust") completed the
conversion from an income trust into a dividend paying corporation,
Zargon Oil & Gas Ltd., pursuant to a Plan of Arrangement under the
Business Corporations Act (Alberta). Subsequent to the conversion,
Zargon had 27.05 million common shares issued and outstanding and no
remaining exchangeable shares.
-- For 2010, revenue increased 15 percent to $179.5 million; net earnings
increased 228 percent to $8.9 million, while funds flow from operating
activities decreased 15 percent to $73.7 million. Fourth quarter 2010
revenue of $42.6 million and funds flow from operating activities of
$14.6 million were lower than the preceding third quarter 2010 levels by
four percent and 21 percent, respectively.
-- Production volumes in 2010 were relatively unchanged from 2009 at 9,879
barrels of oil equivalent per day. Fourth quarter production of 23.28
million cubic feet per day of natural gas and 5,437 barrels per day of
oil and liquids provided Zargon quarterly production volumes of 9,317
barrels of oil equivalent per day, eight percent lower than third
quarter volumes.
-- Net capital expenditures in 2010 were $72.0 million with $11.0 million
for corporate and net property acquisitions, $60.4 million for
exploitation and development programs and $0.6 million for
administrative assets. During the year, Zargon drilled 37.6 net wells
with a 100 percent success ratio, yielding 33.3 net oil wells and 4.3
net natural gas wells.
-- Cash distributions declared in 2010 totalled $2.16 per trust unit.
Including the effect of the exchangeable shares, which do not receive
distributions, and including the effect of the Distribution Reinvestment
Plan ("DRIP"), distributions totalled $47.3 million or 64 percent of the
year's $73.7 million funds flow from operating activities.
-- Year end debt, net of working capital (excluding unrealized risk
management assets/liabilities and future income taxes), of $124.4
million was slightly less than 1.7 times the 2010 funds flow from
operating activities. As at December 31, 2010, Zargon had approximately
$65 million of unutilized committed credit facilities remaining on the
$180 million credit facilities held by three major Canadian-based
banking institutions.
CORPORATE HIGHLIGHTS
Three Months Ended Year Ended
December 31, December 31,
Percent Percent
2010 2009 Change 2010 2009 Change
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(unaudited) (unaudited)
FINANCIAL
Income and Investments
($ millions)
Petroleum and natural
gas revenue 42.64 47.21 (10) 179.47 155.99 15
Funds flow from
operating activities 14.60 24.75 (41) 73.70 86.35 (15)
Cash distributions
(excluding DRIP) 10.99 12.45 (12) 47.35 45.96 3
Net earnings (5.30) 0.44 (1,305) 8.92 2.72 228
Net capital
expenditures 20.29 12.87 58 72.03 104.59 (31)
Bank debt 115.29 76.58 51
Per Share, Diluted
Funds flow from
operating activities
($/share) 0.54 0.95 (43) 2.80 3.64 (23)
Net earnings ($/share) (0.22) 0.02 (1,200) 0.38 0.13 192
Cash Distributions
($/trust unit) 0.54 0.54 - 2.16 2.16 -
Total Common Shares
Outstanding at Year End
(millions) 27.05 26.02 4
OPERATING
Average Daily Production
Oil and liquids
(bbl/d) 5,437 5,485 (1) 5,645 5,055 12
Natural gas (mmcf/d) 23.28 30.60 (24) 25.40 28.80 (12)
Equivalent (boe/d) 9,317 10,586 (12) 9,879 9,856 -
Average Selling
Price (before the
impact of financial
risk management
contracts)
Oil and liquids
($/bbl) 70.49 68.88 2 69.69 59.89 16
Natural gas ($/mcf) 3.44 4.42 (22) 3.87 4.32 (10)
Wells Drilled, Net 13.8 5.0 176 37.6 25.7 46
Undeveloped Land
at Year End (thousand
net acres) 521 540 (4)
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Notes:
Throughout this press release, all comparative figures are the previous results
of the Trust. When discussing prior periods, where applicable, references are
made to common shares, shareholders, share rights and dividends, although for
the pre-conversion period such items were trust units, unitholders, trust unit
rights and distributions, respectively.
Throughout this press release, the calculation of barrels of oil equivalent
("boe") is based on the conversion ratio that six thousand cubic feet of natural
gas is equivalent to one barrel of oil.
For net capital expenditures, amounts include capital expenditures acquired for
cash, equity issuances, acquisition costs (for years prior to 2010) and net debt
assumed on corporate acquisitions.
Funds flow from operating activities is a non-GAAP term that represents net
earnings and asset retirement expenditures except for non-cash items. Cash flows
from operating activities differ from funds flow from operating activities as a
result of changes in non-cash operating working capital.
Common shares outstanding in the pre-conversion periods include trust units plus
exchangeable shares outstanding at year end. The exchangeable shares are
converted at the exchange ratio at the end of the year.
2011 First Quarter Operational Highlights(i)
Zargon has delivered an active first quarter of 2011 that focused on new oil
exploitation drilling and the completion and tie-in of fourth quarter 2010 oil
wells. At the Taber South property in the Alberta Plains South core area, two
horizontal wells were drilled, five horizontal wells were completed and placed
on production and three horizontal producers were converted into water
injectors, thereby permitting the imminent commencement of the Mannville A south
lobe waterflood.
In the Williston Basin core area, three Torquay (Bakken) horizontal wells were
fractured and placed on production in the Sinclair and Fertile properties. To
date, three horizontal wells have been drilled and four horizontal wells
completed and placed on production for Mississippian oil exploitation targets at
Steelman and Elswick, Saskatchewan. In the Alberta Plains North core area, the
first horizontal test well has been drilled in the large oil-in-place Hamilton
Lake Viking Unit. This well is expected to be multi-frac stimulated and
production tested in the second quarter.
Following spring break-up, we will resume our one-rig continuous Williston Basin
drilling program exploiting Mississippian horizontal targets at Elswick, Weyburn
and Manor in Saskatchewan. In the Alberta Plains core areas we will proceed with
a one-rig continuous drilling program highlighted by Taber Sunburst horizontal
pool development and extensions, Hamilton Lake Viking horizontal multi-frac test
wells and the horizontal development of our Jarrow (Killam) Glauconite pool
extension.
2011 Updated Guidance(i)
For 2011, Zargon continues to budget a $55 million capital budget (exclusive of
acquisitions or dispositions) focused almost exclusively on our profitable oil
exploitation business. In addition to a 37 net well oil exploitation drilling
program, the budget emphasizes the implementation and optimization of waterflood
projects and other production optimizations that enable the maximization of oil
recoveries from existing reservoirs.
With the winter drilling program mostly completed, we are able to provide a
tighter range on our 2011 quarterly guidance estimates. Based on our existing
suite of assets and budgeted capital program, we anticipate quarterly production
rates to range from 9,300 to 9,800 barrels of oil equivalent per day, with
average oil and liquids production varying from 5,600 to 6,100 barrels of oil
per day and natural gas production ranging from 20.4 to 22.8 million cubic feet
per day.
(i) Please see comments on "Forward-looking Statements" at the end of this press
release.
CORPORATE CONVERSION
On December 31, 2010, Zargon Energy Trust (the "Trust") completed the conversion
from an income trust into a dividend paying corporation, Zargon Oil & Gas Ltd.
(the "Company" or "Zargon") pursuant to a Plan of Arrangement (the
"Arrangement") under the Business Corporations Act (Alberta). Under the
Arrangement, unitholders received, for each trust unit held, one common share of
the Company. Exchangeable shareholders received 1.84716 common shares of the
Company for each exchangeable share held as determined in accordance with the
terms of the Arrangement. As a result, at December 31, 2010, Zargon had 27.05
million common shares issued and outstanding and no remaining exchangeable
shares. There were no changes to the underlying business of the Company and the
Board of Directors and senior management remained unchanged. Additional
information regarding the Arrangement can be found in the Information Circular
dated November 10, 2010.
The conversion of the Trust into a corporation has been accounted for using the
continuity of interest method. Accordingly, the consolidated financial
statements for the year ended December 31, 2010 reflect the financial position,
results of operations and cash flows as if the Company had always carried on the
business of the Trust. All comparative figures referred to in the consolidated
financial statements and this MD&A are the previous consolidated results of the
Trust. For the convenience of the reader, when discussing prior periods, this
MD&A, where appropriate, refers to common shares, shareholders, share rights and
dividends although for the pre- conversion period, such items were trust units,
unitholders, trust unit rights and distributions, respectively.
2010 HIGHLIGHTS
Despite essentially unchanged 2010 production volumes from 2009 levels and lower
2010 natural gas prices, revenue improved in 2010 due to the year's higher
proportion of production from oil and liquids and the continued strengthening of
oil prices. Zargon's revenue increased by 15 percent to $179.47 million in 2010,
which was primarily due to a 16 percent increase in its realized average field
oil price, that was partially offset by a 10 percent decrease in the average
field natural gas price. Notwithstanding the higher revenue, funds flow from
operating activities showed a 15 percent decrease to $73.70 million due
primarily to substantial realized risk management gains recorded in 2009 that
were not repeated in 2010. Net earnings for the year were $8.92 million, a 228
percent increase from 2009. The majority of the increase in net earnings
resulted from lower non-cash unrealized risk management losses, net of increases
in depletion, depreciation and amortization and asset retirement obligation
accretion.
Net capital expenditures for 2010 totalled $72.03 million with $60.42 million
incurred on field-related activities, $1.60 million on net property
acquisitions, $9.36 million on a corporate acquisition and $0.65 million on
administrative assets. Compared to the prior year, the 2010 capital program
showed a 30 percent increase in field- related expenditures, but a 31 percent
decrease in overall net expenditures due to decreased expenditures on corporate
acquisitions. Only one corporate transaction was undertaken in 2010, which was
the acquisition of Oakmont Energy Ltd. ("Oakmont") on September 9, 2010 for
$9.36 million, that was satisfied by the issuance of 0.336 million Zargon shares
and by the assumption of approximately $3.41 million of net debt. As part of a
continuous program to upgrade its property portfolio, the Company completed a
non-core property disposition program totalling $30.88 million, which largely
funded the acquisition of Alberta oil exploitation properties totalling $32.48
million, resulting in net property acquisitions for the year of $1.60 million.
Under its field capital expenditure program for the year ended December 31,
2010, Zargon drilled, equipped and tied-in wells for $48.10 million, spent $6.93
million on undeveloped land and shot or acquired seismic at a cost of $5.39
million. Cash distributions to unitholders (excluding the Distribution/Dividend
Reinvestment Plan ("DRIP")) totalled $47.35 million during 2010 (2009 - $45.96
million).
Financial Highlights
($ millions, except for per share amounts) 2010 2009 2008
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Petroleum and natural gas revenue 179.47 155.99 229.49
Funds flow from operating activities 73.70 86.35 106.91
Per share - diluted (1) 2.80 3.64 5.18
Cash flows from operating activities 62.45 88.83 110.12
Per share - diluted (1) 2.37 3.74 5.34
Net earnings 8.92 2.72 68.29
Per share - diluted (1) 0.38 0.13 3.80
Total assets 471.65 464.38 447.60
Net capital expenditures (2) 72.03 104.59 119.73
Bank debt 115.29 76.58 77.58
Cash distributions (3) 47.35 45.96 39.09
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(1) For the convenience of the reader, the comparative information presented
in this schedule refers to common shares although, for the pre-corporate
conversion period, these items were trust units.
(2) Amounts include capital expenditures for corporate and property
acquisitions acquired for cash consideration, equity issuances, net debt
assumed and are also inclusive of transaction costs for years prior to
2010.
(3) Cash distributions represent the cash portion only and do not include
equity issued through the DRIP, which commenced in April 2010.
Cash Distributions/Dividends
Cash dividends to shareholders are at the discretion of the Board of Directors
and can fluctuate depending on funds flow from operating activities. The
Company's capital program is financed from available funds flow, equity
issuances and additional draw downs on the bank facilities, if required. The key
drivers of Zargon's funds flow are commodity prices and production volumes.
While commodity prices for both oil and liquids and natural gas continue to have
a significant effect on the Company's funds flow, the impact of the price of oil
and liquids is increasing as their proportion of total production volumes grows.
Of the 9,879 barrels of oil equivalent per day of production volumes in 2010, 57
percent was oil and liquids (43 percent natural gas), as compared to 51 percent
in 2009 when oil and liquids production was 9,856 barrels of oil equivalent per
day. In the event that oil and natural gas prices and/or production volumes are
higher than anticipated and a cash surplus develops, the surplus may be used to
increase dividends, reduce debt and/or increase the capital program. In the
event that oil and natural gas prices and/or production volumes are lower than
expected, the Company may decrease dividends, increase debt and/or decrease the
capital program.
Zargon regularly reviews its monthly dividend policy in the context of the
current commodity price environment, production levels and capital program
requirements. From November 2005 to December 2010, the distributions remained
constant at $0.18 per unit per month. Effective December 31, 2010, Zargon
converted to a dividend paying corporation with an initial dividend rate of
$0.14 per share per month. Cash distributions to unitholders declared for 2010
totalled $47.35 million (excluding the DRIP). For a further discussion, see the
"Liquidity and Capital Resources" section of this report.
For Canadian income tax purposes, the 2010 cash distributions are 100 percent
taxable income.
DETAILED FINANCIAL ANALYSIS
Petroleum and Natural Gas Revenue
Zargon derives its revenue from the production and sale of petroleum (oil and
natural gas liquids) and natural gas. Petroleum and natural gas revenue,
exclusive of the impact of financial risk management contracts, increased 15
percent to $179.47 million in 2010 from $155.99 million in 2009, primarily due
to higher oil and liquids prices. For 2010, the relative weighting of production
revenue from oil and liquids increased to 80 percent (71 percent in 2009) and 20
percent came from the sale of natural gas (29 percent in 2009). Average
production volumes in 2010 remained relatively flat at 9,879 barrels of oil
equivalent per day compared to the prior year's 9,856 barrels of oil equivalent
per day. Natural gas production in 2010 decreased 12 percent, and oil and
liquids production increased 12 percent over 2009 levels. Volume increases in
oil and liquids resulted primarily from a 2010 second quarter property
acquisition, the third quarter corporate acquisition of Oakmont and an active
Williston Basin oil exploitation program. Overall, natural gas production
declines resulted from the Company's planned de-emphasis of natural gas drilling
activity. The average field price of oil and liquids received by Zargon
increased to $69.69 per barrel in 2010, up 16 percent from $59.89 per barrel in
2009. The average Zargon realized field price of natural gas was $3.87 per
thousand cubic feet in 2010, a 10 percent decrease from $4.32 per thousand cubic
feet in 2009.
Pricing
Average for the year 2010 2009 2008
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Natural Gas:
NYMEX average daily spot price ($US/mmbtu) 4.39 3.90 8.88
AECO average daily spot price ($Cdn/mmbtu) 4.01 3.96 8.16
Zargon realized field price before the impact of
financial risk management contracts ($Cdn/mcf) 3.87 4.32 8.12
Zargon realized field price before the impact of
physical and financial risk management contracts
($Cdn/mcf) 3.84 3.80 8.06
Zargon realized field price after the impact of
physical and financial risk management contracts
($Cdn/mcf) 3.87 4.74 8.10
Zargon realized natural gas field price
differential/(premium) (1) 0.14 (0.36) 0.04
Zargon realized natural gas field price
differential before the impact of
physical and financial risk management contracts 0.17 0.16 0.10
Crude Oil:
WTI ($US/bbl) 79.54 61.80 99.65
Edmonton par price ($Cdn/bbl) 77.51 65.87 102.16
Zargon realized field price before the impact of
financial risk management contracts
($Cdn/bbl) 69.69 59.89 89.65
Zargon realized field price after the impact of
financial risk management contracts ($Cdn/bbl) 69.95 72.55 79.82
Zargon realized oil field price differential (2) 7.82 5.98 12.51
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(1) Calculated as Zargon's realized field price before the impact of
financial risk management contracts ($Cdn/mcf) as compared to AECO
average daily spot price ($Cdn/mmbtu). Note: premiums may occur as a
result of the realization of fixed price physical contracts and the
impact of Zargon receiving AECO monthly index pricing for a portion of
its natural gas production.
(2) Calculated as Zargon's realized field price before the impact of
financial risk management contracts ($Cdn/bbl) as compared to Edmonton
par price ($Cdn/bbl).
Petroleum (Oil and Natural Gas Liquids) Pricing
Zargon's field oil and natural gas liquids prices are adjusted at the point of
sale for transportation charges and oil quality differentials from an Edmonton
light sweet crude price that fluctuates with world commodity prices. In 2010,
Zargon's average oil and liquids field price, exclusive of the impact of
financial risk management contracts, increased 16 percent to $69.69 per barrel
from $59.89 per barrel in 2009 and was 22 percent lower than the $89.65 per
barrel received in 2008. The field price differential for Zargon's average
blended 28 degree API crude stream was $7.82 per barrel less than the 2010
Edmonton reference crude price, which compares to the 2009 differential of $5.98
per barrel and the 2008 differential of $12.51 per barrel. Oil and natural gas
liquids transportation expenses are included in production expenses and the oil
and liquid sales price is defined by the point of legal transfer of the product.
Natural Gas Pricing
The average field natural gas price for 2010 decreased to $3.87 per thousand
cubic feet, which is 10 percent lower than the 2009 average of $4.32 per
thousand cubic feet (before the impact of financial risk management contracts)
and 52 percent lower than the 2008 average of $8.12 per thousand cubic feet
(before the impact of financial risk management contracts). Historically,
Zargon's field prices have shown a small discount to the benchmark AECO average
daily price due to transportation tariffs beyond the Zargon sales point. The
2010 field price differential for Zargon's natural gas before the impacts of
physical and financial risk management contracts was a discount of $0.17 per
thousand cubic feet, compared to discounts of $0.16 and $0.10 per thousand cubic
feet (exclusive of the impact of physical and financial risk management
contracts) in 2009 and 2008, respectively. In 2010, the fixed price physical
contract, which is treated as part of natural gas production revenue and natural
gas pricing, created a gain of $0.33 million (2009 - $5.03 million), equivalent
to an increase of $0.04 per thousand cubic feet (2009 - $0.48 per thousand cubic
feet).
Approximately six percent of Zargon's 2010 natural gas production (2009 - six
percent) was sold under aggregator contracts pursuant to long term contracts.
The remainder of Zargon's natural gas production was sold by spot sale contracts
and received Alberta index prices.
Risk Management Activities
Zargon's commodity price risk management policy, which is approved by the Board
of Directors, allows the use of forward sales, costless collars and other
instruments for up to a 24 month term and for up to 30 percent of the combined
oil and natural gas working interest production (subject to a 50 percent maximum
limitation on any single commodity) in order to partially offset the effects of
large commodity price fluctuations. Because our risk management strategy is
protective in nature and is designed to guard the Company against extreme
effects on funds flow from sudden falls in prices and revenue, upward price
spikes tend to produce overall risk management losses.
For 2010, the total realized risk management gain was $0.47 million; compared to
a gain of $27.69 million in 2009 and a loss of $15.72 million in 2008. For 2010,
there was a $0.54 million gain (equivalent to an increase of $0.26 per barrel)
from oil financial risk management transactions partially offset by a $0.07
million loss from electricity risk management transactions. Oil swaps and
costless collars are settled against the NYMEX WTI pricing index, whereas
electricity swaps are settled against the AESO pricing index. Overall, the
average crude oil price realized for 2010 was slightly less than the prices
inherent in the Company's 2010 risk management contracts, which resulted in a
modest realized risk management gain for the year.
Zargon's management considers financial risk management contracts to be
effective on an economic basis, but has decided not to designate these contracts
as hedges for accounting purposes, and, accordingly, an unrealized gain or loss
on these contracts is recorded based on the fair value (mark-to-market) of the
contracts at year end. The 2010 net unrealized risk management loss totalled
$10.80 million, which compares to a $36.39 million net unrealized risk
management loss in 2009 (2008 - $44.38 million gain). Specifically, the 2010 net
unrealized risk management loss resulted from financial oil contract losses
($10.87 million) and financial electricity contract gains ($0.07 million). These
unrealized risk management gains or losses were generated by the change over the
reporting period in the mark-to-market valuation of Zargon's future financial
contracts. Gains or losses on fixed price physical contracts are recorded when
settled and included in petroleum and natural gas revenue and in the statements
of earnings and comprehensive income and accumulated earnings. No mark-to-market
valuation is recorded on these contracts.
Royalties
Royalties include payments made to the Crown, freehold owners and third parties.
Reported royalties also include the cost of the Saskatchewan Resource Surcharge
("SRC") and the cost of North Dakota state oil production/extraction taxes.
During 2010, total royalties were $31.94 million, an increase of 16 percent from
$27.42 million in 2009. The variations in royalty rates generally track changes
in production volumes and prices. Commencing in 2009, the oil and natural gas
royalty structure changed for Alberta production volumes. Further discussion
regarding this issue is provided later in this report under the headings
"Capital Expenditures" and "Alberta Royalty and Tax Regime". Reflecting the
relatively lower commodity prices and modified royalty structure, on a
consolidated basis, royalties, as a percentage of gross revenue, were 17.8
percent in 2010 compared to 17.6 percent in 2009 and 20.3 percent in 2008. On a
commodity basis, natural gas royalties averaged 10.9 percent in 2010, a slight
increase from the previous year's average of 10.4 percent. Oil royalties
averaged 19.6 percent, down slightly from the prior year rate of 20.5 percent.
The decrease in oil royalties is primarily related to initial low royalty rate
incentives on certain new oil production wells in Saskatchewan and Alberta.
During 2010, 54 percent (2009 - 49 percent) of the total royalties were paid to
provincial and state governments, with the remainder paid to freehold owners and
other third parties. The SRC charges were $1.30 million in 2010, an increase
from $1.08 million in the prior year and a decrease from $1.63 million in 2008,
reflecting the upward trend in Saskatchewan oil revenue. North Dakota state oil
production/extraction taxes increased to $1.10 million in 2010 from $0.97
million in the prior year primarily due to increased sales revenue (higher oil
prices received), partially offset by decreased oil production for the US
operations.
The Government of Alberta announced royalty formula changes for both oil and
liquids and for natural gas, effective January 1, 2011, which are expected to
have a positive impact on royalty costs for 2011 and beyond. For oil and
liquids, the maximum royalty rate has been reduced to 40 percent from 50 percent
and for natural gas the maximum rate has been reduced to 36 percent from 50
percent. Additionally, the price component of each formula has been changed to
moderate the increase in rates at the highest price level.
Production Expenses
Zargon's production expenses decreased one percent to $47.19 million in 2010
from $47.56 million in 2009, reflecting, in part, Zargon's effort to improve our
efficiencies and to dispose of many of the higher cost properties acquired in
recent corporate acquisitions. On a per unit of production basis, production
expenses decreased one percent to $13.09 per barrel of oil equivalent from
$13.22 in 2009 ($11.79 in 2008).
Natural gas production expenses in 2010 rose two percent to $2.18 per thousand
cubic feet from $2.14 per thousand cubic feet in 2009, due mainly to decreased
natural gas production volumes.
Oil production expenses decreased in 2010 to $13.11 per barrel, a decline of
three percent from $13.56 per barrel in 2009. The primary reason for the
decrease is due to higher production volumes, which more than offset charges due
to increased workovers, and increased repairs and annual maintenance programs.
For 2011, higher production expenses on a per unit of production basis are
expected due to Zargon's increased weighting to the higher cost oil commodity,
increased service and field costs due to higher industry activity levels and due
to the potential impact of new accounting standards on our business.
Operating Netbacks
The average oil and liquids price received, after realized risk management
gains/losses, in 2010 of $69.95 per barrel was four percent lower than the
$72.55 per barrel received in 2009. The average natural gas price received,
after realized risk management gains/losses, in 2010 of $3.87 per thousand cubic
feet was 18 percent below the $4.74 per thousand cubic feet received in 2009.
Operating netbacks decreased commensurately. Oil and liquids netbacks at $43.21
per barrel were down slightly from $46.72 per barrel in 2009, due to significant
reductions in realized risk management gains. Natural gas netbacks decreased 41
percent to $1.27 per thousand cubic feet from $2.15 per thousand cubic feet in
2009. On a barrel of oil equivalent basis, overall 2010 operating netbacks
decreased eight percent to $27.95 from $30.22 in 2009.
Operating Netbacks
2010 2009
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Oil and Natural Oil and Natural
Liquids Gas Liquids Gas
($/bbl) ($/mcf) ($/bbl) ($/mcf)
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Production revenue 69.69 3.87 59.89 4.32
Realized risk management gain 0.26 - 12.66 0.42
Royalties (13.63) (0.42) (12.27) (0.45)
Production costs (13.11) (2.18) (13.56) (2.14)
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Operating netbacks 43.21 1.27 46.72 2.15
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General and Administrative Expenses
Gross general and administrative costs increased 11 percent in 2010 to $19.27
million from $17.38 million in 2009. On a per unit of production basis, net
general and administrative costs increased 10 percent to $4.23 per barrel of oil
equivalent compared to $3.83 per barrel of oil equivalent in 2009 and $3.08 in
2008. Trending upwards from 2008 and 2009, the 2010 increased general and
administrative costs on a per unit of production basis was primarily due to
increased technical staff and consultant costs and one-time employment related
costs of $1.15 million or $0.32 per barrel of equivalent.
General and Administrative Expenses
($ millions, except as noted) 2010 2009 2008
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Gross general and administrative expenses 19.27 17.38 13.80
Overhead recoveries (4.03) (3.61) (3.35)
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Net general and administrative expenses 15.24 13.77 10.45
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Net expense after recoveries ($/boe) 4.23 3.83 3.08
Number of office employees at year end 59 57 53
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Transaction Costs
Transaction costs include legal and consulting fees associated with business
combinations such as property acquisitions/divestitures and corporate
acquisitions, as well as fees associated with corporate reorganizations. CICA
Handbook Section 1582 "Business Combinations", which was adopted by the Company
effective January 1, 2010, requires that transaction costs associated with
business combinations be expensed in the consolidated statements of earnings and
comprehensive income. This change is applied prospectively and has not impacted
prior periods, for which transaction costs were capitalized as part of the
purchase price allocation of corporate and property acquisitions/dispositions.
For the year ended December 31, 2010, transaction costs were $1.26 million or
$0.35 per barrel of oil equivalent, which included legal and consulting fees
associated with property acquisitions and divestitures, the Oakmont corporate
acquisition, as well as costs associated with Zargon's conversion from a Trust
to a Corporation.
Interest and Financing Charges
Zargon's borrowings are through its syndicated bank credit facilities. Interest
and financing charges were $4.89 million compared to $3.02 million in 2009 and
$4.91 million in 2008. An increase in the average debt level and higher
borrowing costs for 2010 were the primary reasons for the increase in interest
and financing charges. Zargon's effective interest and financing charge rate was
4.9 percent on an average outstanding bank debt of $99.50 million in 2010,
compared to 3.5 percent on an average bank debt of $85.38 million in 2009, and
5.2 percent on an average bank debt of $95.07 million in 2008. At year end 2010,
Zargon's bank debt, net of working capital (excluding unrealized risk management
assets/liabilities and future income taxes), totalled $124.39 million, up 41
percent from $88.01 million at December 31, 2009. The increase in average and
year end debt levels was the result of the field capital expenditure program and
net debt acquired from corporate and property acquisitions. For more information
on Zargon's credit facilities, see the "Bank Debt" section of this report.
Current Income Taxes
Current income taxes for 2010 were $2.15 million compared to $2.49 million in
2009. Of the total, $1.93 million is due to current taxes incurred in the United
States compared to $2.21 million in 2009. On a year-over-year comparison,
current income taxes have decreased due to a reduction in 2010 taxable income in
the United States related to an increased capital drilling program in 2010,
offset slightly by higher revenue attributed to increased oil prices. The
remaining current tax amounts relate to withholding taxes on US dividends
declared from Zargon's US subsidiary to its parent corporation and Canadian
provincial capital taxes, which, in aggregate, totalled $0.22 million in 2010
compared to $0.28 million in 2009.
Tax pools as at December 31, 2010 were approximately $346 million, an increase
from the $293 million of tax pools available to Zargon at the end of 2009, due
to the increased field capital program and tax pools acquired in the Oakmont
acquisition. The Company, post corporate conversion, is a taxable entity under
the Income Tax Act (Canada); however, based on the current forward commodity
strip, these tax pools are calculated to effectively shelter the Company from
paying cash taxes in Canada until 2014. Under the Trust structure through 2010,
distributions were deductible; but as a corporation dividends will not be
deductible, which will result in reduced future tax recoveries.
For Canadian income tax purposes, 2010 cash distributions are 100 percent
taxable income.
Company Netbacks
Despite higher oil prices and marginally lower production costs, operating
netbacks declined in 2010 due mainly to lower realized risk management gains. On
a barrel of oil equivalent basis, revenue of $49.77 in 2010 was 15 percent
higher, while operating netbacks and funds flow netbacks decreased eight percent
to $27.95 and 15 percent to $20.44 per barrel of oil equivalent, respectively.
Company Netbacks
($/boe) 2010 2009 2008
----------------------------------------------------------------------------
Petroleum and natural gas revenue 49.77 43.36 67.77
Realized risk management gain/(loss) 0.13 7.70 (4.65)
Royalties (8.86) (7.62) (13.77)
Production costs (13.09) (13.22) (11.79)
----------------------------------------------------------------------------
Operating netbacks 27.95 30.22 37.56
General and administrative (4.23) (3.83) (3.08)
Transaction costs(1) (0.35) - -
Interest and financing charges (1.35) (0.84) (1.45)
Asset retirement expenditures (0.99) (0.85) (0.26)
Current income taxes (0.59) (0.69) (1.20)
----------------------------------------------------------------------------
Funds flow netbacks 20.44 24.01 31.57
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Prior to 2010, transaction costs incurred on business combinations were
capitalized.
Funds Flow from Operating Activities
In 2010, the increase in revenue was more than offset by the decrease in
realized risk management gains from the hedging program and increased royalties
paid to result in a 15 percent decrease in funds flow from operating activities
to $73.70 million, compared to $86.35 million in 2009 and $106.91 million in
2008. The corresponding funds flow per diluted share was $2.80 in 2010, a 23
percent decrease from $3.64 in 2009 and a 46 percent decrease from $5.18 in
2008. The diluted per share statistics reflect an 11 percent increase in the
weighted average outstanding shares to 26.33 million in 2010 from 23.75 million
in 2009. The 2009 weighted average outstanding shares were also 15 percent
higher than the 2008 amount of 20.63 million.
The following table summarizes the variances in funds flow from operating
activities between 2010 and 2009. It demonstrates that the variance (decrease in
funds flow from operating activities) was caused primarily by a decrease in
realized risk management gains in excess of increased realized commodity prices
and higher royalties due to higher market prices.
$ Per
Diluted Per Share
Common Percent
$ Millions Share Variance
----------------------------------------------------------------------------
Funds flow from operating activities - 2009 86.35 3.64 -
Price variance 23.05 0.88 24
Volume variance 0.41 0.02 1
Realized risk management gains (27.21) (1.03) (28)
Royalties (4.52) (0.17) (5)
Expenses:
Production 0.38 0.01 1
General and administrative (1.47) (0.06) (2)
Transaction costs (1.26) (0.05) (1)
Interest and financing charges (1.87) (0.07) (2)
Asset retirement expenditures (0.51) (0.02) (1)
Current taxes 0.35 0.01 -
Weighted average common shares - diluted - (0.36) (10)
----------------------------------------------------------------------------
Funds flow from operating activities - 2010 73.70 2.80 (23)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Depletion and Depreciation
In 2010, Zargon's depletion and depreciation provision increased three percent
to $66.42 million, compared to $64.72 million in 2009 and $59.64 million in
2008. The higher charges reflect a two percent increase in the charge on a per
barrel of oil equivalent basis. Depletion and depreciation charges calculated on
a unit of production method are based on total proved reserves with a conversion
of six thousand cubic feet of natural gas being equivalent to one barrel of oil.
The 2010 depletion calculation includes $20.29 million of future capital
expenditures to develop the Company's reserves, but excludes $25.16 million of
unproven properties relating to undeveloped land.
Zargon's depletion and depreciation, on a barrel of oil equivalent basis,
increased two percent in 2010 to $18.42 from $17.99 in 2009 and also increased
five percent from the 2008 rate of $17.61.
Accretion of Asset Retirement Obligations
For the year ended December 31, 2010, the non-cash accretion expense for asset
retirement obligations was $3.52 million compared to $2.74 million in 2009 and
$2.18 million in 2008. The year-over-year increases are due to changes in the
estimated future liability for asset retirement obligations as a result of wells
added through Zargon's drilling program and wells acquired with the recent
property and Oakmont corporate acquisitions. The significant assumptions used in
this calculation are a credit adjusted risk-free rate of 7.5 percent, an
inflation rate of two percent and payments to settle the retirement obligations
occurring over the next 40 years, with the majority of the costs being incurred
after 2020. The estimated net present value of the total asset retirement
obligation was $42.98 million as at December 31, 2010, based on a total future
liability of $171.10 million.
Share-Based Compensation
Share-based compensation was $1.45 million in 2010, $0.19 million higher than
the $1.26 million expense in 2009. The increase was the result of the timing of
2010 grants and a general increase in the valuation of these grants. Zargon will
continue to use fair value methodologies for future share rights grants. These
non-cash expenses will be recurring charges in future years if Zargon continues
to grant employees and directors share rights.
In conjunction with conversion to a corporation, Zargon's two original Trust
Unit Rights Incentive Plans were amended and restated as Common Share Rights
Incentive Plans. Under these plans, directors, officers, employees and other
service providers of the Company possess rights to acquire common shares at
their option of either the original exercise price or a "modified price" as
calculated per the provisions of the relevant plan. The Common Share Rights
Incentive Plan (2007) (the "Old Plan") provides for a modified price based on
the increment of the amount by which monthly distributions/dividends exceed a
monthly return of 0.833 percent of the Company's recorded net book value of oil
and natural gas properties (as defined in the Old Plan). Under the Common Share
Rights Incentive Plan (2009) (the "New Plan"), if the monthly
distribution/dividend exceeds the monthly return of 0.833 percent of the
Company's recorded net book value of oil and natural gas properties (as defined
in the New Plan), the entire amount (not the increment) of the
distribution/dividend is deducted from the original grant price. Rights granted
under either Plan generally vest over a three-year period and expire
approximately five years from the grant date. Zargon uses a fair value
methodology to value the common share rights grants. The Company is authorized
to issue up to an aggregate of 2.13 million share rights; however, the number of
shares reserved for issuance upon exercise of the options shall not, at any
time, exceed 10 percent of the aggregate number of the total outstanding shares.
Management does not intend on granting any further rights under either one of
these two plans.
In addition to their approval of the Plan of Arrangement on December 15, 2010,
securityholders also approved a new share-based compensation plan ("Share Award
Plan") effective January 1, 2011. Under the Share Award Plan, directors,
officers, employees and other service providers are granted the right to receive
a defined number of shares in the future, which increases commensurately with
each dividend declared by the Company after the grant date. The awards vest
equally over four years and expire five years after grant date. Holders may
choose to exercise upon vesting or at any time thereafter, with forfeiture of
any shares not exercised by the expiry date. No awards were issued under this
plan until subsequent to December 31, 2010.
Unrealized Foreign Exchange
Unrealized foreign exchange gains of $0.04 million in 2010 compared to losses of
$0.18 million for 2009. Gains and losses result from translation of Zargon's US
subsidiaries into Canadian dollars at rates as determined under the temporal
method of converting foreign subsidiaries as required by Canadian GAAP. The
volatility in the US/Cdn dollar has created non-cash translation gains/losses as
recorded in Zargon's statement of earnings and comprehensive income.
Future Income Taxes
The provision for the future tax recovery for 2010 was $14.88 million when
compared to a future tax recovery of $18.95 million in 2009 and an expense of
$12.75 million in 2008. As a Trust, Zargon's future tax obligations were
reduced, as distributions were 100 percent deductible. The 2010 future tax
recovery, when compared to the 2009 prior year recovery, is impacted by the
decrease in losses before income taxes for the period as a result of previously
mentioned higher oil prices net of increased unrealized risk management losses,
transaction costs, and interest and finance charges.
Non-Controlling Interest - Exchangeable Shares
According to the January 19, 2005 CICA pronouncement, EIC-151 "Exchangeable
Securities Issued by Subsidiaries of Income Trusts", Zargon Energy Trust was
required to reflect the exchangeable securities issued by its subsidiary as
either a non-controlling interest or debt on the consolidated balance sheet
unless they met certain criteria. The exchangeable shares were publicly traded
and had an expiry term, which could be extended at the option of the Board of
Directors. Therefore, these securities were considered by EIC-151 to be
transferable to third parties and to have an indefinite life. EIC-151 states
that if these criteria are met, the exchangeable shares should be reflected as a
non-controlling interest. Prior to 2005, these exchangeable shares were
reflected as a component of unitholders' equity. Additionally, in accordance
with EIC-151, and given the circumstances in Zargon's case, each redemption of
exchangeable shares was accounted for as a step-purchase and resulted in an
increase in property and equipment and in the future income tax liability. This
treatment ceased with the Company's early adoption of the CICA Handbook Section
1602 "Non Controlling Interests" effective January 1, 2010, whereby redemptions
subsequent to that date have been recorded against accumulated earnings rather
than as increases to property and equipment and future taxes. The related
EIC-151 was also updated for this new Handbook Section and for 2010 requires
that the non- controlling interest be reflected as a component of equity, which
has been reflected in the Company's balance sheet for the year ended December
31, 2010 and 2009.
During the year, the Company had increased its non-controlling interest by $0.83
million (2009 - $1.04 million) on the Company's consolidated balance sheets
immediately prior to the December 31, 2010 corporate conversion. Consolidated
net earnings for 2010 had been reduced for net earnings attributable to the
non-controlling interest by $1.10 million (2009 - $0.34 million). In accordance
with EIC-151 and Handbook Section 1581, each redemption prior to 2010 was
accounted for as a step-purchase and resulted in increases for 2009 in property
and equipment of $0.97 million and in the future income tax liability of $0.27
million. In accordance with Handbook Section 1582, redemptions during 2010 were
recorded as a decrease to accumulated earnings, which totalled $1.26 million.
Prior to the corporate conversion, the cumulative impact to date of the
application of EIC-151 for redemption of exchangeable shares was an increase to
gross property and equipment of $56.13 million (for prior years' depletion
impact see note 5 in the audited consolidated financial statements), to
shareholders' capital and non-controlling interest of $69.27 million, to future
income tax liability of $18.46 million, a decrease to accumulated earnings of
$1.26 million and an allocation of net earnings to exchangeable shareholders of
$30.34 million. Funds flow from operating activities were not impacted by this
accounting treatment.
As part of the conversion to a corporation on December 31, 2010, all outstanding
exchangeable shares were converted to common shares of the Company at an
exchange ratio of 1.84716. As a result, 3.12 million shares were issued at a
fair value of $68.06 million and recorded as shareholders' capital, the
non-controlling interest was eliminated and the offset was recorded as a
decrease to accumulated earnings of $42.41 million which, together with the
aforementioned $1.26 million impact of redemptions during 2010, generated an
accumulated deficit of $31.47 million. Pursuant to the Arrangement, on December
31, 2010, the shareholders' capital was reduced by $31.47 million (the amount of
the accumulated deficit) resulting in an accumulated earnings/deficit balance of
zero on December 31, 2010.
Net Earnings
Zargon's 2010 net earnings were $8.92 million, a 228 percent increase from $2.72
million in 2009. The 2008 net earnings were $68.29 million. The net earnings
track the funds flow from operating activities for the respective periods
modified by asset retirement expenditures and non-cash charges, which, in 2010
were primarily related to depletion and depreciation, unrealized risk management
losses and future income tax recoveries. On a per diluted share basis, 2010 net
earnings were $0.38 compared to net earnings of $0.13 in 2009 and $3.80 in 2008.
The 2010 net earnings were 12 percent of funds flow from operating activities,
an improvement over 2009 when net earnings represented three percent of funds
flow from operating activities, primarily reflecting the increase in revenue due
to improved oil prices and proportionately higher oil production volumes and a
decrease in non-cash charges for unrealized risk management losses. Net earnings
were 64 percent of funds flow from operating activities in 2008.
Capital Expenditures
Total net capital expenditures (including net property acquisitions, equity
consideration and net debt assumed for the Oakmont corporate acquisition) in
2010 of $72.03 million decreased 31 percent from $104.59 million in 2009, and
was highlighted by an increase in Zargon's field capital expenditure program of
30 percent in 2010 to $60.42 million from $46.45 million in 2009. In 2010,
Zargon drilled 46 gross (37.6 net) wells compared to 29 gross (25.7 net) wells
in 2009 and, as a result, drilling and completion expenditures increased by 54
percent to $33.69 million. Of the total 2010 field capital expenditures
(excluding corporate and net property acquisitions), $20.30 million were
expended on Alberta Plains North, $10.89 million on Alberta Plains South and
$29.23 million on Williston Basin properties. Additionally, $0.65 million was
incurred corporately on leasehold improvements and administrative assets and
$10.96 million was attributed to the net property and corporate acquisitions.
Field capital expenditures for the 2010 year are net of Alberta drilling credits
which totalled $3.09 million and $1.66 million in the respective Alberta Plains
North and Alberta Plains South core areas. Alberta drilling credits are designed
to encourage the execution of new drilling projects in Alberta and were
announced in 2009 in response to the slow-down in drilling throughout the
province. The drilling credit is based on a $200 per metre credit on total
metres drilled with a cap based on production levels and Alberta Crown royalties
paid. The Alberta drilling incentive program expires on March 31, 2011.
Capital Expenditures
($ millions) 2010 2009 2008
----------------------------------------------------------------------------
Undeveloped land 6.93 5.60 8.14
Geological and geophysical (seismic) 5.39 3.71 4.44
Drilling and completion of wells 33.69 21.94 27.66
Well equipment and facilities 14.41 15.20 13.11
----------------------------------------------------------------------------
Exploration and development 60.42 46.45 53.35
----------------------------------------------------------------------------
Property acquisitions (1) 32.48 1.17 6.41
Property dispositions (30.88) (0.13) (0.22)
----------------------------------------------------------------------------
Net property acquisitions/(dispositions) (1) 1.60 1.04 6.19
----------------------------------------------------------------------------
Corporate acquisitions assigned to property and
equipment (2) 9.36 56.34 59.85
----------------------------------------------------------------------------
Total net capital expenditures excluding
administrative assets (1) (2) 71.38 103.83 119.39
Administrative assets 0.65 0.76 0.34
----------------------------------------------------------------------------
Total net capital expenditures (1) (2) 72.03 104.59 119.73
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Amounts include capital expenditures acquired for cash and equity
issuances.
(2) Amounts include capital expenditures acquired for cash, equity
issuances, acquisition costs for transactions in 2009 and 2008 and net
debt assumed on corporate acquisitions.
Corporate Acquisition
On September 9, 2010, the Company acquired all of the issued and outstanding
common shares of Oakmont Energy Ltd. ("Oakmont"), a private oil and gas company,
for a total consideration of 335,574 Zargon common shares and the assumption of
approximately $3.41 million of net debt for a total transaction value of $9.36
million. The results of operations for Oakmont have been included in the
consolidated financial statements since September 9, 2010.
Liquidity and Capital Resources
In 2010, the summation of the funds inflows coming from the funds flow from
operating activities ($73.70 million) plus the issuance of common shares ($8.31
million - arising from the acquisition of Oakmont and share right exercises) and
the increase in bank debt of $38.71 million exceeded the summation of the funds
outflows pertaining to the net capital expenditure program ($72.03 million) and
the cash distributions to shareholders ($47.35 million) by $1.34 million.
Zargon's financing philosophy and the three sources of funding are as follows:
-- Internally generated funds flow from operating activities provides the
basic level of funding for the Company's annual capital expenditures
program and for distributions/dividends to shareholders.
-- Debt may be utilized for acquisitions or to expand capital programs when
it is deemed appropriate. As at December 31, 2010, the Company had $180
million in syndicated committed credit facilities of which $64.71
million or 36 percent was unutilized.
-- New equity, if available and if on favourable terms, can be utilized for
acquisitions or to expand capital programs.
Cash Distributions Analysis
($ millions) 2010 2009 2008
----------------------------------------------------------------------------
Cash flows from operating activities 62.45 88.83 110.12
Net earnings 8.92 2.72 68.29
Cash distributions relating to the period (1) (47.35) (45.96) (39.09)
----------------------------------------------------------------------------
Excess of cash flows from operating activities
over cash distributions 15.10 42.87 71.03
Excess (shortfall) of net earnings over cash
distributions (38.43) (43.24) 29.20
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Cash distributions represent the cash portion only and do not include
equity issued through the DRIP, which commenced in April 2010.
During the 12 months of 2010, Zargon maintained a monthly distribution of $0.18
per unit and subsequent to the conversion to a corporation effective December
31, 2010, has commenced with an initial monthly dividend of $0.14 per share.
Management monitors the Company's distribution/dividend policy with respect to
forecasted net cash flows, debt levels and capital expenditures. Going forward,
Zargon's cash dividends are discretionary to the extent that these dividends are
in compliance with Section 43 of the Business Corporations Act (Alberta) and do
not cause a breach of the financial covenants under Zargon's credit facilities.
As a crude oil and natural gas company, Zargon's reserve base is depleted with
production and Zargon, therefore, relies on ongoing exploration, development and
acquisition activities to replace reserves and to offset production declines.
The success of these exploration, development and acquisition capital programs,
along with commodity price fluctuations and the Company's ability to manage
costs, are the main factors influencing the sustainability of the Company's
distributions/dividends.
For the year ended December 31, 2010, cash flows from operating activities
(after changes in non-cash working capital) of $62.45 million exceeded cash
distributions of $47.35 million. This was consistent with the year ended
December 31, 2009, in which cash flows from operating activities (after changes
in non-cash working capital) of $88.83 million exceeded cash distributions of
$45.96 million.
For the year ended December 31, 2010, cash distributions of $47.35 million
exceeded net earnings of $8.92 million. Net earnings included significant
non-cash charges ($68.35 million in 2010), particularly unrealized risk
management losses and depletion and depreciation that do not impact cash flows.
For the year ended December 31, 2009, cash distributions of $45.96 million
exceeded net earnings of $2.72 million. Net earnings also include fluctuations
in future income taxes due to changes in tax rates and tax rules. In the
instances where distributions/dividends exceed net earnings, a portion of the
cash distribution/dividend paid may represent an economic return of the
shareholders' capital.
For the year ended December 31, 2010, cash distributions and net capital
expenditures totalled $119.38 million ($113.43 million excluding the $5.95
million of equity issuances attributed to the Oakmont acquisition), which was
$56.93 million higher than cash flows from operating activities (after changes
in non-cash working capital) of $62.45 million. For the year ended December 31,
2009, cash distributions and net capital expenditures totalled $150.55 million,
which was $61.72 million higher than cash flows from operating activities (after
changes in non- cash working capital) of $88.83 million. Zargon relies on access
to debt and capital markets to the extent cash distributions/dividends and net
capital expenditures exceed cash flows from operating activities (after changes
in non-cash working capital). Over the long term, Zargon expects to fund future
cash dividends and capital expenditures with its cash flows from operating
activities; however, it will continue to fund acquisitions and growth through
additional debt and equity issuances. In the crude oil and natural gas industry,
because of the nature of reserve reporting, the natural reservoir declines and
the risks involved in capital investment, it is not possible to distinguish
between capital spent on maintaining productive capacity and capital spent on
growth opportunities, therefore, maintenance capital is not disclosed separately
from development capital spending.
On April 9, 2010, the Company implemented a Distribution Reinvestment Plan.
Under the Arrangement, the Distribution Reinvestment Plan has been amended and
restated as a Dividend Reinvestment Plan ("DRIP") and all existing participants
in the Distribution Reinvestment Plan are deemed to be participants in the DRIP.
Canadian shareholders are entitled to reinvest monthly cash
distributions/dividends in additional shares of the Company. At the discretion
of the Company, these additional shares will be issued from Treasury at 95
percent of the "weighted average closing price". For the purposes of the shares
issued, the "weighted average closing price" is calculated as the weighted
average trading price of shares for the five days prior to the
distribution/dividend payment date.
Capital Sources and Uses
($ millions) 2010 2009 2008
----------------------------------------------------------------------------
Funds flow from operating activities 73.70 86.35 106.91
Change in bank debt 38.71 (1.00) 20.71
Issuance of common shares 8.31 65.14 25.08
Cash distributions to unitholders (1) (47.35) (45.96) (39.09)
Changes in working capital and other (1.34) 0.06 6.12
----------------------------------------------------------------------------
Total capital sources 72.03 104.59 119.73
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) Cash distributions represent the cash portion only and do not include
equity issued through the DRIP, which commenced in April 2010.
Funds Flow from Operating Activities
It is anticipated that Zargon's 2011 exploration and development capital budget
and cash dividends to shareholders will be financed through the Company's funds
flow from operating activities and its credit facilities. Funds flow is
partially influenced by factors that the Company cannot control, such as
commodity prices, the US/Canadian dollar exchange rates and interest rates.
Zargon's 2011 estimated sensitivity to moderate fluctuations in these key
business parameters is shown in the accompanying table.
Funds Flow Sensitivity Summary
Change in 2011 Funds Flow
($ millions) ($/share)
----------------------------------------------------------------------------
Change of $1.00 US/bbl in the price of WTI oil 1.91 0.07
Change in oil production of 100 bbl/d 2.29 0.09
Change of $0.10 US/mcf in the price of NYMEX natural gas 0.68 0.03
Change in natural gas production of one mmcf/d 1.14 0.04
Change of $0.01 in the $US/$Cdn exchange rate 1.94 0.07
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Bank Debt
On June 29, 2010, Zargon amended and renewed its syndicated committed credit
facilities, which maintained the available facilities and borrowing base of $180
million. These facilities consist of a $170 million tranche available to the
Canadian borrower and a US $8 million tranche available to the US borrower. A
$300 million demand debenture on the assets of the subsidiaries of the Company
has been provided as security for these facilities.
The facilities are fully revolving for a 364-day period with the provision for
an annual extension at the option of the lenders and upon notice from Zargon's
management. The next renewal date is June 28, 2011. Should the facilities not be
renewed, they convert to one year non-revolving term facilities at the end of
the revolving 364-day period. Repayment would not be required until the end of
the non-revolving term, and, as such, these facilities have been classified as
long term debt. These facilities continue to be available for general corporate
purposes and the potential acquisition of additional oil and natural gas
properties, such as those most recently acquired through property acquisitions
and the corporate acquisition of Oakmont, which were funded by bank debt and
equity issuances. Zargon reviews its compliance with its bank debt covenants on
a quarterly basis and had no violations as at December 31, 2010. The Company
converted to a corporation from its previous trust structure on December 31,
2010. In order for this conversion to have occurred, Zargon had to ensure that
all legal and regulatory requirements were satisfied. Zargon's current
syndicated credit facility was amended and restated effective January 1, 2011 to
reflect the corporate conversion.
Through to the 2011 renewal, it is anticipated that Zargon's borrowing costs
will be higher as general debt pricing, standby fees and extension fees have
increased slightly due to current debt levels. Interest rates fluctuate under
the syndicated facilities with Canadian prime, US prime and US base rates plus
an applicable margin between 100 basis points and 250 basis points (2009 - 125
and 275 basis points, respectively), as well as with Canadian banker's
acceptance and LIBOR rates plus an applicable margin between 250 basis points
and 400 basis points (2009 - 275 and 425 basis points, respectively).
At December 31, 2010, $115.29 million (December 31, 2009 - $76.58 million) had
been drawn on the syndicated committed credit facilities with any unused amounts
subject to standby fees.
In the normal course of operations, Zargon enters into various letters of
credit. At December 31, 2010, the approximate value of outstanding letters of
credit totalled $1.25 million (December 31, 2009 - $0.61 million).
Zargon's debt net of working capital (excluding unrealized risk management
assets/liabilities and future income taxes) of $124.39 million at December 31,
2010 was equivalent to 169 percent of the 2010 funds flow from operating
activities of $73.70 million. At December 31, 2009, the debt net of working
capital (excluding unrealized risk management assets/liabilities and future
income taxes) was $88.01 million, equivalent to 102 percent of the 2009 funds
flow from operating activities of $86.35 million.
Equity
At March 9, 2011, Zargon Oil & Gas Ltd. had 27.095 million common shares
outstanding. Pursuant to the common share rights incentive plans, there are
currently an additional 1.498 million common share incentive rights issued and
outstanding.
During 2010, 12.831 million Zargon common shares traded on the Toronto Stock
Exchange with a high trading price of $22.59 per share, a low of $16.99 per
share and a closing price of $22.46 per share. The 2010 trading statistics show
a seven percent year-over-year increase in trading volume and a 17 percent
increase in the closing share price. Zargon's market capitalization at year end
2010, was approximately $607 million, compared to approximately $501 million at
the end of 2009.
Pursuant to the Arrangement, 23.93 million shares of the Company were issued in
exchange for all of the outstanding trust units of the Trust on a one-for-one
basis, 3.12 million shares of the Company were issued in exchange for all of the
outstanding exchangeable shares based on an exchange ratio of 1.84716 at the
time of conversion. Pursuant to the Arrangement, the shareholders' capital was
reduced by the deficit of the Trust of $31.47 million as of December 31, 2010.
Segmented Geographic Information
During 2010, approximately 91 percent (2009 - 90 percent) of Zargon's combined
petroleum and natural gas revenue came from Western Canadian (Alberta,
Saskatchewan and Manitoba) properties, with the remaining nine percent (2009 -
10 percent) of revenue generated in the United States (North Dakota). This shift
in weighting is due to additional revenue generated from property acquisitions
and Oakmont corporate acquisition which both were comprised of only Canadian oil
and natural gas properties.
Selected Quarterly Information
($ millions, except per share amounts) 2010
----------------------------------------------------------------------------
Q4 Q3 Q2 Q1
----------------------------------------------------------------------------
Petroleum and natural gas revenue 42.64 44.50 43.89 48.46
Funds flow from operating activities 14.60 18.49 18.38 22.24
Per share - diluted (1) 0.54 0.70 0.70 0.85
Cash flows from operating activities 8.53 20.05 12.87 21.00
Per share - diluted (1) 0.32 0.76 0.49 0.80
Net earnings/(losses) (5.30) 0.41 8.65 5.16
Per share - diluted (1) (0.22) 0.02 0.37 0.22
Cash distributions 10.99 11.92 11.88 12.55
Per share - diluted (1) 0.54 0.54 0.54 0.54
Net capital expenditures 20.29 (1.26) 34.26 18.74
Total assets 471.65 462.92 484.45 466.22
Bank debt 115.29 97.61 114.12 84.23
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Selected Quarterly Information
($ millions, except per share amounts) 2009
----------------------------------------------------------------------------
Q4 Q3 Q2 Q1
----------------------------------------------------------------------------
Petroleum and natural gas revenue 47.21 40.96 35.84 31.98
Funds flow from operating activities 24.75 22.84 20.92 17.85
Per share - diluted (1) 0.95 0.90 0.91 0.84
Cash flows from operating activities 27.86 23.30 21.94 15.73
Per share - diluted (1) 1.07 0.92 0.95 0.74
Net earnings/(losses) 0.44 4.47 (2.55) 0.37
Per share - diluted (1) 0.02 0.20 (0.13) 0.02
Cash distributions 12.45 12.22 11.26 10.03
Per share - diluted (1) 0.54 0.54 0.54 0.54
Net capital expenditures 12.87 29.32 48.96 13.44
Total assets 464.38 473.47 466.60 440.76
Bank debt 76.58 77.05 70.43 85.78
----------------------------------------------------------------------------
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(1) For the convenience of the reader, the comparative information presented
in this schedule refers to common shares although, for the pre-corporate
conversion period, these items were trust units.
Fourth Quarter 2010 Results
During the fourth quarter of 2010, Zargon's petroleum and natural gas revenues
of $42.64 million were four percent lower than the previous quarter's revenues.
Production for the 2010 fourth quarter of 9,317 barrels of oil equivalent per
day was eight percent lower than the 2010 third quarter's production of 10,094
barrels of oil equivalent per day. Compared to the previous quarter, oil
production decreased seven percent to 5,437 barrels per day due to late summer
and fall wet weather and surface access challenges that delayed the Williston
Basin horizontal drilling program, as well as Williston Basin inventory builds
and shut-ins due to pipeline apportionment restrictions. Fourth quarter natural
gas production decreased nine percent from the previous quarter to 23.28 million
cubic feet per day due to natural declines that were not offset by new
production volumes. Average field prices received during the fourth quarter,
before the impact of financial risk management contracts, were $70.49 per barrel
for oil and liquids, a four percent increase compared to the 2010 third quarter
and $3.44 per thousand cubic feet for natural gas, essentially flat from the
prior quarter. Zargon's field price differential for its blended 28 degree API
crude oil stream increased to a $9.85 per barrel discount to the Edmonton
reference crude oil price, a 38 percent increase from Zargon's average
differential of $7.13 per barrel for the first nine months of 2010.
Funds flow from operating activities was $14.60 million in the fourth quarter, a
decrease of 21 percent or $3.89 million from the prior quarter. A comparative
analysis of the primary factors that caused this quarter-over-quarter decrease
is as follows:
-- Fourth quarter 2010 petroleum and natural gas revenues of $42.64 million
were four percent lower than the 2010 third quarter revenue of $44.50
million. This revenue decrease was a result of the eight percent decline
in average daily production volumes, partially offset by a four percent
increase in average realized commodity prices.
-- Realized risk management losses were $1.94 million in the fourth quarter
of 2010, a $1.75 million increase from the prior quarter's $0.19 million
loss due to increasing commodity prices. The fourth quarter net losses
resulted from losses realized on financial oil risk management contracts
($1.92 million) and on financial electricity management contracts ($0.02
million). Oil and liquids prices strengthened during the 2010 fourth
quarter.
-- Royalties for the fourth quarter were $7.33 million, a decrease of $0.33
million from the prior quarter due mainly to lower production, and as
the average royalty rate for the quarter of 17.2 percent was consistent
with the 2010 third quarter rate.
-- Production expenses were $11.54 million for the quarter, four percent
lower than the third quarter of 2010. On a per barrel of oil equivalent
basis, production expenses increased four percent to $13.47 in the
fourth quarter of 2010 compared to $12.91 in the prior quarter. This
quarterly increase was due, in part, to decreased production due to wet
weather delays pushing back on-production dates from new wells, in
addition to pipeline apportionment issues.
-- General and administrative expenses increased in the fourth quarter by
$0.34 million or 10 percent as compared to the third quarter of 2010.
-- Transaction costs of $0.77 million incurred in the fourth quarter were
72 percent higher than the $0.45 million incurred in the prior quarter,
due mainly to legal and consulting fees incurred as a result of the
December 31, 2010 corporate conversion.
-- Interest and financing charges were $1.42 million, an increase of 15
percent or $0.19 million from the prior quarter. The average debt level
increased six percent to $108.92 million compared to $102.80 million in
the third quarter of 2010, resulting in higher debt servicing charges.
Zargon's interest borrowing rates also increased during the quarter in-
line with the borrowing pricing grid established under the terms of
Zargon's credit facilities.
-- Current income taxes of $0.26 million were $0.06 million lower than in
the 2010 third quarter. The decrease was primarily due to the fourth
quarter 2010 drilling program in the US, which decreased US corporate
taxes and was partially offset by withholding tax paid on dividends
declared from Zargon's US subsidiary to its parent corporation.
-- Asset retirement expenditures reflect the actual amounts incurred to
abandon and reclaim unutilized non- producing wells. These asset
retirement expenditures totalled $0.92 million in the 2010 fourth
quarter and increased from the prior quarter amount of $0.66 million.
The difference between accretion expenses (as reflected on the
consolidated statements of earnings and comprehensive income and
accumulated earnings) and asset retirement expenditures are a result of
the timing differences between the estimating of future expenses and the
incurrence of actual expenses during the period.
Net losses for the quarter were $5.30 million, a decrease of $5.71 million
compared to the third quarter of 2010 net earnings of $0.41 million, mainly as a
result of realized and unrealized risk management losses. Net earnings track the
funds flow from operating activities for the respective periods modified by
asset retirement expenditures and non-cash charges, which included the following
for the fourth quarter of 2010:
-- Share-based compensation expense increased by $0.01 million during the
fourth quarter of 2010 to $0.36 million, a three percent increase from
the third quarter.
-- Depletion and depreciation expense decreased by $0.73 million to $16.26
million in the 2010 fourth quarter. The decreased expense was due to
lower production in the fourth quarter, despite the use of an updated
depletion and depreciation rate of $18.97 per barrel of oil equivalent,
compared to the prior quarter's $18.30 per barrel of oil equivalent
charge.
-- Unrealized risk management losses in the 2010 fourth quarter of $9.71
million were 104 percent higher than the third quarter losses of $4.76
million. These unrealized losses result from "marking-to-market"
financial risk management contracts at each period end. During the
fourth quarter, unrealized risk management losses resulted from higher
commodity pricing at the December 31, 2010 mark-to-market date when
compared to the third quarter September 30, 2010 mark-to-market date. In
particular, higher year end futures resulted in unrealized risk
management contract oil losses of $9.74 million and electricity contract
gains of $0.03 million. The realization and the expiry of certain
financial oil contracts also affect the mark-to-market amounts.
-- The provision for accretion of asset retirement obligations for the 2010
fourth quarter was $0.95 million, up four percent from the prior quarter
expense. The small quarter-over-quarter increase is due to changes in
the estimated future liability for asset retirement obligations as a
result of wells added through Zargon's drilling program, inclusive of
wells acquired/disposed of in the quarter and changes resulting from
revisions to the timing and the amounts of the original estimates of
undiscounted cash flows.
-- Unrealized foreign exchange gains of $0.05 million in the 2010 fourth
quarter compare to losses of $0.02 million for the prior quarter. Gains
and losses result from translations of Zargon's US subsidiaries into
Canadian dollars at rates as determined under the temporal method of
converting foreign subsidiaries as required by Canadian GAAP. Relative
to the closing foreign exchange rates at September 30, 2010, the
increase in the value of the Canadian dollar relative to the US dollar
has created nominal non-cash translation gains as recorded in Zargon's
income statement for the fourth quarter.
-- The future income tax recovery was $5.72 million during the quarter
compared to a future income tax recovery of $4.35 million from the third
quarter of 2010. The increase was due to a significant increase of
losses before taxes of $11.44 million compared to the third quarter
losses before taxes of $3.56 million. In summary, the fourth quarter
losses before taxes were primarily a result of higher non-cash
unrealized risk management contract losses in the quarter.
-- Reduction in losses due to non-controlling interests pertaining to
exchangeable shares was $0.68 million in the 2010 fourth quarter
compared to a reduction in earnings of $0.05 million in the third
quarter. This was due to a net loss before non-controlling interest in
the fourth quarter.
Net capital expenditures were $20.29 million during the fourth quarter of 2010,
compared to a prior quarter divestiture amount of $1.26 million (which included
$9.36 million for the Oakmont acquisition and divestitures of $21.89 million for
the disposition package). During the fourth quarter, Zargon completed a field
capital program highlighted by Sunburst horizontal oil exploitation wells in the
Alberta Plains South core area, and Mississippian and Bakken (Torquay)
horizontal oil exploitation wells in the Williston Basin core area. During the
fourth quarter of 2010, 13.8 net wells (Williston Basin - 8.1 net wells, Alberta
Plains South - 2.0 net wells, Alberta Plain North - 3.7 net wells) were drilled
compared to 4.8 net wells in the third quarter of 2010.
Cash distributions to unitholders declared for the 2010 fourth quarter totalled
$10.99 million (excluding the DRIP) ($0.18 per unit per month).
CONSOLIDATED BALANCE SHEETS
As at December 31 ($ thousands) 2010 2009
----------------------------------------------------------------------------
ASSETS (note 6)
Current
Accounts receivable 22,883 25,223
Prepaid expenses and deposits 2,191 2,013
Unrealized risk management asset (note 12) - 4,289
Future income taxes (note 13) 2,894 1,714
----------------------------------------------------------------------------
27,968 33,239
Long term deposit 653 1,845
Goodwill 2,969 2,969
Property and equipment, net (notes 4 and 5) 439,228 425,964
Future income taxes (note 13) 830 361
----------------------------------------------------------------------------
471,648 464,378
----------------------------------------------------------------------------
----------------------------------------------------------------------------
LIABILITIES
Current
Accounts payable and accrued liabilities 30,431 34,507
Cash distributions payable (note 19) 3,750 4,157
Unrealized risk management liability (note 12) 10,737 6,032
Future income taxes (note 13) - 1,219
----------------------------------------------------------------------------
44,918 45,915
Long term debt (note 6) 115,285 76,580
Unrealized risk management liability (note 12) 3,080 1,270
Asset retirement obligations (note 7) 42,979 35,468
Future income taxes (note 13) 18,190 30,327
----------------------------------------------------------------------------
224,452 189,560
----------------------------------------------------------------------------
Commitments and contingencies
(notes 6, 8, 12, 14 and 15)
SHAREHOLDERS' EQUITY
Shareholders' capital (note 8) 240,805 -
Unitholders' capital (note 8) - 188,840
Non-controlling interest - exchangeable
shares (note 9) - 26,477
Contributed surplus (note 8) 6,391 5,471
Accumulated earnings - 54,030
----------------------------------------------------------------------------
247,196 274,818
----------------------------------------------------------------------------
471,648 464,378
----------------------------------------------------------------------------
----------------------------------------------------------------------------
See accompanying notes to the consolidated financial statements.
CONSOLIDATED STATEMENTS OF EARNINGS AND COMPREHENSIVE INCOME AND
ACCUMULATED EARNINGS
For the years ended December 31
($ thousands, except per share amounts) 2010 2009
----------------------------------------------------------------------------
REVENUE
Petroleum and natural gas revenue 179,472 155,985
Unrealized risk management loss (note 12) (10,804) (36,393)
Realized risk management gain (note 12) 471 27,685
Royalties (31,937) (27,422)
----------------------------------------------------------------------------
137,202 119,855
----------------------------------------------------------------------------
EXPENSES
Production 47,185 47,564
General and administrative 15,240 13,769
Transaction costs 1,258 -
Share-based compensation (note 8) 1,446 1,263
Interest and financing charges (note 6) 4,889 3,015
Unrealized foreign exchange (gain)/loss (42) 184
Accretion of asset retirement obligations (note 7) 3,522 2,744
Depletion and depreciation 66,415 64,715
----------------------------------------------------------------------------
139,913 133,254
----------------------------------------------------------------------------
LOSSES BEFORE INCOME TAXES (2,711) (13,399)
----------------------------------------------------------------------------
INCOME TAXES (note 13)
Current 2,145 2,492
Future tax recovery (14,875) (18,947)
----------------------------------------------------------------------------
(12,730) (16,455)
----------------------------------------------------------------------------
CONSOLIDATED EARNINGS 10,019 3,056
Less net earnings attributed to non-controlling
interest (note 9) 1,097 337
----------------------------------------------------------------------------
NET EARNINGS AND COMPREHENSIVE INCOME ATTRIBUTED
TO ZARGON 8,922 2,719
----------------------------------------------------------------------------
----------------------------------------------------------------------------
NET EARNINGS PER SHARE (note 10)
Basic 0.38 0.13
Diluted 0.38 0.13
----------------------------------------------------------------------------
----------------------------------------------------------------------------
CONSOLIDATED STATEMENTS OF ACCUMULATED EARNINGS
----------------------------------------------------------------------------
Accumulated gross earnings, beginning of year 259,823 257,104
Accumulated cash distributions, beginning
of year (note 19) (205,793) (159,829)
----------------------------------------------------------------------------
ACCUMULATED EARNINGS, BEGINNING OF YEAR 54,030 97,275
Equity adjustment for exchangeable shares (note 9) (43,667) -
Cash distributions (note 19) (50,757) (45,964)
Net earnings and comprehensive income attributed
to Zargon 8,922 2,719
Reduction of deficit pursuant to the Arrangement
(notes 1 and 8) 31,472 -
----------------------------------------------------------------------------
ACCUMULATED EARNINGS, END OF YEAR - 54,030
----------------------------------------------------------------------------
----------------------------------------------------------------------------
See accompanying notes to the consolidated financial statements.
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the years ended December 31 ($ thousands) 2010 2009
----------------------------------------------------------------------------
OPERATING ACTIVITIES
Net earnings for the year 8,922 2,719
Add (deduct) non-cash items:
Non-controlling interest - exchangeable shares 1,097 337
Unrealized risk management loss 10,804 36,393
Depletion and depreciation 66,415 64,715
Accretion of asset retirement obligations 3,522 2,744
Share-based compensation 1,426 1,263
Unrealized foreign exchange (gain)/loss (42) 184
Future income tax recovery (14,875) (18,947)
Asset retirement expenditures (3,567) (3,056)
----------------------------------------------------------------------------
73,702 86,352
Changes in non-cash operating working capital
(note 16) (11,251) 2,476
----------------------------------------------------------------------------
62,451 88,828
----------------------------------------------------------------------------
FINANCING ACTIVITIES
Advances/(repayment) of bank debt 38,705 (1,001)
Cash distributions declared to unitholders (47,348) (45,964)
Exercise of share rights 2,359 1,295
Issuance of shareholders' capital, net of issue costs - 33,444
Changes in non-cash financing working capital (note 16) (408) 831
----------------------------------------------------------------------------
(6,692) (11,395)
----------------------------------------------------------------------------
INVESTING ACTIVITIES
Additions to property and equipment (93,550) (48,382)
Proceeds on disposal of property and equipment 30,878 127
Corporate acquisitions (cash portion) - (19,260)
Long term deposit 1,192 (233)
Changes in non-cash investing working capital
(note 16) 5,721 (9,685)
----------------------------------------------------------------------------
(55,759) (77,433)
----------------------------------------------------------------------------
NET CHANGE IN CASH DURING THE YEAR AND CASH,
END OF YEAR - -
----------------------------------------------------------------------------
----------------------------------------------------------------------------
See supplemental cash flow information contained in note 17.
See accompanying notes to the consolidated financial statements.
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2010 and 2009
All amounts are stated in Canadian dollars unless otherwise noted.
1. STRUCTURE OF THE COMPANY
On December 31, 2010, Zargon Energy Trust (the "Trust") completed the conversion
from an income trust into a dividend paying corporation, Zargon Oil & Gas Ltd.
("the Company" or "Zargon"), pursuant to a Plan of Arrangement (the
"Arrangement") under the Business Corporations Act (Alberta). Under the
Arrangement, unitholders received, for each trust unit held, one common share of
the Company. Exchangeable shareholders received 1.84716 common shares of the
Company for each exchangeable share held as determined in accordance with the
terms of the Arrangement. As a result, at December 31, 2010, Zargon had 27.05
million common shares issued and outstanding and no remaining exchangeable
shares. There were no changes to the underlying business of the Company and the
Board of Directors and senior management remained unchanged. Additional
information regarding the Arrangement can be found in the Information Circular
dated November 10, 2010.
The conversion of the Trust into a corporation has been accounted for using the
continuity of interest method. Accordingly, the consolidated financial
statements for the year ended December 31, 2010 reflect the financial position,
results of operations and cash flows as if the Company had always carried on the
business of the Trust. All comparative figures referred to in the consolidated
financial statements are the previous consolidated results of the Trust. For the
convenience of the reader, when discussing prior periods, the consolidated
financial statements, where appropriate, refer to common shares, shareholders,
share rights and dividends although for the pre-conversion period such items
were trust units, unitholders, trust unit rights and distributions,
respectively.
Zargon is a publicly traded corporation incorporated in Canada with its head
office located in Calgary, Alberta. The consolidated financial statements of the
Company for the years ended December 31, 2010 and December 31, 2009 comprise the
Company and its wholly owned subsidiaries. The Company is engaged in the
exploration for and development and production of oil and natural gas and
conducts many of its activities jointly with others; these financial statements
reflect only the Company's proportionate interest in such activities.
Pursuant to the Arrangement, the shareholders' capital was reduced by the amount
of the deficit on December 31, 2010 of $31.47 million.
The Company's principal business activity is the exploration for and development
and production of petroleum and natural gas in Canada and the United States
("US").
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation and Consolidation
These consolidated financial statements have been prepared by management in
accordance with Canadian generally accepted accounting principles ("GAAP").
Effective January 1, 2011, Zargon will be required to prepare consolidated
financial statements in accordance with International Financial Reporting
Standards ("IFRS"). Because a precise determination of many assets and
liabilities is dependent upon future events, the preparation of periodic
financial statements necessarily involves the use of estimates and
approximations. Accordingly, actual results could differ materially from those
estimates. The consolidated financial statements have, in management's opinion,
been properly prepared within reasonable limits of materiality and within the
framework of the Company's accounting policies summarized below.
The consolidated financial statements include the accounts of Zargon Oil & Gas
Ltd., all of its subsidiaries and a partnership. All subsidiaries and the
partnership are directly or indirectly owned and their operations are fully
reflected in the consolidated financial statements.
Revenue Recognition
Revenue associated with the sale of crude oil, natural gas, and natural gas
liquids is recognized when title and risks pass to the purchaser, normally at
the plant gate which is the pipeline delivery point for natural gas and at the
contracted delivery point for crude oil.
Joint Operations
A portion of the petroleum and natural gas operations of the Company are
conducted jointly with others, and accordingly, these consolidated financial
statements reflect only the proportionate interests of the Company in such
activities.
Property and Equipment
The Company follows the full cost method of accounting for its oil and natural
gas operations whereby all costs relating to the acquisition, exploration and
development of oil and natural gas reserves are capitalized and accumulated in
separate cost centres for Canada and the United States. Such costs include land
acquisition costs, annual carrying charges of non-producing properties,
geological and geophysical costs and costs of drilling and equipping wells.
Depletion and depreciation of petroleum, natural gas properties and equipment is
computed using the unit of production method based on the estimated proved
reserves of petroleum and natural gas before royalties determined by independent
consultants. For purposes of this calculation, reserves are converted to common
units on the basis that six thousand cubic feet of natural gas is equivalent to
one barrel of oil. A portion of the cost of petroleum and natural gas rights
relating to undeveloped properties is excluded from the depletion calculation.
Twenty percent of the year end balance of these costs is added to the depletion
base each year. Proceeds on the disposal of petroleum and natural gas properties
are applied against capitalized costs, with gains or losses not ordinarily
recognized, unless such a disposal would result in a change in the depletion
rate of 20 percent or more.
Depreciation of office equipment is provided using the declining balance method
at an annual rate of 20 percent. Leasehold improvements are depreciated over the
term of the lease.
Impairment Test
The Company applies an impairment test to petroleum, natural gas properties and
equipment costs on a quarterly basis or more frequently as events or
circumstances dictate. This impairment test is performed on both the Canadian
and US cost centres. An impairment loss exists when the carrying amount of the
Company's petroleum, natural gas properties and equipment exceeds the estimated
undiscounted future net cash flows associated with the Company's proved reserves
(before royalties). If an impairment loss is determined to exist, the costs
carried on the consolidated balance sheets in excess of the fair value of the
Company's proved and probable reserves plus the cost of unproved properties are
charged to earnings. Reserves are determined pursuant to evaluation by
independent engineers as dictated by National Instrument 51-101.
Goodwill
The Company must record goodwill relating to a corporate acquisition when the
total purchase price exceeds the fair value for accounting purposes of the net
identifiable assets and liabilities of the acquired company. The goodwill
balance is assessed for impairment annually at year end or as events occur that
could result in an indication of impairment. Impairment is recognized based on
the fair value of the reporting entity (consolidated Company) compared to the
book value of the reporting entity. If the fair value of the consolidated
Company is less than the book value, impairment is measured by allocating the
fair value of the consolidated Company to the identifiable assets and
liabilities as if the Company had been acquired in a business combination for a
purchase price equal to its fair value. The excess of the fair value of the
consolidated Company over the amounts assigned to the identifiable assets and
liabilities is the fair value of the goodwill. Any excess of the book value of
goodwill over this implied fair value of goodwill is the impairment amount.
Impairment is charged to earnings in the period in which it occurs.
Goodwill is stated at cost less impairment and is not amortized.
At December 31, 2010 an impairment test was performed and it was determined that
there was no impairment to the goodwill balance (December 31, 2009 - nil).
Asset Retirement Obligations
Zargon recognizes the fair value of an Asset Retirement Obligation ("ARO") in
the period in which it is incurred when a reasonable estimate of the fair value
can be made. The fair value of the estimated ARO is recorded as a liability,
with a corresponding increase in the carrying amount of the related asset. The
capitalized amount is depleted on the unit of production method based on proved
reserves (before royalties). The liability amount is increased each reporting
period due to the passage of time and the amount of accretion is expensed in the
period. Actual costs incurred upon the settlement of the ARO are charged against
the liability.
Financial Instruments
All financial instruments are required to be measured at fair value on initial
recognition of the instrument, except for certain related party transactions.
Measurement in subsequent periods depends on whether the financial instrument
has been classified as "held-for-trading", "available-for-sale",
"held-to-maturity", "loans and receivables", or "other financial liabilities" as
defined by the Canadian Institute of Chartered Accountants ("CICA") Handbook
Section 3855.
Financial assets and financial liabilities classified as "held-for-trading" are
measured at fair value with changes in fair value recognized in earnings.
Financial assets classified as "available-for-sale" are measured at fair value,
with changes in fair value recognized in other comprehensive income ("OCI")
until the asset is removed from the consolidated balance sheets. Financial
assets classified as "held-to-maturity", "loans and receivables" and "other
financial liabilities" are measured at amortized cost using the effective
interest method of amortization.
Derivative financial instruments are utilized to reduce commodity price risk
associated with the Company's production of oil and natural gas. The base prices
for the commodities are sometimes denominated in US dollars and the Company may
also use such financial instruments to reduce the related foreign currency risk.
Financial instruments may also be used from time to time to reduce interest rate
risk on outstanding debt. The Company does not enter into financial instruments
for trading or speculative purposes.
The Company follows a policy of using risk management instruments such as fixed
price swaps, forward sales, puts and costless collars. The objective is to
partially offset or mitigate the wide price swings commonly encountered in oil
and natural gas commodities and in so doing protect a minimum level of cash flow
in periods of low commodity prices.
Electricity price contracts are utilized to hedge anticipated purchases of
electricity to manage the Company's exposure to price fluctuations, which impact
production expenses.
The Company considers these financial risk management contracts to be effective
on an economic basis, but has decided not to designate these contracts as hedges
for accounting purposes and, accordingly, for outstanding contracts not
designated as hedges, an unrealized gain or loss is recorded based on the change
in fair value ("mark- to-market") of the contracts at each reporting period end.
These instruments have been recorded as unrealized risk management
assets/liabilities in the consolidated balance sheets.
In the case of forward sales, the instrument can sometimes be satisfied by
physical delivery. In the case of physical delivery, the payment/receipt is
recorded as part of the normal revenue stream.
Foreign currency collar and swap agreements are utilized to manage the risk
inherent in producing commodities whose price is based directly or indirectly on
US dollars, using notional principal amounts equal to the projected monthly
revenue from their sale. Payments or charges are calculated and paid according
to the terms of the agreement, usually with monthly settlement.
The Company had no interest rate financial instruments at December 31, 2010 and
2009.
Income Taxes
The Company follows the liability method of tax allocation in accounting for
income taxes. Under this method, the Company records future income taxes for the
effect of any differences between the accounting and income tax basis of an
asset or liability using income tax rates expected to apply in the periods in
which these temporary differences are expected to be recovered or settled. The
effect on future income tax assets and liabilities of a change in tax rates is
recognized in earnings in the period in which the change is substantively
enacted.
Foreign Currency Translation
The Company uses the temporal method of foreign currency translation whereby the
monetary assets and liabilities recorded in a foreign currency are translated
into Canadian dollars at year end exchange rates, and non-monetary assets and
liabilities at the exchange rates prevailing when the assets were acquired or
liability incurred. Revenues and expenses are translated at the average rate of
exchange prevailing during the year. Gains and losses on translation are
included in the consolidated statements of earnings and comprehensive income and
accumulated earnings.
Common Share Rights and Share-Based Compensation
Under the Company's share options incentive plans (the "Plans"), options to
purchase common shares were granted to directors, officers, employees and other
service providers at market prices. The Plans allow for the exercise price of
options to be reduced in future periods by an amount that
distributions/dividends exceed a stated return on assets. Under the fair value
method of accounting for share-based compensation, the cost of the option is
charged to earnings with an offsetting amount recorded in contributed surplus,
based on an estimate from the fair value model. Forfeiture of options is
recorded as a reduction in expense in the period in which it occurs if the
options have not yet vested.
Per Share Amounts
Per share amounts are calculated using the weighted average number of common
shares outstanding during the year. Diluted per share amounts are calculated
using the treasury stock method to determine the dilutive effect of share- based
compensation. The Company follows the treasury stock method, which assumes that
the proceeds received from "in-the-money" common share options and unrecognized
future share-based compensation expense are used to repurchase shares at the
average market rate during the year. Diluted per share amounts also include
exchangeable shares using the "if-converted" method, whereby it is assumed the
conversion of the exchangeable shares occurs at the beginning of the reporting
period (or at the time of issuance if later) where applicable.
Measurement Uncertainty
The amounts recorded for depletion and depreciation of property and equipment
and the assessment of these assets for impairment are based on estimates of
proved reserves, production rates, petroleum and natural gas prices, future
costs and other relevant assumptions. By their nature, these estimates are
subject to measurement uncertainty and the impact on the consolidated financial
statements of changes in such estimates in future periods could be material.
Inherent in the fair value calculation of asset retirement obligations are
numerous assumptions and judgments including the ultimate settlement amounts,
inflation factors, credit adjusted discount rates, timing of settlement and
changes in the legal and regulatory environments. To the extent future revisions
to these assumptions impact the fair value of the existing asset retirement
obligation liability, a corresponding adjustment is made to the property and
equipment balance.
Cash Distributions/Dividends
In 2010, the Trust declared monthly distributions of cash to unitholders of
record on the last day of each calendar month. Pursuant to the Trust policy, it
paid distributions to its unitholders subject to satisfying its financing
covenants. Such distributions are recorded as distributions of equity upon
declaration of the distribution. Commencing in 2011, the Company will declare
monthly dividends of cash to shareholders of record on the last day of each
calendar month. Pursuant to the Company's policy, it will pay dividends to its
shareholders subject to satisfying its financing covenants and the requirements
of the Business Corporations Act (Alberta). Such dividends are recorded as
distributions of equity upon declaration of the dividend.
3. CHANGES IN ACCOUNTING POLICIES
Business Combinations
On January 1, 2010, the Company adopted the CICA Handbook Section 1582 "Business
Combinations", replacing Section 1581 of the same name. Under this new guidance,
the purchase price used in a business combination is based on the fair value of
shares exchanged at the date of exchange and contingent liabilities are to be
recognized at fair value at the acquisition date and re-measured at fair value
with changes recorded through earnings each period until settled. In addition,
this new guidance generally requires all transaction costs to be expensed and
negative goodwill to be recognized immediately in earnings. The provisions of
this new Section were applied to the acquisition of Oakmont Energy Ltd. (see
note 4 to the consolidated financial statements).
Consolidated Financial Statements
On January 1, 2010, the Company adopted the CICA Handbook Section 1601
"Consolidated Financial Statements", replacing Section 1600 of the same name.
This guidance requires uniform accounting policies to be consistent throughout
all consolidated entities and the difference between reporting dates of a parent
and a subsidiary to be no longer than three months. The adoption of this Section
did not have an impact on the Company's consolidated financial statements.
Non-Controlling Interest
On January 1, 2010, the Company adopted the CICA Handbook Section 1602
"Non-Controlling Interests", which replaces Section 1600 "Consolidated Financial
Statements". Commencing in 2010, non-controlling interest ("NCI") is presented
within equity. Under this new guidance, when there is a loss or gain of control,
the Company's previously held interest is re-valued at fair value. In addition,
NCI may be reported at fair value or at the proportionate share of the fair
value of the acquired net assets and allocation of the net income to the NCI
will be on this basis. The adoption of this Section has reclassified the NCI
from liabilities to equity on the Company's consolidated balance sheet.
Additionally, in accordance with EIC-151 "Exchangeable Securities Issued by
Subsidiaries of Income Trusts", each redemption of exchangeable shares was
accounted for as a step-purchase and resulted in an increase in property and
equipment and in the future income tax liability. This treatment ceased with the
adoption of Handbook Section 1602 whereby redemptions subsequent to January 1,
2010 have been recorded against accumulated earnings rather than as increases to
property and equipment and the future tax liability.
The above CICA Handbook Sections are converged with International Financial
Reporting Standards.
4. ACQUISITIONS
Oakmont Energy Ltd.
On September 9, 2010, the Company acquired all of the outstanding shares of
Oakmont Energy Ltd. ("Oakmont"), a private oil and gas company, for
consideration of $5.95 million. Consideration consisted of the issuance of
335,574 Zargon common shares valued at $17.72 per share.
These consolidated financial statements incorporate the results of operations of
the acquired Oakmont properties from September 9, 2010. For the period September
9, 2010 to December 31, 2010, Zargon recorded revenue from oil, natural gas and
natural gas liquids of $0.91 million in respect of the acquired assets. Had the
acquisition occurred on January 1, 2010, for the 12 months ended December 31,
2010, Zargon estimates that its pro forma revenue would have been approximately
$3.84 million.
The acquisition was accounted for by the purchase method and the preliminary
purchase price allocation is as follows:
Net Assets Acquired
($ thousands)
----------------------------------------------------------------------------
Property and equipment 12,403
Working capital deficiency (3,410)
Future income tax liability (56)
Asset retirement obligations (2,991)
----------------------------------------------------------------------------
Total net assets acquired 5,946
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Consideration
($ thousands)
----------------------------------------------------------------------------
Common shares issued (1) 5,946
----------------------------------------------------------------------------
Total purchase price 5,946
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) For the convenience of the reader, the information presented in this
schedule refers to common shares although, for the pre- corporate
conversion period, these items were trust units.
Acquisition costs for the transaction of $0.13 million have been included in
Transaction Costs on the consolidated statements of earnings and comprehensive
income and accumulated earnings as a result of the adoption of Section 1582
"Business Combinations" effective January 1, 2010.
Churchill Energy Inc.
On September 23, 2009, the Company acquired all of the outstanding shares of
Churchill Energy Inc. ("Churchill"), a public oil and gas company, for
consideration of $9.74 million. Consideration consisted of $0.11 million cash,
the issuance of 554,669 Zargon common shares valued at $16.87 per share and
acquisition costs of $0.27 million.
The results of operations for Churchill have been included in the consolidated
financial statements since September 23, 2009.
The acquisition was accounted for by the purchase method and the purchase price
allocation is as follows:
Net Assets Acquired
($ thousands)
----------------------------------------------------------------------------
Property and equipment 9,794
Working capital deficiency (6,576)
Future income tax asset 8,920
Asset retirement obligations (2,403)
----------------------------------------------------------------------------
Total net assets acquired 9,735
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Consideration
($ thousands)
----------------------------------------------------------------------------
Cash 108
Common shares issued (1) 9,357
Acquisition costs 270
----------------------------------------------------------------------------
Total purchase price 9,735
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) For the convenience of the reader, the information presented in this
schedule refers to common shares although, for the pre- corporate
conversion period, these items were trust units.
Masters Energy Inc.
On April 29, 2009, the Company acquired all of the outstanding shares of Masters
Energy Inc. ("Masters"), a public oil and gas company, for consideration of
$27.10 million. Consideration consisted of $5.70 million cash, the issuance of
1,475,468 Zargon common shares valued at $14.26 per share and acquisition costs
of $0.36 million. Zargon assumed Masters' long term debt, which was repaid on
the closing date of the acquisition.
The results of operations for Masters have been included in the consolidated
financial statements since April 29, 2009.
The acquisition was accounted for by the purchase method and the purchase price
allocation is as follows:
Net Assets Acquired
($ thousands)
----------------------------------------------------------------------------
Property and equipment 44,030
Working capital deficiency (105)
Long term debt (12,825)
Future income tax asset 69
Asset retirement obligations (4,072)
----------------------------------------------------------------------------
Total net assets acquired 27,097
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Consideration
($ thousands)
----------------------------------------------------------------------------
Cash 5,700
Common shares issued (1) 21,040
Acquisition costs 357
----------------------------------------------------------------------------
Total purchase price 27,097
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) For the convenience of the reader, the information presented in this
schedule refers to common shares although, for the pre- corporate
conversion period, these items were trust units.
5. PROPERTY AND EQUIPMENT
December 31, 2010
----------------------------------------------------------------------------
Accumulated
Depletion and Net Book
($ thousands) Cost Depreciation Value
----------------------------------------------------------------------------
Petroleum, natural gas properties and
other equipment (1) 850,138 413,144 436,994
Leasehold improvements and office
equipment 4,798 2,564 2,234
----------------------------------------------------------------------------
854,936 415,708 439,228
----------------------------------------------------------------------------
----------------------------------------------------------------------------
December 31, 2009
----------------------------------------------------------------------------
Accumulated
Depletion and Net Book
($ thousands) Cost Depreciation Value
----------------------------------------------------------------------------
Petroleum, natural gas properties and
other equipment (1) 771,121 347,260 423,861
Leasehold improvements and office
equipment 4,136 2,033 2,103
----------------------------------------------------------------------------
775,257 349,293 425,964
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) As a result of shareholders redeeming exchangeable shares, property and
equipment has cumulatively increased $56.13 million, nil relating to
2010, $0.97 million relating to 2009 and $55.16 million relating to
prior years. The effect of these increases has resulted in additional
depletion and depreciation expense of approximately $31.33 million,
$4.11 million relating to 2010, $4.91 million relating to 2009 and
$22.31 million relating to prior years.
At December 31, 2010, petroleum, natural gas properties and equipment included
$25.16 million (2009 - $24.37 million) related to undeveloped properties that
have been excluded from the depletion calculation.
An impairment test calculation was performed on the Company's petroleum, natural
gas properties and equipment at December 31, 2010 in which the estimated
undiscounted future net cash flows associated with the proved reserves exceeded
the carrying amount of the Company's petroleum, natural gas properties and
equipment; consequently an impairment provision was not recorded. This
impairment calculation was performed separately on both the Canadian and US cost
centres.
The following table outlines benchmark prices used in the impairment test at
December 31, 2010:
WTI Crude Oil Exchange Rate WTI Crude Oil AECO Gas
Year ($US/bbl) ($US/$Cdn) ($Cdn/bbl) ($Cdn/gj)
----------------------------------------------------------------------------
2011 93.73 1.00 93.73 3.79
2012 93.91 0.99 94.86 4.25
2013 92.66 0.98 94.55 4.50
2014 92.55 0.98 94.44 4.65
2015 92.80 0.98 94.69 4.79
----------------------------------------------------------------------------
Thereafter (inflation %) 2.0% 0.99 2.0% 2.0%
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Actual prices used in the impairment test were adjusted for commodity price
differentials specific to Zargon.
6. LONG TERM DEBT
On June 29, 2010, Zargon amended and renewed its syndicated committed credit
facilities, the result of which was the maintaining of the available facilities
and borrowing base of $180 million. These facilities consist of a $170 million
tranche available to the Canadian borrower and a US $8 million tranche available
to the US borrower. A $300 million demand debenture on the assets of the
subsidiaries of the Company has been provided as security for these facilities.
The facilities are fully revolving for a 364-day period with the provision for
an annual extension at the option of the lenders and upon notice from Zargon's
management. The next renewal date is June 28, 2011. Should the facilities not be
renewed, they convert to one year non-revolving term facilities at the end of
the revolving 364-day period. Repayment would not be required until the end of
the non-revolving term, and, as such, these facilities have been classified as
long term debt.
Interest rates fluctuate under the syndicated facilities with Canadian prime, US
prime and US base rates, plus an applicable margin between 100 basis points and
250 basis points (2009 - 125 and 275 basis points, respectively), as well as
with Canadian banker's acceptance and LIBOR rates plus an applicable margin
between 250 basis points and 400 basis points (2009 - 275 and 425 basis points,
respectively). At December 31, 2010, $115.29 million (December 31, 2009 - $76.58
million) had been drawn on the syndicated committed credit facilities with any
unused amounts subject to standby fees. In the normal course of operations
Zargon enters into various letters of credit. At December 31, 2010, the
approximate value of outstanding letters of credit totalled $1.25 million
(December 31, 2009 - $0.61 million). The letters of credit reduce the amount of
Zargon's available credit facilities to $63.46 million at December 31, 2010
(2009 - $102.81 million).
Zargon reviews its compliance with its bank debt covenants on a quarterly basis
and had no violations as at December 31, 2010. Zargon converted to a corporation
from its previous trust structure on December 31, 2010 and had to ensure that
all legal and regulatory requirements were satisfied. Zargon's current
syndicated credit facility was amended and restated effective January 1, 2011 to
reflect the corporate conversion.
7. ASSET RETIREMENT OBLIGATIONS
The total future asset retirement obligation was estimated by management based
on Zargon's net working interest in all wells and facilities, estimated costs to
reclaim and abandon wells and facilities and the estimated timing of the costs
to be incurred in future periods. Zargon has estimated the net present value of
its total asset retirement obligations to be $42.98 million as at December 31,
2010 (2009 - $35.47 million), based on a total future liability of $171.10
million (2009 - $164.58 million). These payments are expected to be made over
the next 40 years with the majority of the costs being incurred after 2020.
Commencing July 1, 2005, incremental asset retirement obligations are calculated
using a revised credit adjusted risk-free rate of 7.5 percent. Asset retirement
obligations prior to this period were calculated using a credit adjusted
risk-free rate of 8.5 percent. An inflation rate of two percent used in the
calculation of the present value of the asset retirement obligation remains
unchanged.
The following table reconciles Zargon's asset retirement obligations:
Year Ended December 31,
----------------------------------------------------------------------------
($ thousands) 2010 2009
----------------------------------------------------------------------------
Balance, beginning of year 35,468 28,592
Net liabilities incurred/acquired 7,595 7,353
Liabilities settled (3,567) (3,056)
Accretion expense 3,522 2,744
Foreign exchange (39) (165)
----------------------------------------------------------------------------
Balance, end of year 42,979 35,468
----------------------------------------------------------------------------
----------------------------------------------------------------------------
8. SHAREHOLDERS' EQUITY
Pursuant to the Arrangement, 23.93 million shares of the Company were issued in
exchange for all of the outstanding trust units of the Trust on a one-for-one
basis and 3.12 million shares of the Company were issued in exchange for all of
the outstanding exchangeable shares based on an exchange ratio of 1.84716 at the
time of conversion. Pursuant to the Arrangement, the shareholders' capital was
reduced by the deficit of the Trust as of December 31, 2010 of $31.47 million.
Trust Units
December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
Number of Amount Number of Amount
(thousands) Units ($) Units ($)
----------------------------------------------------------------------------
Balance, beginning of year 23,097 188,840 18,479 120,650
Unit rights exercised for cash 149 2,359 98 1,295
Unit-based compensation recognized
on exercise of unit rights - 482 - 391
Issued on corporate and property
acquisitions (note 4) 336 5,946 2,030 30,397
Equity issuance - - 2,365 35,475
Issue costs, net of future tax
effect of $487 - - - (1,544)
Issued on redemption of
exchangeable shares 162 3,182 125 2,176
Issued pursuant to Distribution
Reinvestment Plan 184 3,409 - -
Exchanged on conversion to a
corporation (23,928) (204,218) - -
----------------------------------------------------------------------------
Balance, end of year - - 23,097 188,840
----------------------------------------------------------------------------
----------------------------------------------------------------------------
On June 5, 2009, the Company closed an offering of 2.365 million common shares
on a bought deal basis at $15.00 per share for total gross proceeds of $35.48
million ($33.44 million net of issue costs).
The Company is authorized to issue an unlimited number of voting common shares
and 10,000,000 preferred shares.
Common Shares
December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
Number of Amount Number of Amount
(thousands) Shares ($) Shares ($)
----------------------------------------------------------------------------
Balance, beginning of year - - - -
Issuance of common shares for
trust units pursuant to corporate - -
conversion 23,928 204,218
Issuance of common shares for
exchangeable shares pursuant to
corporate conversion 3,118 68,059 - -
Reduction in shareholders' capital
for deficit amounts - (31,472) - -
----------------------------------------------------------------------------
Balance, end of year 27,046 240,805 - -
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Common Share Rights Incentive Plan
In conjunction with conversion to a corporation, Zargon's two original Trust
Unit Rights Incentive Plans were amended and restated as Common Shares Rights
Incentive Plans. Under these plans, directors, officers, employees and other
service providers of the Company possess rights to acquire common shares at
their option of either the original exercise price or a "modified price" as
calculated per the provisions of the relevant plan. The Common Share Rights
Incentive Plan (2007) (the "Old Plan") provides for a modified price based on
the increment of the amount by which monthly distributions/dividends exceed a
monthly return of 0.833 percent of the Company's recorded net book value of oil
and natural gas properties (as defined in the Old Plan). Under the Common Share
Incentive Rights Plan (2009) (the "New Plan"), if the monthly
distributions/dividend exceeds the monthly return of 0.833 percent of the
Company's recorded net book value of oil and natural gas properties (as defined
in the New Plan), the entire amount (not the increment) of the
distributions/dividend is deducted from the original grant price. Rights granted
under either Plan generally vest over a three-year period and expire
approximately five years from the grant date. Zargon uses a fair value
methodology to value the common share rights grants. The Company is authorized
to issue up to 2.13 million share rights; however, the number of shares reserved
for issuance upon exercise of the options shall not, at any time, exceed 10
percent of the aggregate number of the total outstanding shares. Management does
not intend on granting any further rights under either one of these two plans.
In addition to their approval of the Plan of Arrangement on December 15, 2010,
securityholders also approved a new share-based compensation plan ("Share Award
Plan") commencing effective January 1, 2011. Under the Share Award Plan,
directors, officers, employees and other service providers are granted the right
to receive a defined number of shares in the future, which increases
commensurately with each dividend declared by the Company after the grant date.
The awards vest equally over four years and expire five years after grant date.
Holders may choose to exercise upon vesting or at any time thereafter, with
forfeiture of any shares not exercised by the expiry date. No awards were
granted under this plan until subsequent to December 31, 2010.
The following table summarizes information about the Company's share options
under the Old Plan:
December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
Weighted Weighted
Average Average
Exercise Price Exercise Price
Number of Initial and Number of Initial and
Share Modified Share Modified
Options ($/share Options ($/share
(thousands) option) (thousands) option)
----------------------------------------------------------------------------
Outstanding at
beginning of
year 1,322 25.97 / 23.52 1,654 25.57 / 23.63
Share options
exercised (1) (96) 17.00 (98) 13.21
Share options
cancelled (1) (488) 27.42 (234) 26.60
----------------------------------------------------------------------------
Outstanding at
end of year 738 25.61 / 23.10 1,322 25.97 / 23.52
----------------------------------------------------------------------------
Share rights
exercisable at
year end (1) 650 25.99 / 23.37 961 26.87 / 23.99
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) For the convenience of the reader, the information presented in this
schedule refers to common share options although, for the pre- corporate
conversion period, these items were trust unit rights.
The following table summarizes information about the Company's share
options under the New Plan:
December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
Weighted Weighted
Average Average
Exercise Price Exercise Price
Number of Initial and Number of Initial and
Share Modified Share Modified
Options ($/share Options ($/share
(thousands) option) (thousands) option)
----------------------------------------------------------------------------
Outstanding at
beginning of
year 421 15.81 / 14.58 - - / -
Share options
granted (1) 478 19.72 434 15.81
Share options
exercised (1) (53) 13.52 - -
Share options
cancelled (1) (138) 17.99 (13) 15.76
----------------------------------------------------------------------------
Outstanding at
end of year 708 18.03 / 15.64 421 15.81 / 14.58
----------------------------------------------------------------------------
Share rights
exercisable at
year end (1) 96 15.86 / 12.49 - - / -
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) For the convenience of the reader, the information presented in this
schedule refers to common share options although, for the pre- corporate
conversion period, these items were trust unit rights.
The following tables summarize information about share rights outstanding
and exercisable at December 31, 2010:
For the Old Plan at the initial grant price:
Share Options
Share Options Outstanding Exercisable
----------------------------------------------------------------------------
Weighted Weighted
Range of Weighted Average Average
Exercise Average Exercise Exercise
Prices Number Remaining Price Number Price
($/share Outstanding Contractual ($/share Exercisable ($/share
option) (thousands) Life option) (thousands) option)
----------------------------------------------------------------------------
13.00 - 21.55 111 2.1 years 21.27 75 21.33
22.10 - 24.90 266 1.2 years 23.32 241 23.45
26.00 - 27.91 216 1.5 years 26.72 189 26.83
29.93 - 33.05 145 0.1 years 31.49 145 31.49
----------------------------------------------------------------------------
738 25.61 650 25.99
----------------------------------------------------------------------------
----------------------------------------------------------------------------
For the Old Plan at the modified price:
Share Options
Share Options Outstanding Exercisable
----------------------------------------------------------------------------
Weighted Weighted
Range of Weighted Average Average
Exercise Average Exercise Exercise
Prices Number Remaining Price Number Price
($/share Outstanding Contractual ($/share Exercisable ($/share
option) (thousands) Life option) (thousands) option)
----------------------------------------------------------------------------
11.55 - 19.94 111 2.1 years 19.67 75 19.73
20.21 - 21.72 266 1.2 years 20.89 241 20.96
24.22 - 25.24 216 1.5 years 24.49 189 24.53
25.77 - 29.58 145 0.1 years 27.72 145 27.72
----------------------------------------------------------------------------
738 23.10 650 23.37
----------------------------------------------------------------------------
----------------------------------------------------------------------------
For the New Plan at the initial grant price:
Share Options
Share Options Outstanding Exercisable
----------------------------------------------------------------------------
Weighted Weighted
Range of Weighted Average Average
Exercise Average Exercise Exercise
Prices Number Remaining Price Number Price
($/share Outstanding Contractual ($/share Exercisable ($/share
option) (thousands) Life option) (thousands) option)
----------------------------------------------------------------------------
15.56 262 3.1 years 15.56 81 15.56
15.80 8 3.1 years 15.80 3 15.80
17.31 13 3.1 years 17.31 4 17.31
17.70 - 19.85 425 4.0 years 19.62 8 18.12
----------------------------------------------------------------------------
708 18.03 96 15.86
----------------------------------------------------------------------------
----------------------------------------------------------------------------
For the New Plan at the modified price:
Share Options
Share Options Outstanding Exercisable
----------------------------------------------------------------------------
Weighted Weighted
Range of Weighted Average Average
Exercise Average Exercise Exercise
Prices Number Remaining Price Number Price
($/share Outstanding Contractual ($/share Exercisable ($/share
option) (thousands) Life option) (thousands) option)
----------------------------------------------------------------------------
12.08 262 3.1 years 12.08 81 12.08
12.59 8 3.1 years 12.59 3 12.59
14.47 13 3.1 years 14.47 4 14.47
15.35 - 19.21 425 4.0 years 17.93 8 15.46
----------------------------------------------------------------------------
708 15.64 96 12.49
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Share-Based Compensation
The weighted average assumptions used for share options granted in 2010 include
a volatility factor of expected market price of 33.2 percent, a risk-free
interest rate of 2.3 percent and an expected life of the share options of four
years. The fair value of the share options granted under the New Plan in the
year was calculated at $5.71 per share option. These share options, together
with the continued vesting of share options granted in prior years and the
intrinsic value of stock appreciation rights, resulted in share-based
compensation expense in 2010 of $1.45 million (2009 - $1.26 million).
Compensation expense associated with share options granted under either Plan is
recognized in earnings over the vesting period of the Plan with a corresponding
increase in contributed surplus. The exercise of share options is recorded as an
increase in shareholders' capital with a corresponding reduction in contributed
surplus. Forfeiture of rights is recorded as a reduction in expenses in the
period in which it occurs if the options have not yet vested.
The following table summarizes information about the Company's contributed
surplus account:
Contributed Surplus
($ thousands)
----------------------------------------------------------------------------
Balance, December 31, 2008 4,617
Share-based compensation expense (1) 1,245
Share-based compensation recognized on exercise of share options (391)
----------------------------------------------------------------------------
Balance, December 31, 2009 5,471
Share-based compensation expense (1) 1,402
Share-based compensation recognized on exercise of share options (482)
----------------------------------------------------------------------------
Balance, December 31, 2010 6,391
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) During the fourth quarter of 2008, the Company issued 10,000 stock
appreciation rights ("SARs") with an intrinsic value of $0.02 million at
December 31, 2010 ($0.02 million at December 31, 2009). These SARs are
awards entitling the recipients to receive cash in an amount equivalent
to any excess of the market value of a stated number of shares over a
stated price. SARs are included in share-based compensation expense.
During the fourth quarter of 2010, 2,500 SARs were exercised with a
value of $0.02 million. This amount has been included in share-based
compensation. However, rewards settled in cash are liabilities and
therefore are not included in contributed surplus.
9. NON-CONTROLLING INTEREST - EXCHANGEABLE SHARES
Exchangeable shares were convertible into trust units at the option of the
shareholder, based on the exchange ratio, which was adjusted monthly to reflect
the distribution paid on the trust units. Cash distributions were not paid on
the exchangeable shares. During the year, a total of 0.10 million (2009 - 0.08
million) exchangeable shares were converted into 0.16 million (2009 - 0.12
million) trust units based on the exchange ratio at the time of conversion. At
December 31, 2010, the exchange ratio was 1.84716 (2009 - 1.63709) trust units
per exchangeable share. Pursuant to the corporate conversion, on December 31,
2010, each outstanding exchangeable share was exchanged for 1.84716 common
shares and as a result, there are no exchangeable shares outstanding.
Non-Controlling Interest - Exchangeable Shares
December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
(thousands, except Number of Number of
exchange ratio) Shares Amount ($) Shares Amount ($)
----------------------------------------------------------------------------
Balance, beginning of year 1,784 26,477 1,862 27,610
Exchanged for trust units at
book value and including
earnings attributed during
the period (96) (1,929) (78) (1,470)
Earnings attributable to
non-controlling interest - 1,097 - 337
Exchanged for common
shares pursuant to the
corporate conversion
(notes 1 and 8) (1,688) (25,645) - -
----------------------------------------------------------------------------
Balance, end of year - - 1,784 26,477
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Exchange ratio, end of period - 1.63709
Trust units issuable upon
conversion of exchangeable
shares, end of year - 2,920
----------------------------------------------------------------------------
----------------------------------------------------------------------------
In connection with the corporate conversion, Zargon issued 3,117,638 common
shares in exchange for the remaining 1,687,801 exchangeable shares based on the
exchange ratio of 1.84716. This transaction was accounted for as an acquisition
of the non-controlling interest at fair value. The fair value of the common
shares issued in consideration for the non-controlling interest represented by
the exchangeable shares was $68.06 million. The difference between that amount
and the carrying value of the non-controlling interest of $25.65 million
resulted in a decrease to accumulated earnings of $42.41 million. An additional
adjustment to accumulated earnings of $1.26 million was booked in 2010 in
accordance with Handbook Section 1602 (refer to note 3 for further details), to
record the elimination of the non-controlling interest on the redemption of
exchangeable shares be reflected as a component of equity rather than as an
increase to property and equipment. The total adjustment to accumulated earnings
in 2010 was $43.67 million.
The effect of EIC-151 on Zargon's unitholders' capital and exchangeable shares
is as follows:
Zargon Zargon Oil
Energy & Gas Ltd.
Trust Exchangeable
($ thousands) Units Shares Total
----------------------------------------------------------------------------
Balance at December 31, 2008 120,650 27,610 148,260
Issued on redemption of exchangeable
shares at book value 192 (192) -
Effect of EIC-151 1,984 (941) 1,043
Unit-based compensation recognized on
exercise of unit rights 391 - 391
Issued on corporate and property
acquisitions 30,397 - 30,397
Unit rights exercised for cash 1,295 - 1,295
Equity issuance (net of share issue
costs and future taxes) 33,931 - 33,931
----------------------------------------------------------------------------
Balance at December 31, 2009 188,840 26,477 215,317
Issued on redemption of exchangeable
shares at book value 233 (233) -
Effect of EIC-151 2,949 (599) 2,350
Unit-based compensation recognized on
exercise of unit rights 482 - 482
Issued on corporate and property
acquisitions 5,946 - 5,946
Unit rights exercised for cash 2,359 - 2,359
Unit rights issued pursuant to
Distribution Reinvestment Plan 3,409 - 3,409
Exchanged for common shares pursuant
to the corporate conversion (204,218) (25,645) (229,863)
----------------------------------------------------------------------------
Balance at December 31, 2010 - - -
----------------------------------------------------------------------------
----------------------------------------------------------------------------
In accordance with EIC-151, exchangeable securities issued by a subsidiary of an
Income Trust should be reflected as either a non-controlling interest or debt on
the consolidated balance sheets unless they meet certain criteria. The
exchangeable shares issued were publicly traded and had an expiry term, which
could be extended at the option of the Board of Directors. Therefore, these
securities were considered, by EIC-151, to be transferable to third parties and
to have an indefinite life. EIC-151 states that if these criteria are met, the
exchangeable shares should be reflected as a non-controlling interest.
As a result of EIC-151, the Company has increased its non-controlling interest
for 2010 by $0.83 million (2009 - $1.04 million) on the Company's consolidated
balance sheets immediately prior to the December 31, 2010 corporate conversion.
Consolidated net earnings for 2010 have been reduced for net earnings
attributable to the non- controlling interest by $1.10 million (2009 - $0.34
million). In accordance with EIC-151 and Handbook Section 1581, each redemption
prior to 2010 was accounted for as a step-purchase and resulted in increases for
2009 in property and equipment of $0.97 million and in the future income tax
liability of $0.27 million. In accordance with Handbook Section 1582 and 1602,
redemptions during 2010 were recorded as a decrease to accumulated earnings,
which totalled $1.26 million.
Prior to the corporate conversion, the cumulative impact to date of the
application of EIC-151 for redemption of exchangeable shares was to increase
gross property and equipment by $56.13 million (for prior years' depletion
impact see note 5), to shareholders' capital and non-controlling interest of
$69.27 million, to future income tax liability of $18.46 million, a decrease to
accumulated earnings of $1.26 million and an allocation of net earnings to
exchangeable shareholders of $30.34 million.
As part of the conversion to a corporation on December 31, 2010, all outstanding
exchangeable shares were converted to common shares of the Company at an
exchange ratio of 1.84716. As a result, 3.12 million shares were issued at a
fair value of $68.06 million and recorded as shareholders' capital, the
non-controlling interest was eliminated and the offset was recorded as a
decrease to retained earnings of $42.41 million.
10. WEIGHTED AVERAGE NUMBER OF TOTAL SHARES
(thousands of shares) 2010 2009
----------------------------------------------------------------------------
Basic (1) 23,526 21,099
Diluted (1) 26,333 23,745
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) For the convenience of the reader, the information presented in this
schedule refers to common shares although,, for the pre- corporate
conversion period, these items were trust units.
Dilution amounts of 2.81 million shares (2009 - 2.65 million) were added to the
weighted average number of shares outstanding during the year in the calculation
of diluted per share amounts. These share additions represent the dilutive
effect of share options according to the treasury stock method and also include
exchangeable shares using the "if-converted" method. Due to the fact that at the
time of exercise, the options holder has the option of exercising at the
original grant price or a modified price as calculated under the Old Plan and
the New Plan, the prices used in the treasury stock calculation are the lower
prices calculated under the Old Plan and the New Plan. An adjustment to the
numerator amount was required in the diluted calculation to provide for the
earnings of $1.10 million (2009 - $0.34 million) attributable to the
non-controlling interest pertaining to the exchangeable shareholders. As a
result of the conversion to a corporation (notes 1, 8 and 9), units of the Trust
were converted to common shares of Zargon on a one-for-one basis and holders of
exchangeable shares received 1.84716 common shares for each exchangeable share
held.
11. CAPITAL DISCLOSURES
The Company's capital structure is comprised of shareholders' equity plus long
term debt. The Company's objectives when managing its capital structure are to:
i) maintain financial flexibility so as to preserve Zargon's access to
capital markets and its ability to meet its financial obligations; and
ii) finance internally generated growth as well as acquisitions.
The Company monitors its capital structure and short term financing requirements
using the non-GAAP financial metric of debt net of working capital ("net debt")
to funds flow from operating activities. Net debt, as used by the Company, is
calculated as bank debt and any working capital deficit excluding the current
portion of unrealized risk management assets and liabilities and future income
taxes. Funds flow from operating activities represent net earnings/losses and
asset retirement expenditures except for non-cash items. The metric is used to
steward the Company's overall debt position as a measure of the Company's
overall financial strength and is calculated as follows:
($ thousands, except ratio) December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
Net debt 124,392 88,008
Funds flow from operating activities 73,702 86,352
----------------------------------------------------------------------------
Net debt to funds flow from operating
activities ratio 1.69 1.02
----------------------------------------------------------------------------
----------------------------------------------------------------------------
As at December 31, 2010, Zargon's net debt to funds flow from operating
activities ratio was 1.69, an increase from 1.02 at December 31, 2009. This
increase was primarily a result of increased long term debt due to Zargon's
field capital expenditures and net property and corporate acquisitions. On June
29, 2010, Zargon amended and renewed its syndicated committed credit facilities
of $180 million. The next renewal date is June 28, 2011. These facilities
continue to be available for general corporate purposes and the potential
acquisition of oil and natural gas properties. The Company converted to a
corporation from its previous trust structure on December 31, 2010. Zargon's
current syndicated credit facility was amended and restated effective January 1,
2011 to reflect the corporate conversion.
To manage its capital structure, the Company may adjust capital spending, adjust
dividends paid to shareholders, issue new shares, issue new debt or repay
existing debt.
The Company's capital management objectives, evaluation measures, definitions
and targets have remained unchanged over the periods presented. Zargon is
subject to certain financial covenants in its credit facility agreements and is
in compliance with all financial covenants.
Zargon reviews its compliance with its bank debt covenants on a quarterly basis
and had no violations as at December 31, 2010.
12. FINANCIAL INSTRUMENTS AND RISK MANAGEMENT CONTRACTS
Fair Value of Financial Assets and Liabilities
Zargon's financial assets and liabilities are comprised of accounts receivable,
deposits, accounts payable, cash distributions payable, unrealized risk
management assets and liabilities and long term debt. Fair values of financial
assets and liabilities, summarized information related to risk management
positions and discussion of risks associated with financial assets and
liabilities are presented as follows:
A) Fair Value of Financial Assets and Liabilities
Accounts receivable are designated as "loans and receivables". Accounts payable
and accrued liabilities, cash distributions payable and long term debt are
designated as "other liabilities". The fair values of these accounts approximate
their carrying amounts.
Risk management assets and liabilities are derivative financial instruments
classified as "held-for-trading". These accounts are recorded at their estimated
fair value using quoted market prices.
Financial instruments of the Company carried on the consolidated balance sheets
are carried at amortized cost with the exception of risk management contracts,
which are carried at fair value.
All of the Company's risk management contracts are transacted in active markets.
The Company classifies the fair value of these transactions according to the
following hierarchy based on the amount of observable inputs used to value the
instrument.
- Level I
Quoted prices are available in active markets for identical assets or
liabilities as of the reporting date. Active markets are those in which
transactions occur in sufficient frequency and volume to provide pricing
information on an ongoing basis.
- Level II
Pricing inputs are other than quoted prices in active markets included in Level
I. Prices in Level II are either directly or indirectly observable as of the
reporting date. Level II valuations are based on inputs, including quoted
forward prices for commodities, time value and volatility factors, which are can
be substantially observed or corroborated in the marketplace.
- Level III
Valuations in this level are those with inputs for the asset or liability that
are not based on observable market data.
The Company's risk management contracts have been assessed on the fair value
hierarchy described above. The Company's risk management contracts are
classified as Level II. Assessment of the significance of a particular input
into the fair value measurement requires judgment and may affect the placement
within the fair value hierarchy level.
B) Risk Management Assets and Liabilities
The Company is a party to certain financial instruments that have fixed the
price of a portion of its oil production and electricity rates. The Company
enters into these contracts for risk management purposes only, in order to
protect a portion of its future cash flow from the volatility of oil and natural
gas commodity prices and electricity rates. For financial risk management
contracts, the Company considers these contracts to be effective on an economic
basis, but has decided not to designate these contracts as hedges for accounting
purposes and, accordingly, any unrealized gains or losses are recorded in
earnings based on the fair value (mark-to-market) of the contracts at each
reporting period. The unrealized loss on the consolidated statements of earnings
and comprehensive income and accumulated earnings for 2010 was $10.80 million
and the unrealized loss for 2009 was $36.39 million.
As at December 31, 2010, the Company had the following outstanding commodity and
electricity risk management contracts:
Commodity Financial Risk Management Contracts:
Fair Market
Value
Weighted Range of Liability ($
Rate Average Price Terms thousands)
----------------------------------------------------------------------------
Oil swaps Jan. 1/11 -
400 bbl/d $77.40 US/bbl Jun. 30/11 (1,131)
Jan. 1/11 -
300 bbl/d $77.25 US/bbl Sep. 30/11 (1,326)
Jan. 1/11 -
1,100 bbl/d $83.33 US/bbl Dec. 31/11 (4,162)
Jan. 1/11 -
600 bbl/d $83.05 US/bbl Jun. 30/12 (3,515)
Jan. 1/11 -
400 bbl/d $85.54 US/bbl Sep. 30/12 (2,102)
Jul. 1/11 -
200 bbl/d $83.50 US/bbl Aug. 31/12 (904)
Oct. 1/11 -
200 bbl/d $87.65 US/bbl Sep. 30/12 (464)
Jan. 1/12 -
200 bbl/d $91.85 US/bbl Dec. 31/12 (146)
----------------------------------------------------------------------------
Total Fair Market Value, Commodity Price Financial Contracts (13,750)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil swaps are settled against the NYMEX WTI pricing index.
Electricity Financial Risk Management Contracts:
Fair Market
Value
Weighted Range of Liability
Rate Average Price Terms ($ thousands)
----------------------------------------------------------------------------
Electricity Jan. 1/11 -
swaps 6 MWs/d $79.33/MWh Dec. 31/11 (67)
----------------------------------------------------------------------------
Total Fair Market Value, Electricity Financial Contracts (67)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Electricity swaps are settled against the AESO pricing index.
Electricity Physical Risk Management Contracts:
Fair Market
Weighted Range of Value Gain
Rate Average Price Terms ($ thousands)
----------------------------------------------------------------------------
Electricity Jan. 1/11 -
swaps 32 MWs/d $55.50/MWh Mar. 31/11 22
----------------------------------------------------------------------------
Total Fair Market Value, Physical Contracts 22
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Electricity contracts are settled by way of physical delivery and are recognized
as part of the normal operating cost stream. These instruments have no book
values recorded in the consolidated financial statements.
As at March 9, 2011, the Company had entered into the following new outstanding
commodity risk management contracts since year end:
Commodity Financial Risk
Management Contracts:
Weighted Range of
Rate Average Price Terms
----------------------------------------------------------------------------
Jan. 1/12 -
Oil swaps 400 bbl/d $96.25 US/bbl Dec. 31/12
Jul. 1/11 -
200 bbl/d $98.10 US/bbl Jun. 30/12
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil swaps are settled against the NYMEX WTI pricing index.
Commodity Price Sensitivities
The following table summarizes the sensitivity of the fair value of the
Company's risk management positions to fluctuations in commodity prices, with
all other variables held constant. When assessing the potential impact of these
commodity price changes, the Company believes 10 percent volatility is a
reasonable long term measure.
Fluctuations of 10 percent in commodity prices could have resulted in unrealized
gains or losses on risk management contracts impacting net earnings as follows:
($ thousands) December 31, 2010 December 31, 2009
----------------------------------------------------------------------------
Crude oil price 12,792 8,617
----------------------------------------------------------------------------
----------------------------------------------------------------------------
C) Risks Associated with Financial Assets and Liabilities
The Company is exposed to financial risks arising from its financial assets and
liabilities. The financial risks include market risk (commodity prices, interest
rates and foreign exchange rates), credit risk and liquidity risk.
- Market Risk
Market risk is the risk that the fair value or future cash flows of financial
assets or liabilities will fluctuate due to movements in market prices and is
comprised of the following:
- Commodity Price Risk
As a means of mitigating exposure to commodity price risk volatility, the
Company has entered into various derivative agreements. The use of derivative
instruments is governed under formal policies and is subject to limits
established by the Board of Directors. The Company's policy is to not use
derivative financial instruments for speculative purposes.
Natural Gas - To partially mitigate the natural gas commodity price risk, the
Company may enter into swaps, to fix the Canadian dollar AECO prices.
Crude Oil - The Company has partially mitigated its exposure to the WTI NYMEX
price with fixed price swaps.
- Interest Rate Risk
Borrowings under bank credit facilities are market rate based (variable interest
rates); thus, carrying values approximate fair values.
At the December 31, 2010 debt pricing levels, the increase or decrease in net
earnings for each one percent change in interest rates would amount to $0.97
million (2009 - $0.82 million).
- Foreign Exchange Risk
As Zargon operates in North America, fluctuations in the exchange rate between
the US/Canadian dollar can have a significant effect on the Company's reported
results. A $0.01 change in the US to Canadian dollar exchange rate would have
resulted in a $0.80 million (2009 - $0.61 million) increase or decrease in net
earnings for the year ended December 31, 2010.
- Credit Risk
Credit risk is the risk that the counterparty to a financial asset will default,
resulting in the Company incurring a financial loss. This credit exposure is
mitigated with credit practices that limit transactions according to
counterparties' credit quality. A substantial portion of the Company's accounts
receivable are with customers in the oil and gas industry and are subject to
normal industry credit risks.
The maximum credit risk exposure associated with accounts receivable, accrued
revenues and risk management assets is the total carrying value. The Company
monitors these balances monthly to limit the risk associated with collection. Of
Zargon's accounts receivable at December 31, 2010, approximately 54 percent
(December 31, 2009 - 40 percent) was owing from two companies and Zargon
anticipates full collection.
The Company's allowance for doubtful accounts was $0.10 million as at December
31, 2010 and $0.10 million as at December 31, 2009. During 2010, the Company did
not record any additional provisions for non-collectible accounts receivable.
When determining whether amounts that are past due are collectible, management
assesses the credit worthiness and past payment history of the counterparty, as
well as the nature of the past due amount. Zargon considers all material amounts
greater than 90 days to be past due. As at December 31, 2010, $1.01 million of
accounts receivable are past due, excluding amounts described above, all of
which are considered to be collectible.
- Liquidity Risk
Liquidity risk is the risk the Company will encounter difficulties in meeting
its financial liability obligations. The Company manages its liquidity risk
through cash and debt management. See note 11 for a more detailed discussion.
As at December 31, 2010, Zargon had available unused committed bank credit
facilities of approximately $63.46 million compared to $102.81 million at
December 31, 2009. The Company believes it has sufficient funding through the
use of these facilities to meet foreseeable borrowing requirements.
The timing of cash outflows relating to financial liabilities are outlined in
the table below:
($ thousands) 1 year 2-3 years Total
----------------------------------------------------------------------------
Accounts payable and accrued liabilities 30,431 - 30,431
Cash distributions payable 3,750 - 3,750
Risk management liabilities (1) 10,737 3,080 13,817
Long term debt (2) - 115,285 115,285
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) See the section titled "Commodity Price Sensitivities" in this note for
a better understanding of the volatility around these amounts.
(2) See note 6 for the details on the credit facilities.
13. INCOME TAXES
The provision for income taxes in the consolidated statements of earnings and
comprehensive income and accumulated earnings reflect an effective rate which
differs from the expected statutory tax rate. Differences were accounted for as
follows:
($ thousands) 2010 2009
----------------------------------------------------------------------------
Statutory income tax rates 28.45% 29.42%
Expected income taxes expense (recovery) (772) (3,942)
Add (deduct) income tax effect of:
Rate adjustments 1,538 458
Trust distributions (14,440) (13,523)
Capital taxes and withholding taxes 212 285
Other 732 267
----------------------------------------------------------------------------
(12,730) (16,455)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
The future income tax liabilities reflect the net tax effects of temporary
differences between the carrying amounts of assets and liabilities for financial
reporting purposes and the amounts used for income tax purposes. The components
of Zargon's net future income tax liability are as follows:
($ thousands) 2010 2009
----------------------------------------------------------------------------
Net book value of property and equipment in
excess of tax pools 44,832 46,983
Deferred partnership earnings 8,568 7,560
Asset retirement obligations (11,067) (9,199)
Current unrealized risk management (asset)/liability (2,894) (495)
Long-term unrealized risk management (asset)/liability (830) (361)
Non-capital losses (23,555) (14,296)
Share issue costs (355) (491)
Other (233) (230)
----------------------------------------------------------------------------
14,466 29,471
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Zargon's estimated federal tax pools are as follows:
December December
($ thousands) 31, 2010 31, 2009
----------------------------------------------------------------------------
Canadian oil and gas property expenses 75,983 74,239
Canadian development expenses 52,208 47,713
Canadian exploration expenses 55,846 49,411
Capital cost allowance 57,879 61,290
Non-capital losses 100,521 60,600
US tax pools 2,260 2,425
Partnership deferral (1,023) (6,290)
Other 2,699 3,750
----------------------------------------------------------------------------
346,373 293,138
----------------------------------------------------------------------------
----------------------------------------------------------------------------
For tax purposes, the Company has $0.55 million allowable capital losses derived
from the dissolution of one of its US subsidiaries in 2010; however, the future
benefits have not been recorded in the consolidated financial statements as the
Company does not anticipate any capital gains. The allowable capital loss can be
carried forward indefinitely but only used to offset future taxable capital
gains.
14. COMMITMENTS
The Company is committed to future minimum payments for natural gas
transportation sales commitments in addition to operating leases for office
space, office equipment and vehicles. Payments required under these commitments
for each of the next five years are: 2011 - $2.47 million; 2012 - $1.78 million;
2013 - $1.66 million; 2014 - $1.66; 2015 - $0.97 million; thereafter - nil.
15. CONTINGENCIES AND GUARANTEES
In the normal course of operations, Zargon executes agreements that provide for
indemnification and guarantees to counterparties in transactions such as the
sale of assets and operating leases.
These indemnifications and guarantees may require compensation to counterparties
for costs and losses incurred as a result of various events, including breaches
of representations and warranties, loss of or damages to property, environmental
liabilities or as a result of litigation that may be suffered by counterparties.
Certain indemnifications can extend for an unlimited period and generally do not
provide for any limit on the maximum potential amount. The nature of
substantially all of the indemnifications prevents the Company from making a
reasonable estimate of the maximum potential amount that might be required to
pay counterparties as the agreements do not specify a maximum amount, and the
amounts depend on the outcome of future contingent events, the nature and
likelihood of which cannot be determined at this time.
The Company indemnifies its directors and officers against any and all claims or
losses reasonably incurred in the performance of their services to the Company
to the extent permitted by law. The Company has acquired and maintains liability
insurance for its directors and officers. The Company is party to various legal
claims associated with the ordinary conduct of business. The Company does not
anticipate that these claims will have a material impact on its financial
position.
Towards the end of 2010, Canada Revenue Agency commenced a flow-through share
audit on one of Zargon's previously acquired companies. The audit is currently
in the preliminary stage and, therefore, an estimate of any potential contingent
loss is not determinable at this time.
16. CHANGES IN NON - CASH WORKING CAPITAL
Year Ended December 31,
----------------------------------------------------------------------------
($ thousands) 2010 2009
----------------------------------------------------------------------------
Changes in non-cash working capital items:
Accounts receivable 2,340 (4,498)
Prepaid expenses and deposits (178) (851)
Accounts payable and accrued liabilities (4,076) 5,820
Cash distributions payable (407) 831
Working capital acquired from corporate acquisitions (3,410) (6,681)
Foreign exchange and other (207) (999)
----------------------------------------------------------------------------
(5,938) (6,378)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Changes relating to operating activities (11,251) 2,476
Changes relating to financing activities (408) 831
Changes relating to investing activities 5,721 (9,685)
----------------------------------------------------------------------------
(5,938) (6,378)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
17. SUPPLEMENTAL CASH FLOW INFORMATION
($ thousands) 2010 2009
----------------------------------------------------------------------------
Cash interest paid 4,465 3,558
Cash taxes paid 2,654 1,204
----------------------------------------------------------------------------
----------------------------------------------------------------------------
18. SEGMENTED INFORMATION
Zargon's entire operating activities are related to exploration, development and
production of oil and natural gas in the geographic regions of Canada and the
US.
2010
----------------------------------------------------------------------------
($ thousands) Canada United States Combined
----------------------------------------------------------------------------
Petroleum and natural gas revenue 164,113 15,359 179,472
Earnings/(losses) before income taxes (8,938) 6,227 (2,711)
Property and equipment, net 407,395 31,833 439,228
Total assets 437,410 34,238 471,648
Goodwill 2,969 - 2,969
Net capital expenditures 60,022 2,650 62,672
----------------------------------------------------------------------------
----------------------------------------------------------------------------
2009
----------------------------------------------------------------------------
($ thousands) Canada United States Combined
----------------------------------------------------------------------------
Petroleum and natural gas revenue 141,012 14,973 155,985
Earnings/(losses) before income taxes (19,313) 5,914 (13,399)
Property and equipment, net 394,448 31,516 425,964
Total assets 430,653 33,725 464,378
Goodwill 2,969 - 2,969
Net capital expenditures 47,682 573 48,255
----------------------------------------------------------------------------
----------------------------------------------------------------------------
19. CASH DISTRIBUTIONS
During the year, the Company declared distributions to the unitholders in the
aggregate amount of $50.76 (1) million (2009 - $45.96 million) in accordance
with the following schedule:
2010 Distributions Record Date Distribution Date Per Trust Unit
----------------------------------------------------------------------------
January January 31, 2010 February 15, 2010 $0.18
February February 28, 2010 March 15, 2010 $0.18
March March 31, 2010 April 15, 2010 $0.18
April April 30, 2010 May 17, 2010 $0.18
May May 31, 2010 June 15, 2010 $0.18
June June 30, 2010 July 15, 2010 $0.18
July July 31, 2010 August 16, 2010 $0.18
August August 31, 2010 September 15, 2010 $0.18
September September 30, 2010 October 15, 2010 $0.18
October October 31, 2010 November 15, 2010 $0.18
November November 30, 2010 December 15, 2010 $0.18
December December 31, 2010 January 17, 2011 $0.18
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1) The 2010 cash distributions include a non-cash equity issuance amount of
$3.41 million for the Dividend/Distribution Reinvestment Plan which
commenced in April 2010.
2009 Distributions Record Date Distribution Date Per Trust Unit
----------------------------------------------------------------------------
January January 31, 2009 February 16, 2009 $0.18
February February 28, 2009 March 16, 2009 $0.18
March March 31, 2009 April 15, 2009 $0.18
April April 30, 2009 May 15, 2009 $0.18
May May 31, 2009 June 15, 2009 $0.18
June June 30, 2009 July 15, 2009 $0.18
July July 31, 2009 August 17, 2009 $0.18
August August 31, 2009 September 15, 2009 $0.18
September September 30, 2009 October 15, 2009 $0.18
October October 31, 2009 November 16, 2009 $0.18
November November 30, 2009 December 15, 2009 $0.18
December December 31, 2009 January 15, 2010 $0.18
----------------------------------------------------------------------------
----------------------------------------------------------------------------
20. RELATED PARTY TRANSACTIONS
Zargon paid $0.01 million (2009 - $0.05 million) for vehicle leases to a company
owned by a Board member and $0.66 million (2009 - $0.41 million) for legal
services to a law firm of which a Board member is a partner. These payments were
in the normal course of operations, were made on commercial terms, and were
therefore recorded at their exchange amounts.
21. COMPARATIVE FIGURES
Certain comparative figures have been reclassified to conform with the current
year's financial statement presentation.
Forward-looking Statements - This press release offers our assessment of
Zargon's future plans and operations as at March 9, 2011, and contains
forward-looking statements including:
-- our expected profitability of exploitation projects and the impact on
returns to shareholders in the first paragraph of this press release;
-- our expectations for drilling activity and the results therefrom
referred to under the headings "2011 First Quarter Operational
Highlights" and "2011 Updated Guidance";
-- our expectations for capital spending, drilling and field optimization
activities and production referred to under the heading "2011 Updated
Guidance";
-- our expectations for production costs referred to under the heading
"Production Expenses";
-- our distribution/dividend policy referred to under the headings "2010
Highlights" and "Liquidity and Capital Resources";
-- our expectations as to the impact of legislated modifications to Alberta
Crown royalties referred to under the heading "Royalties";
-- our expectations for taxes referred to under the heading "Current Income
Taxes";
-- our expectations for our new Share Award Plan referred to under the
heading "Share-Based Compensation";
-- our expected sources of funds for distributions/dividends and capital
expenditures referred to under the heading "Liquidity and Capital
Resources";
-- our expectations for key business parameters referred to under the
heading "Funds Flow from Operating Activities"; and
-- our expectations for interest expenses referred to under the heading
"Bank Debt".
Such statements are generally identified by the use of words such as
"anticipate", "continue", "estimate", "expect", "forecast", "may", "will",
"project", "should", "plan", "intend", "believe" and similar expressions
(including the negatives thereof). By their nature, forward-looking statements
are subject to numerous risks and uncertainties, some of which are beyond our
control, including such as those relating to results of operations and financial
condition, general economic conditions, industry conditions, changes in
regulatory and taxation regimes, volatility of commodity prices, escalation of
operating and capital costs, currency fluctuations, the availability of
services, imprecision of reserve estimates, geological, technical, drilling and
processing problems, environmental risks, weather, the lack of availability of
qualified personnel or management, stock market volatility, the ability to
access sufficient capital from internal and external sources and competition
from other industry participants for, among other things, capital, services,
acquisitions of reserves, undeveloped lands and skilled personnel. Risks are
described in more detail in our Annual Information Form, which is available on
our website and at www.sedar.com. Forward-looking statements are provided to
allow investors to have a greater understanding of our business.
You are cautioned that the assumptions, including among other things, future oil
and natural gas prices; future capital expenditure levels; future production
levels; future exchange rates; the cost of developing and expanding our assets;
our ability to obtain equipment in a timely manner to carry out development
activities; our ability to market our oil and natural gas successfully to
current and new customers; the impact of increasing competition, our ability to
obtain financing on acceptable terms; and our ability to add production and
reserves through our development and acquisition activities used in the
preparation of such information, although considered reasonable at the time of
preparation, may prove to be imprecise and, as such, undue reliance should not
be placed on forward-looking statements. Our actual results, performance, or
achievement could differ materially from those expressed in, or implied by,
these forward-looking statements. We can give no assurance that any of the
events anticipated will transpire or occur, or if any of them do, what benefits
we will derive from them. The forward-looking information contained in this
document is expressly qualified by this cautionary statement. Our policy for
updating forward- looking statements is that Zargon disclaims, except as
required by law, any intention or obligation to update or revise any
forward-looking statements, whether as a result of new information, future
events or otherwise.
Other Advisories - Boe's may be misleading, particularly if used in isolation. A
boe conversion ratio of 6 Mcf:1 bbl is based on an energy equivalency conversion
method primarily applicable at the burner tip and does not represent a value
equivalency at the wellhead. The estimates of reserves and future net revenue
for individual properties may not reflect the same confidence level as estimates
of reserves and future net revenue for all properties, due to the effects of
aggregation.
Zargon Oil & Gas Ltd. is a Calgary based oil and natural gas company working in
the Western Canadian and Williston sedimentary basins with a long history of
earnings and distributions/dividends. Zargon's smaller size and technical focus
provides a unique opportunity to deliver profitable oil exploitation results
from smaller oil projects that may be overlooked by larger competitors.
In order to learn more about Zargon, we encourage you to visit Zargon's website
at www.zargon.ca where you will find a current shareholder presentation,
financial reports and historical news releases.
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