CALGARY, May 9 /PRNewswire-FirstCall/ -- (CNE.UN- TSX; CNE - NYSE)
Canetic Resources Trust ("Canetic" or the "Trust" or "We") is
pleased to announce its financial and operating results for the
three months ending March 31, 2006. Highlights of the first quarter
include: - On January 5, 2006, Canetic was formed on the completion
of the merger of Acclaim Energy Trust ("Acclaim") and StarPoint
Energy Trust ("StarPoint"). Canetic is now one of the largest
conventional oil and gas trusts in Canada with an enterprise value
of more than $5 billion. - The Acclaim and StarPoint properties,
information systems and staff were integrated as planned on the
completion of the merger. - On February 15, 2006, Canetic listed on
the New York Stock Exchange and commenced trading under the symbol
CNE. - Production for the quarter averaged 72,737 boe/d, excluding
StarPoint volumes for the first four days of January prior to the
date of the merger. Including StarPoint volumes for the first four
days of January, combined production for Canetic from January 1,
2006, to March 31, 2006 averaged 74,250 boe/d. - Cash flow for the
first quarter increased 141 percent to $194.7 million as compared
to $80.8 million for the same period in 2005. - Monthly
distributions increased to $0.23 per unit resulting in a payout
ratio of 68 percent during the quarter. This represents an increase
in monthly distributions of 18 percent to former Acclaim
unitholders and 5 percent to former StarPoint unitholders. This
also represents 42 consecutive months of sustained or increased
distributions for former Acclaim unitholders and 15 consecutive
months for former StarPoint unitholders. - During the quarter,
Canetic was active in the exploitation of the combined assets,
incurring $67.0 million in development expenditures while
participating in the drilling of 103 gross wells with a 98 percent
success rate. The program resulted in 62 gross (29.5 net) gas
wells, 37 gross (22.2 net) oil wells, 2 gross (0.2 net) service
wells and 2 gross (1.5 net) dry and abandoned wells. The merger of
Acclaim and StarPoint has been accounted for as a purchase by
Acclaim and accordingly, the comparative figures are that of
Acclaim for the same period of 2005. Additionally, as the merger
occurred January 5, 2006, all financial and operating results of
the StarPoint properties have been excluded for the first four days
of the quarter. All unitholders are welcome to attend the Annual
Meeting on May 9, 2006 in the Main Ballroom at the Metropolitan
Centre, 333 - 4th Avenue S.W., Calgary, Alberta at 3:00 p.m.
Calgary time or participate via the webcast on Canetic's website at
http://www.canetictrust.com/. FINANCIAL AND OPERATING SUMMARY
Financial ($millions except Three Months Ended March 31 per share
amounts) 2006(1) 2005 %
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Gross revenue 350.3 171.2 105% Cash flow from operations 194.7 80.8
141% Per unit - basic(2) 0.97 0.92 5% Per unit - diluted(2) 0.96
0.91 5% Net earnings (loss) 59.2 (16.8) - Per unit - basic(2) 0.29
(0.19) - Per unit - diluted(2) 0.29 (0.19) - Distributions 132.9
50.7 162% Per unit(2) 0.6900 0.4875 42%
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Capital expenditures Development expenditures 67.0 26.1 157% Net
capital expenditures 2,582.6 24.9 10272% Total assets 4,937.4
1,536.1 221% Long-term debt 838.1 334.8 150% Net debt (excluding
financial derivatives) 828.0 292.1 - Unitholders' equity 3,282.2
734.3 347%
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Weighted average trust units outstanding (000s)(2) 200,705 87,392
130% Trust units outstanding at period end (000s)(2) 201,182 86,313
133%
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Operating Production Natural gas (mmcf/d) 176.1 104.1 69% Crude oil
(bbl/d) 37,625 19,043 98% Natural gas liquids (bbl/d) 5,763 5,698
1% Barrel of oil equivalent (boe/d) @ 6:1 72,737 42,089 73%
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Average prices Natural gas ($/mcf) 8.94 7.02 27% Natural gas
($/mcf) (net of financial instruments) 9.13 7.06 29% Crude oil
($/bbl) 54.33 51.09 6% Crude oil ($/bbl) (net of financial
instruments) 51.08 44.38 15% Natural gas liquids ($/bbl) 46.86
34.93 34%
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Drilling activity (gross) Gas wells 62 16 - Oil wells 37 4 -
Standing/service 2 - - Dry and abandoned 2 - -
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Total gross wells 103 20 -
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Total net wells 53.4 5.6 - Success rate (%) 98% 100% - (1) Includes
the financial and operating results of StarPoint from the date of
the merger, January 5, 2006. (2) All units of Acclaim up to the
merger on January 5, 2006 have been restated using the exchange
ratio of 0.8333 of a Canetic unit for each Acclaim unit.
PRESIDENT'S MESSAGE The first quarter of 2006 saw the formation of
Canetic, a new benchmark energy trust, from the merger of Acclaim
and StarPoint on January 5, 2006. The combined entity is now the
third largest conventional oil and gas trust in Canada with an
enterprise value of more than $5 billion. We believe the merger was
strategic and that it provides unitholders with a high quality
asset base, a reserve base of 238 million boe on a proved plus
probable basis; a Reserve Life Index of approximately nine years; a
diversified production base weighted 60 percent towards primarily
light oil and 40 percent to natural gas; a high quality, low risk
development drilling inventory; and a strong balance sheet. One of
our objectives in completing the merger was to be aggressive with
the integration of the two organizations and "hit the ground
running" on January 5, 2006. We are pleased to report that the
targets were met and the information systems, data and staff were
integrated at close, including the addition of over 40 new
employees. The management and employees of both Acclaim and
StarPoint worked diligently through the challenges presented by
such a large undertaking with great success. As a measure of that
success, Canetic had a very active exploitation and optimization
program in the first quarter of 2006. Canetic's operated program
resulted in the drilling of 31 gross (27.2 net) wells while also
participating in 72 gross (26.2 net) wells operated by our partners
with a 98 percent success rate. In addition, we also completed 230
optimization and facility projects during the quarter which
continued to add production at very efficient rates. On February
15, 2006, Canetic began trading under the symbol CNE on the New
York Stock Exchange. We believe Canetic is now well positioned to
create long term value for its unitholders through a quality asset
base, a strong balance sheet and quality people. Additionally, the
combined Trust has a greater weighting in the TSE indexes, and
through the NYSE listing, should have greater access to capital. We
believe this positions the Trust to be more competitive in pursuing
and executing strategic acquisitions and in diversifying our asset
base through investment in long term, more capital intensive
projects. FINANCIAL RESULTS The merger of Acclaim and StarPoint has
been accounted for as a purchase of StarPoint by Acclaim.
Accordingly, the financial and operating results of StarPoint have
been included from the date of acquisition, January 5, 2006. The
comparative results for 2005 are those of Acclaim only. All
disclosures of units and per unit amounts of Acclaim up to the
merger on January 5, 2006 have been restated using the exchange
ratio of 0.8333 of a Canetic unit for each Acclaim unit. For the
three months ended March 31, 2006, Canetic revenue and cash flow
more than doubled and production levels were up 73 percent compared
to the same period in 2005 due to the merger of Acclaim and
StarPoint and continued strong commodity prices. Canetic's gross
revenue for the first quarter of 2006 totaled $350.3 million, up
105 percent from $171.2 million reported by Acclaim in the first
quarter of 2005 and up 50 percent from $234.1 million in the last
quarter of 2005. Cash flow from operations increased to $194.7
million or $0.97 per basic unit, an increase of 141 percent from
$80.8 million or $0.92 per basic unit, for the same period in 2005.
This also represents an 83 percent increase from Acclaim's cash
flow of $106.5 million reported in the fourth quarter of 2005. Our
2006 cash flow includes a realized financial derivative loss of
$8.0 million compared to a loss of $11.1 million for the same
period in 2005. The increase in cash flow is due to higher
production levels associated with the StarPoint merger and higher
commodity prices. Net earnings for the three months ended March 31,
2006 totaled $59.2 million or $0.29 per basic unit compared to a
loss of $16.8 million or $0.19 per basic unit for the same period
in 2005. The price of West Texas Intermediate (WTI) crude averaged
US$63.53 per barrel during the first quarter of 2006, up 27 percent
from the average price of US$49.90 per barrel for the same period
in 2005. The Trust received an average crude oil price, before
adjustments for financial instruments, of $54.33 per barrel as
compared to $51.09 per barrel for the comparable period in 2005.
The Trust's corporate average price for natural gas before
adjustments for financial instruments was $8.94 per thousand cubic
feet as compared to $7.02 per thousand cubic feet for the same
period in 2005. Capital spending on development activities for the
three months ended March 31, 2006 totaled $67.0 million, 156
percent greater than the $26.1 million incurred in the same period
in 2005. Additionally, the consideration for the acquisition of
StarPoint was $2,511.7 million, resulting in net capital
expenditures of $2,582.6 million in the first quarter of 2006.
REVIEW OF OPERATIONS Canetic's first quarter of operations was
highlighted by a significant increase in drilling activity and an
expanded optimization program relative to the same period in 2005.
In total, 103 gross (53.4 net) wells were drilled during the first
three months of 2006, with activity primarily focused in the
Williston Basin and Rocky areas as well our coalbed methane ("CBM")
plays. Drilling resulted in 62 gross (29.5 net) gas wells, 37 gross
(22.2 net) oil wells, 2 gross (0.2 net) service wells and 2 gross
(1.5 net) dry and abandoned wells with a 98 percent success rate.
Optimization continued to play a key role in the Trust's ongoing
development program. Canetic executed on over 230 optimization and
facility events during the quarter. Canetic invested a total of
$67.0 million of capital during the first quarter including $39.2
million for drilling, $15.2 million for optimization, $8.7 million
for workovers and recompletions, $1.1 million for geological
expenditures and $2.7 million on land acquisitions. Production for
the quarter averaged 72,737 boe/d, excluding StarPoint volumes for
the first four days of January prior to the close of the merger. If
StarPoint volumes had been included from January 1, 2006,
production for Canetic from January 1, 2006, to March 31, 2006
would have averaged 74,250 boe/d. Operating costs remained on
budget, averaging $8.49 per boe during the quarter. As increased
levels of activity across the sector continue to put upward
pressure on costs Canetic will continue to pursue cost saving
initiatives. The first quarter of 2006 was highlighted by
aggressive exploitation activity in the following areas: - In the
Williston Basin, which includes southeast Saskatchewan, southwest
Manitoba and North Dakota, Canetic participated in the drilling of
28 gross (17.5 net) oil wells with a 100 percent success rate. All
28 wells were tied in and on production prior to the quarter end.
Multi-well programs have been identified in the southeast
Saskatchewan area for second and third quarter of 2006. - Canetic
was also active in our CBM plays during the first quarter of 2006.
During the quarter, Canetic drilled 11 gross (3.6 net) gas wells in
the Horseshoe Canyon play in central Alberta. Another 10 gross (6.2
net) gas wells were drilled in the Powder River Basin coals in
Wyoming. The maturity of this basin enables the production of sales
volumes within six months of initiating the dewatering process. A
further 3 gross (1.4 net) gas wells were drilled in the Upper
Mannville coals at the Doris and Corbett properties in south
central Alberta. Continued industry activity and the incorporation
of horizontal drilling technology in the Upper Mannville coal play
has significantly reduced dewatering times. As a result, wells
drilled during the first quarter of 2006 are expected to be
producing sales volumes within three to five months. Each of these
three areas will see increased activity throughout the remainder of
2006 with up to 70 new CBM wells planned. - In the Rocky area, a
total of 15 gross (8.2 net) wells were drilled during the first
quarter. The activity was primarily in Willesden Green where 14
gross (7.2 net) gas wells targeted the Edmonton Sands, Belly River
Sands and Rock Creek formations with a 100 percent success rate. Up
to 25 wells remain to be drilled through the remainder of 2006,
with 22 of those targeting gas. - In the Peace River Arch area,
Canetic drilled 9 gross (3.4 net) wells resulting in 5 gross (3.4
net) gas wells and 4 gross (0.5 net) oil wells with a 100 percent
success rate. Gas drilling was focused on the Pouce Coupe assets
targeting the Halfway, Montney and Doig formations. Canetic expects
to have four gas wells on-stream prior to the end of the second
quarter. The Trust is proceeding with the construction of a
compressor facility at Pouce Coupe which is expected to be in place
early in the third quarter resulting in additional incremental
production. Additionally, Canetic participated in the shooting of a
24 km2 3D program in the Pouce Coupe area and will be using the
results to aggressively pursue the Halfway, Montney and Doig
formations during the remainder of 2006. During the first quarter
Canetic drilled its first joint venture Cadomin well at Blackhawk,
located in northeastern British Columbia. Canetic is a 20 percent
participant with a 50 percent interest at the equip and tie-in
stage. This drill followed a 76 km2 3D seismic program that was
shot earlier in the quarter. Canetic is expecting to participate in
at least two other similar wells before the end of the second
quarter. - Additional drilling was completed in other areas
including Drayton Valley, Southern Alberta and Central Alberta. In
our fourth quarter press release we noted that our targeted
production could be impacted by the decline of Leduc D3a production
at Acheson, tie in delays and capacity constraints at Pouce Coupe
and Willesden Green. Although production from the D3a pool at
Acheson has significantly outperformed our expectations since we
acquired this property as part of the Chevron/Texaco acquisition in
June 2004, we experienced a greater decline than anticipated in the
first quarter of 2006. Accordingly, we now expect that annual
production for 2006 will average between 72,000 and 74,000 boe/d.
It is important to note that our 2006 drilling and optimization
programs remain on track and continue to add production and
reserves as planned. CASH DISTRIBUTIONS & TAXABILITY Canetic
paid distributions of $132.9 million during the quarter or $0.69
per Trust unit. This represents a payout ratio of 68 percent. The
first distribution of $0.23 per unit per month for Canetic was paid
February 15, 2006 to unitholders of record on January 31, 2006.
Based on our current business and financial model, Canetic
continues to estimate that for 2006 income tax purposes, our
distributions will be comprised of 5 to 15 percent return of
capital and 85 to 95 percent income for Canadian investors. For US
investors, we estimate that our distributions for 2006 will be zero
to 10 percent return of capital and 90 to 100 percent qualifying
dividend income as computed under US income tax law. This tax
estimate is based on information available to Management as of May
9, 2006, and is subject to change based on a variety of
circumstances including, but not limited to, commodity prices,
acquisitions and tax and royalty rates. Actual taxable and return
of capital amounts will be provided in early 2007. COMMODITY PRICE
RISK MANAGEMENT The price of West Texas Intermediate (WTI) crude
averaged US$63.53 per barrel during the first quarter of 2006, up
27 percent from the average price of US$49.90 per barrel for the
same period in 2005. Canetic's average crude oil price, before
adjustments for financial instruments, was $54.33 per barrel
compared to $51.09 per barrel for the comparable period in 2005.
Although the price of WTI has increased substantially over the past
year, the price received by Canadian producers has not increased by
the same proportional amount. We believe that this is due to the
seemingly contradictory events of physical crude oil inventories
being at historically high levels at a time when political tensions
and other factors cast concerns over global crude oil supplies. We
believe that concerns about Iran's plutonium enrichment program,
rebel conflicts in Nigeria and ongoing supply disruptions from Iraq
coupled with continued high demand growth from China and the Far
East have pushed the benchmark WTI futures contract on the New York
Mercantile Exchange (NYMEX) to record closing levels. We are of the
view that these concerns have created a risk premium for
financially traded barrels on the NYMEX that is not entirely
captured by producers, resulting in a widening gap between the
NYMEX price and the producer's actual sales price. The most
commonly quoted benchmark price for Canadian natural gas is the
AECO Daily Index which averaged $7.52 per thousand cubic feet
during the first quarter of 2006, up 9 percent from the average
price of $6.90 per thousand cubic feet for the same period in 2005.
Canetic's corporate average price, before adjustments for financial
instruments, was $8.94 per thousand cubic feet versus $7.02 per
thousand cubic feet for the same period in 2005. In an effort to
mitigate price volatility, Canetic splits its natural gas sales
evenly between daily and monthly pricing indexes. This strategy
benefited Canetic in the first quarter as the AECO Monthly Index
price averaged $9.30 per thousand cubic feet, significantly higher
than the benchmark AECO Daily Index price for the same period. The
winter of 2005-2006 was one of the warmest on record and has been
much publicized as the primary cause for the sharp decline in
natural gas prices in the first quarter of 2006. This is North
America's second unusually warm winter in succession and natural
gas inventories are at their highest end-of-winter level ever. We
believe that concerns of possibly over-filling storage during the
summer injection season has caused natural gas prices to weaken on
both the spot and futures market. In addition to the warm winter,
it is believed that there has been some discretionary loss of
industrial demand for natural gas in the second half of last year
due to the high prices at that time and some temporary demand loss
due to hurricanes Katrina and Rita. Canetic believes that current
inventory levels are the result of short-term factors and that
natural gas is still a scarce resource in North America with
significant potential for price increases. OUTLOOK One of our
objectives on the completion of the Acclaim/StarPoint merger was to
"hit the ground running". We are pleased with our progress which
can be measured somewhat by our results for the first quarter of
2006 as well as by the level of exploitation activity reported. On
an operated basis, we drilled 31 gross wells while participating in
72 gross wells operated by our partners. For the balance of 2006,
we will continue to actively exploit our asset base, particularly
in the second half of 2006. We are encouraged by the results of our
first quarter program and as a result, our capital budget will
remain at approximately $320 million. This level of capital
expenditure will allow us to participate in the drilling of
approximately 270 gross wells. We have reduced slightly our
production forecast range from 73,500-75,500 boe/d to 72,000-74,000
boe/d to reflect the one time impact at Acheson. Our capital
programs continue to deliver production and reserves at very
efficient rates. We remain excited about the future prospects of
Canetic. We truly believe that we have created an entity that is
well positioned for the long term, with significant asset depth and
diversity, great opportunities and quality people. We also continue
to look for both asset and corporate acquisition opportunities
which complement our current asset base as well as maintaining a
leadership role in the consolidation of oil and gas trusts.
Canetic's complete Financial Statements and Notes and Management
Discussion and Analysis are available on Canetic's website at
http://www.canetictrust.com/ or on SEDAR at http://www.sedar.com/
or on EDGAR at http://www.edgar.com/. ADVISORY: FORWARD LOOKING
STATEMENTS: Certain information regarding Canetic Resources Trust
including management's assessment of future plans and operations,
may constitute forward-looking statements under applicable
securities law and necessarily involve known and unknown risks,
including, without limitation, risks associated with oil and gas
exploration, development, exploitation, production, marketing and
transportation, loss of markets, volatility of commodity prices,
currency fluctuations, imprecision of reserve estimates,
environmental risks, competition, incorrect assessment of the value
of acquisitions, failure to realize the anticipated benefits of
acquisitions, inability to access sufficient capital from internal
and external sources, changes in legislation, including but not
limited to income tax and environmental laws and regulatory
matters; as a consequence, actual results may differ materially
from those anticipated in the forward-looking statements. Readers
are cautioned that the foregoing list of factors is not exhaustive.
Additional information on these and other factors that could affect
Canetic's operations or financial results are included in Canetic's
reports on file with Canadian securities regulatory authorities and
may be accessed through the SEDAR website (http://www.sedar.com/),
the EDGAR website (http://www.edgar.com/), Canetic's website
(http://www.canetictrust.com/) or by contacting Canetic.
Furthermore, the forward-looking statements contained in this news
release are made as of the date of this news release, and Canetic
does not undertake any obligation to update publicly or to revise
any of the included forward-looking statements, whether as a result
of new information, future events or otherwise, except as expressly
required by securities law. NON-GAAP MEASURES We use the term cash
flow, which we define as net earnings before deducting non-cash
expenses, to analyze operating performance and leverage. Cash flow
does not have a standardized measure prescribed by GAAP and
therefore may not be comparable with the calculation of similar
measures for other companies or trusts. We use the term payout
ratio, which we define as distributions to unitholders divided by
cash flow. Payout ratio does not have a standardized measure
prescribed by GAAP and therefore may not be comparable with
calculations of similar measures for other companies or trusts. We
use the term net debt, which we define as long-term debt and
working capital, to analyze liquidity and capital resources. Net
debt does not have a standardized measure prescribed by GAAP and
therefore may not be comparable with calculations of similar
measures for other companies or trusts. Where reserves or
production are stated on a barrel of oil equivalent (boe) basis,
natural gas volumes have been converted to a barrel of oil
equivalent (boe) at a ratio of 6,000 cubic feet of natural gas to
one barrel of oil. This conversion ratio is based upon an energy
equivalent conversion method primarily applicable at the burner tip
and does not represent value equivalence at the wellhead. Boe may
be misleading, particularly if used in isolation. Additional
Information Additional information regarding the Trust and its
business operations, including the Trust's annual information form
for the period ended December 31, 2005, is available on the Trust's
SEDAR company profile at http://www.sedar.com/ or the EDGAR company
profile at http://www.edgar.com/. Consolidated Balance Sheets March
31 December 31 (unaudited) ($000s) 2006 2005
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ASSETS Current Assets Accounts receivable $ 257,764 $ 140,907
Prepaid expenses and deposits 22,212 11,630
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279,976 152,537 Property, plant and equipment, net 3,750,179
1,317,917 Goodwill 906,740 87,954 Deferred financing charges, net
of amortization 505 689 Deferred costs - 12,000
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Total assets $ 4,937,400 $ 1,571,097
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LIABILITIES AND UNITHOLDERS' EQUITY Current Liabilities Accounts
payable and accrued liabilities $ 223,642 $ 157,368 Distributions
payable 46,251 17,834 Financial derivative liability 49,514 22,965
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319,407 198,167 Bank debt 838,086 309,146 Convertible debentures
51,885 16,289 Financial derivative liability 35,065 8,763 Future
income taxes 288,266 202,110 Asset retirement obligations 122,499
68,235
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1,655,208 802,710 Non-controlling interest - 3,804 UNITHOLDERS'
EQUITY Capital 3,718,804 1,087,459 Convertible debentures 6,539 -
Contributed surplus - 40,836 Accumulated earnings 221,064 161,869
Accumulated distributions (664,215) (525,581)
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3,282,192 764,583
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Total liabilities and unitholders' equity $ 4,937,400 $ 1,571,097
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Consolidated Statements of Earnings and Accumulated Earnings Three
Months Ended March 31 (unaudited) ($000s except per unit amounts)
2006 2005
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REVENUE Petroleum and natural gas sales $ 350,346 $ 171,201 Royalty
expense (net of Alberta Royalty Tax Credit) (67,124) (37,174)
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283,222 134,027
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EXPENSES Operating 55,565 30,040 Transportation 4,444 2,095 General
and administrative 7,871 4,795 Interest 9,186 2,957 Interest on
convertible debentures 660 1,554 Unit-based compensation 6,973
2,432 Depletion, depreciation and amortization 150,518 58,291
Accretion of asset retirement obligations 2,451 1,173 Realized loss
on financial derivatives 8,029 11,100 Unrealized loss (gain) on
financial derivatives (4,934) 56,139
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240,763 170,576
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Earnings (loss) before taxes 42,459 (36,549) Provision for capital
taxes 2,726 683 Provision for future income taxes (recovery)
(19,462) (20,407)
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NET EARNINGS (LOSS) 59,195 (16,825) Accumulated earnings, beginning
of period 161,869 96,021
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Accumulated earnings, end of period $ 221,064 $ 79,196
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Net earnings (loss) per unit (2005 restated) Basic $ 0.29 $ (0.19)
Diluted $ 0.29 $ (0.19) Weighted average units outstanding (2005
restated) Basic 200,705 87,392 Diluted 203,016 88,536
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Consolidated Statements of Cash Flows Three Months Ended March 31
(unaudited) ($000s) 2006 2005
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CASH FLOWS RELATED TO THE FOLLOWING ACTIVITIES: OPERATING
ACTIVITIES Net earnings (loss) $ 59,195 $ (16,825) Adjustments for:
Unit-based compensation 6,973 2,432 Depletion, depreciation and
amortization 150,518 58,291 Accretion 2,451 1,173 Unrealized loss
(gain) on financial derivatives (4,934) 56,139 Provision for future
income taxes (recovery) (19,462) (20,407) Asset retirement costs
incurred (3,456) (260) Changes in non-cash operating working
capital (83,773) (55,085)
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107,512 25,458
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FINANCING ACTIVITIES Proceeds from bank debt 90,548 50,955 Proceeds
from issuance of units, net of issue costs 4,339 2,337
Distributions to unitholders (132,879) (50,677) Changes in non-cash
financing working capital - 199
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(37,992) 2,814
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69,520 28,272
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INVESTING ACTIVITIES Disposition of petroleum and natural gas
properties - 1,833 Capital expenditures (67,365) (26,724) Changes
in non-cash investing working capital (2,155) (3,381)
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Cash used in investing activities (69,520) (28,272)
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Cash beginning and end of period $ - $ -
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The Trust paid the following cash amounts: Interest paid $ 13,442 $
4,992 Capital taxes paid $ 6,446 $ -
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DATASOURCE: Canetic Resources Trust CONTACT: Investor Relations,
(403) 539-6300 or toll-free in North America 1-877-539-6300, ,
http://www.canetictrust.com/; To request a free copy of this
organization's annual report, please go to http://www.newswire.ca/
and click on Tools for Investors.
Copyright