CALGARY, Nov. 8 /PRNewswire-FirstCall/ -- (CNE.UN - TSX; CNE -
NYSE) - Canetic Resources Trust ("Canetic" or the "Trust") is
pleased to announce its operating and financial results for the
three and nine months ended September 30, 2007. "We have achieved
solid financial and operating results for the fourth consecutive
quarter despite the challenges posed by the current natural gas
pricing environment, continued cost escalation, facility
turnarounds and the rapid appreciation of the Canadian to U.S.
dollar exchange rate. We credit our strong performance this quarter
to our ability to successfully operate and sustain production
within our significant asset base," said J. Paul Charron, President
and Chief Executive Officer of Canetic. "We are also very excited
by our recently announced strategic combination with Penn West
Energy Trust ("Penn West") as we believe this combination will
strategically position our Trust and our unitholders for the
future. The combination creates Canada's flagship energy trust and
the premier independent light oil producer in Western Canada with
initial production in excess of 200,000 barrels of oil equivalent
("boe") per day in 2008 and conventional proven plus probable
reserves in excess of 800 million boe. The combined trust will have
the size, financial strength and flexibility to be the dominant oil
and natural gas trust in North America. Moving forward, we will
continue to seek further growth opportunities, within the Western
Canadian Sedimentary Basin and outside Canada, to enhance our
portfolio for long-term sustainability." Highlights - Production
volumes averaged 74,572 boe per day for the third quarter 2007,
compared to 74,475 boe per day for the third quarter 2006, and
reflect the impact of planned and unplanned turnarounds and outages
as well as normal production declines. On a year-to-date basis,
production volumes have averaged 77,435 boe per day in 2007
compared to 72,431 boe per day in 2006. These volumes reflect the
impact of production related to the 2006 Samson acquisition offset
by minor property dispositions of approximately 1,000 boe per day
in the second quarter 2007, outages, and natural production
declines. - During the third quarter 2007, Canetic generated cash
flow from operating activities of $182.5 million, an increase of 32
percent compared with the same period of 2006. For the nine months
ended September 30, 2007, cash flow from operating activities
increased 18 percent to $574.0 million from $485.8 million during
the comparable period of 2006. - Third quarter 2007 capital
expenditures for development activities totalled $88.0 million as
compared to $104.4 million for the same period in 2006. A total of
64 gross (27.4 net) wells were drilled during the quarter with a
success rate of 100 percent. On a year-to-date basis we have
drilled a total of 188 gross (96.6 net) wells, incurring
approximately $325.3 million on exploitation and development
activities. - On October 18, 2007, Canetic announced its agreement
to acquire Titan Exploration Ltd. ("Titan") creating a dominant
position in the emerging Lower Shaunavon play in Southwest
Saskatchewan. Canetic will acquire production of approximately
1,800 boe per day, weighted 63 percent to oil, and a Canetic
estimated 7.3 million boe of proved plus probable reserves with a
Reserve Life Index ("RLI") of approximately 11 years. Canetic will
also acquire approximately 73,000 net acres of undeveloped land
including over 49,000 gross (23,700 net) acres in the Leitchville
area overlaying the Lower Shaunavon trend. - On October 31, 2007,
Canetic and Penn West announced that they had entered into a
combination agreement (the "Combination Agreement") that would
provide for the strategic combination of Penn West and Canetic. The
combined trust will be the largest conventional oil and natural gas
trust in North America with an enterprise value of approximately
$15 billion and initial production in excess of 200,000 boe per
day. The combined asset portfolio will include interests in a
significant number of Western Canada's highest quality conventional
oil and natural gas pools and will also include a number of
non-conventional growth opportunities including oil sands, coalbed
methane, shale gas and enhanced oil recovery. At closing, this
merger of assets and people will operate under the Penn West name
and will be led by a management team and board of directors drawn
from each of Canetic and Penn West. Under the terms of the
Combination Agreement, Canetic unitholders will receive 0.515 of a
Penn West unit for each Canetic unit on a tax-deferred basis for
Canadian and U.S. tax purposes. Immediately prior to the closing of
the combination, a one-time special distribution of $0.09 per unit
will be paid to Canetic unitholders. The special distribution is
intended to keep Canetic unitholders whole, in cash distributions,
for a period of six months. Based on the closing price of Penn West
units on the Toronto Stock Exchange ("TSX") on October 30, 2007
Canetic unitholders will receive a premium of 7.1 percent to the
closing price of Canetic units on the TSX on October 30, 2007. On
completion of the combination, Penn West unitholders will own
approximately 67 percent and Canetic unitholders will own
approximately 33 percent of the combined trust. Penn West units
will continue to be listed on both the TSX and the New York Stock
Exchange ("NYSE"). The combination is subject to stock exchange,
court and regulatory approval, and the approval of at least 66 2/3
percent of the votes cast by Canetic unitholders at a unitholder
meeting to be held to approve the combination in mid January 2008
with closing to occur immediately thereafter. An Information
Circular is expected to be mailed to unitholders of Canetic in
early December 2007. A conference call will be held to discuss
Canetic's third quarter operating and financial results on November
9, 2007, at 11:00am mountain time (1:00pm eastern time). The call
number for participants is (416)644-3434 or toll-free
(800)814-4861. A replay of the conference call will be made
available approximately one hour following the call and remain
accessible until 11:59pm on November 16, 2007. The replay number is
(416)640-1917 or toll-free (877)289-8525 and the passcode is
21252717 followed by the pound key. FINANCIAL AND OPERATING SUMMARY
As At And For The As At And For The Three Months Ended Nine Months
Ended September 30 September 30
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($millions except % % per unit amounts) 2007 2006 change 2007 2006
change
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FINANCIAL Petroleum and natural gas sales 346.1 368.5 -6% 1,084.7
1,060.1 2% Funds flow(1) from operations 181.6 200.3 -9% 564.0
580.1 -3% Per unit - basic 0.80 0.95 -17% 2.48 2.91 -15% Per unit -
diluted 0.79 0.93 -15% 2.48 2.85 -13% Net earnings (loss) 15.7
102.7 -85% (293.0) 244.7 -220% Per unit - basic 0.07 0.49 -86%
(1.29) 1.23 -205% Per unit - diluted 0.07 0.48 -86% (1.29) 1.21
-206% Cash distributions 130.0 144.9 -10% 397.5 417.0 -5%
Distributions declared per unit 0.57 0.69 -17% 1.71 2.07 -17%
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Capital expenditures Net development expenditures 88.0 104.4 -16%
325.3 257.2 26% Net capital expenditures 101.5 1,078.4 -91% 303.7
3,773.0 -92% Total assets 5,578.4 5,853.2 -5% 5,578.4 5,853.2 -5%
Long-term debt 1,374.0 1,223.0 12% 1,374.0 1,223.0 12% Net debt(1)
1,404.2 1,254.4 12% 1,404.2 1,254.4 12% Unitholders' equity 2,887.7
3,662.5 -21% 2,887.7 3,662.5 -21%
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Weighted average trust units outstanding (000s) 228,328 210,226 9%
227,389 199,640 14% Trust units outstanding at period end (000s)
230,108 224,530 2% 230,108 224,530 2%
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OPERATING Production Natural gas (mmcf/d) 205.7 181.4 13% 212.2
174.5 22% Crude oil (bbl/d) 34,578 38,314 -10% 35,636 37,765 -6%
Natural gas liquids (bbl/d) 5,711 5,925 -4% 6,426 5,577 15% Crude
oil and NGLs (bbl/d) 40,289 44,239 -9% 42,062 43,342 -3% Barrels of
oil equivalent (boe/d) @ 6 mcf:1 bbl 74,572 74,475 0% 77,435 72,431
7%
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Average prices Natural gas ($/mcf) 5.33 6.21 -14% 6.91 7.04 -2%
Natural gas ($/mcf) (including financial instruments) 6.64 7.23 -8%
7.51 7.72 -3% Crude oil ($/bbl) 68.38 67.27 2% 61.79 63.03 -2%
Crude oil ($/bbl) (including financial instruments) 64.42 62.67 3%
59.88 58.63 2% Natural gas liquids ($/bbl) 50.60 50.60 0% 46.65
48.81 -4%
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Total ($/boe) 50.45 53.78 -6% 51.31 53.61 -4% Total ($/boe)
(including financial instruments) 52.22 53.91 -3% 52.09 52.96 -2%
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Drilling activity (gross) Natural gas 33 55 - 84 150 - Oil 31 34 -
92 101 - Other - 1 - 7 5 - Dry and abandoned - 2 - 5 7 -
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Total gross wells 64 92 - 188 263 -
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Total net wells 27.4 43.2 - 96.6 125.6 -
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Success rate (%) 100% 98% - 97% 97% -
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(1) Please see Non-GAAP measures in this news release. See also the
Non- GAAP measures section of Canetic Management's Discussion and
Analysis ("MD&A") available at http://www.sedar.ca/ or
http://www.sec.gov/ Note: All references are to Canadian dollars
unless otherwise indicated. Natural gas volumes recorded in
thousand cubic feet ("mcf") or million cubic feet ("mmcf") are
converted to barrels of oil equivalent ("boe") using the ratio of
six (6) thousand cubic feet to one (1) barrel of oil ("bbl"). BOEs
may be misleading, particularly if used in isolation. A BOE
conversion ratio of six (6) mcf: one (1) bbl is based on an energy
equivalent conversion method primarily applicable at the burner tip
and does not represent a value equivalent at the wellhead.
PRESIDENT'S MESSAGE We are pleased with the operational and
production performance of our existing high quality asset base and
continue to be encouraged by the strong results of our ongoing
exploitation and development activities undertaken to date. The
solid performance of our assets helped to partially mitigate the
impact of both planned and unplanned third party facility
turnarounds and outages experienced during the quarter. The
combined impact of turnaround activity, facility outages, weather,
and extended spring break-up related factors resulted in the loss
of an estimated 1,100 boe per day of production over the quarter.
Minor property dispositions in Northeast Alberta, effective April
30, 2007, accounted for an additional loss of approximately 1,100
boe per day of production during the quarter. In addition to our
continued focus on operations we have renewed our efforts on the
acquisition front. On October 18, 2007, Canetic announced its
agreement with Titan pursuant to which Canetic will acquire
production of approximately 1,800 boe per day, weighted 63 percent
to oil, and a Canetic estimated 7.3 million boe of proved plus
probable reserves with an RLI of approximately 11 years. More
importantly, Canetic will also acquire over 49,000 gross (23,700
net) acres of land, in the Leitchville area of Southwest
Saskatchewan, in close proximity to Canetic's existing 45,100 gross
(41,200 net) acres, to create a dominant position in the emerging
and strategically significant Lower Shaunavon trend. Current Titan
production in Southwest Saskatchewan exceeds 900 boe per day. In
addition to the production and lands in Southwest Saskatchewan,
Canetic will also acquire approximately 900 boe per day of
production located in the northern regions of Alberta and British
Columbia. Approximately two-thirds of this production is located in
the Peace River Arch region in close proximity to Canetic's
existing lands. On October 31, 2007, Canetic announced our
agreement to complete a strategic combination with Penn West that
will create Canada's flagship energy trust and the dominant
independent light oil producer in Western Canada with production in
excess of 200,000 boe per day in 2008 and conventional proven plus
probable reserves in excess of 800 million boe. The combination
will provide Canetic unitholders with exposure to a significantly
enhanced portfolio of unconventional development opportunities
including the multi-billion barrel (discovered heavy oil resources
in place) Peace River Oil Sands Project, a significant area for
potential future growth now available to Canetic unitholders. The
combination also serves to provide significantly greater exposure
to growth opportunities from coalbed methane, shale gas and
enhanced recovery from some of Canada's largest legacy light oil
pools. The increased size and financial strength of the combined
trust will help to accelerate the future development of both its
conventional and unconventional growth opportunities and will
provide added flexibility in positioning for 2011 and beyond. The
larger size of the combined trust is also expected to enhance
liquidity on the Toronto and New York stock exchanges and increase
its weighting in major indices, including the S&P/TSX 60 Index.
Thus leading to greater attention and potentially better valuation
from both equity and income investors. The increased liquidity and
enhanced financial flexibility is expected to facilitate further
expansion both within the Western Canadian Sedimentary Basin and
outside of Canada, further bolstering the competitiveness of the
combined trust beyond 2011. The combined trust will initially boast
tax pools in excess of $5.5 billion and safe harbour capacity for
growth, under the Undue Expansion rules set out for income trusts,
of approximately $8.7 billion on an equity basis in 2008, and
approximately $15 billion on an equity basis in total. Going
forward, we believe that unitholders of the combined trust will
benefit from the strength and experience of the combined board of
directors, management team and personnel. On the development front
we have continued to focus a significant proportion of our 2007
capital program on the exploitation and development of our
extensive inventory of high quality crude oil prospects, many of
which were acquired as part of the StarPoint transaction completed
early in 2006. Year-to-date we have operated or participated in the
drilling of 188 gross (96.6 net) wells at a total exploitation and
development cost of approximately $325.3 million. Highlights of the
third quarter 2007 development program include the successful
drilling of our first operated multi-lateral horizontal Mannville
coalbed methane well in the Corbett Creek area. Canetic holds a 100
percent working interest in this well which also served to validate
a 21 section exploration license in the active Mannville coalbed
methane play. We expect to complete the well and begin production
in 2008. Other activity included the successful drilling and
completion of two high rate oil wells in the strategically
important Leitchville area of Southwest Saskatchewan. Year-to-date,
Canetic has actively participated at Saskatchewan land sales
amassing approximately 20,000 acres on the Lower Shaunavon trend,
at a cost of approximately $24 million. This targeted activity
culminated in the highlighted announcement of our intention to
acquire Titan to create a dominant position in the Southwest
Saskatchewan trend, an area anticipated to provide significant
growth and development opportunity for Canetic. We continue to see
upward pressure on our cost base, primarily from increasing field
service costs, specifically power and labour. As we continue to
experience higher field costs through our asset base, considerable
effort and focus is being given to improving operational
efficiencies which are expected to help control operating costs on
a unit-of-production basis, including the divestiture of assets
which have a high cost base. Further challenges facing our industry
include the continued and rapid appreciation of the Canadian
dollar. The Canadian dollar continued to appreciate and moved above
par with the U.S. dollar by the end of the third quarter of 2007.
This will continue to impact our revenues as prices for both oil
and natural gas are based on U.S. dollar benchmarks thus reducing
overall margins we receive in Canadian dollars. Our commodity price
risk management program is primarily designed to provide price
protection on a portion of our future production in the event of
adverse commodity price movements, while retaining some
participation in favourable price movements. Canetic remains well
hedged in light of continuing weakness in natural gas prices.
Approximately 40 percent of natural gas production volumes are
hedged to March 31, 2008 under costless collars with a floor price
of approximately $7.00 per Gigajoule. In light of challenges posed
by today's changing economic and political environments we believe
the combination of Penn West and Canetic will create a platform
able to deliver incremental value for our unitholders and having
the financial strength to embark on strategic acquisitions and
initiatives that will optimize the combined trust's diverse
portfolio of oil and gas properties. We also believe it will help
to attract new talent and access to opportunities which will
further contribute to the foundation of world-class assets and
expertise. We believe our current course positions the combined
trust well to compete in today's environment and provide our
unitholders with a sustainable source of income. FINANCIAL Revenue
for the nine months ended September 30, 2007 totalled $1,084.7
million, an increase of two percent from $1,060.1 million for the
comparable period of 2006. Revenue for the third quarter 2007
totalled $346.1 million, a decrease of six percent compared to
$368.5 million during the same period of 2006. The decrease in
quarterly revenue year-over-year is largely attributable to
declines in crude oil volumes, softer natural gas prices and the
appreciation in the Canadian dollar relative to the U.S. dollar.
Funds flow from operations totalled $564.0 million or $2.48 per
diluted unit, down three percent from $580.1 million reported for
the corresponding period in 2006. Funds flow from operations,
during the third quarter totalled $181.6 million or $0.79 per
diluted unit, a decrease of nine percent from $200.3 million or
$0.93 per diluted unit in the same period of 2006 and a five
percent decrease from $192.0 million or $0.84 per diluted unit
during the second quarter of 2007. The net loss for the nine months
ended September 30, 2007, totalled $293.0 million or $1.29 per
diluted unit as compared to net income of $244.7 million reported
for the same period in 2006. Net income for the third quarter was
$15.7 million or $0.07 per diluted unit, as compared to $102.7
million or $0.48 per diluted unit in 2006. The net loss for the
nine months ended September 30, 2007, results from a one time
charge to future tax expense associated with the enactment of Bill
C-52 (Budget Implementation Act, 2007) which incorporated the
Specified Investment Flow-Through Rules (the "SIFT Rules") which
became law on June 22, 2007. The price of West Texas Intermediate
("WTI") crude averaged US$75.33 (Cdn$78.71) per bbl during the
third quarter 2007, compared to US$70.55 (Cdn$79.10) per bbl for
the same period in 2006. For the first nine months of 2007, WTI
crude averaged US$66.26 (Cdn$73.22) per bbl compared to US$68.29
(Cdn$77.32) per bbl for the same period in 2006. Crude oil prices
remain strong with global demand growth continuing to tighten the
supply-demand situation as inventories decline. As the year has
progressed there has been a continued call for OPEC production to
increase as Non-OPEC supply growth has not been able to meet this
increased demand. For the nine months ended September 30, 2007, we
received an average oil price of $61.79 per bbl as compared to
$63.03 per bbl for the comparable period in 2006. Our differentials
from the WTI crude oil prices fluctuate as premiums for our light
sweet crude oil are offset by increases in the differentials on
heavy crude oil. The AECO Monthly Index gas price averaged $5.61
per mcf in the third quarter of 2007, compared to $6.03 per mcf in
the third quarter 2006. Year-to-date, the AECO Monthly Index price
has averaged $6.81 per mcf, compared to $7.19 per mcf for the same
period in 2006. The AECO price continues to remain weak, consistent
with 2006 levels. We believe that the primary factors influencing
the AECO gas price are high inventory levels in North America
caused by robust drilling activity in the United States, growth in
liquefied natural gas spot cargos redirected into North America
from Europe due to weak gas prices there, and the lack of
significant weather patterns to draw down gas storage. The Western
Canadian Sedimentary Basin's ("WCSB") activity levels are expected
to remain weak until prices appreciate to a level where natural gas
margins improve to begin to drive supply. Our average realized
natural gas price was $6.91 per mcf for the nine months ended
September 30, 2007 as compared to $7.04 per mcf during the same
period in 2006. Our average natural gas price for the quarter was
$5.33 per mcf compared to $6.21 per mcf in the third quarter in
2006. During the third quarter of 2007, Canetic paid cash
distributions of $130.0 million or $0.57 per unit. For the nine
months ended September 30, 2007 our cash distributions totalled
$397.5 million. For 2007, we estimate that for Canadian taxpayers,
100 percent of cash distributions will be taxable and no portion of
the distributions will be a tax-deferred return of capital. We
estimate that for U.S. taxpayers, 100 percent of cash distributions
paid during the year will be taxable as "Qualified Dividends" and
no portion of the distributions will be a tax-deferred return of
capital. Actual taxable amounts may vary and is dependant upon the
Trust's current and accumulated earnings and profits as determined
under U.S. tax laws. REVIEW OF OPERATIONS Production For the nine
months ended September 30, 2007, production volumes averaged 77,435
boe per day as compared to 72,431 boe per day for the same period
in 2006. The seven percent increase in average production volumes
for the nine months ended September 30, 2007 reflect the full
impact of the Samson acquisition which closed on August 31, 2006.
Production in 2007 has been impacted by planned and unplanned
turnaround activity, weather related downtime in the second and
third quarter and minor property dispositions. We continue to add
new production volumes through our active drilling and optimization
programs which focused in the Rocky, Central and Southern Alberta
areas during the third quarter. Third quarter volumes were
negatively impacted by planned and unplanned outages, with a
resulting impact of approximately 1,200 boe per day. Major outages
occurred at the non-operated Kaybob South and Keyera plants, with
smaller non-operated outages in Saskatchewan. In addition, our
third quarter volumes were impacted by minor property dispositions
totalling approximately 1,000 boe per day in Northeastern Alberta,
primarily natural gas. Looking forward to the fourth quarter, we
are anticipating a number of outages that will impact production.
We expect that each outage individually will not be significant and
will impact production for only a few days. These turnarounds are
designed to take advantage of the softness in natural gas prices
prior to the winter heating season. Exploitation and Development
Operational highlights during the third quarter reflect our
continued active exploitation and optimization program. We
continued to target high quality opportunities, high graded from
our growing inventory list of prospects. Specific program
highlights include: - The completion of our first ever operated
multi-lateral horizontal Mannville CBM well in Corbett. This well
validates a 21 section exploration license in the Mannville play
and is expected to begin producing in 2008. - Canetic followed its
first quarter success in the Hoadley, Ferrybank area with an
additional four well program targeting high quality glauconite and
Ellerslie gas. This asset was acquired in the Samson deal and has
yielded results that to date have exceeded expectations. One of our
first wells, drilled in the first quarter of 2007, was brought on
stream during the third quarter and is currently producing at
approximately 1.8 mmcf/d. In addition, production tests from recent
wells are encouraging with high initial test rates from multiple
zones. We expect all wells from this program to be tied in and on
stream by year-end, following the addition of incremental
compression to handle the higher than planned rates. - Canetic
effectively brought on production two high rate oil wells in the
Leitchville area of Southwest Saskatchewan. Production is from
horizontal wells targeting the Lower Shaunavon formation and
initial production volumes are strong from this medium crude
reservoir. Following these successful tests, we have embarked on a
larger drilling program through to the end of 2007. - Canetic
drilled an eight well oil program in Southern Alberta targeting
medium crude from the Sunburst formation, six of which are
currently on stream and producing. - Canetic continued to have good
success in the Greater Queensdale area of Southeast Saskatchewan
with one horizontal well targeting the Alida formation. Initial
production from the well was approximately 300 boe per day.
Continued drilling in this region is planned, with a three well
program planned for execution in the fourth quarter. - Non-operated
highlights include participation with Centrica in Mannville CBM
wells in the Corbett area, participation with Conoco in
Homeglen-Rimbey area targeting Leduc oil, and participation with
Penn West and BP Amoco in the Pembina and Pine Creek areas
targeting prolific gas production from the Glauconite and Bluesky
formations. During the third quarter, Canetic drilled and cased 18
gross (16.7 net)operated wells while participating in 46 gross
(10.7 net) non-operated wells. Operated wells consisted of 9 gross
(8.8 net) oil wells, 8 gross (6.8 net) gas wells and 1 gross (1
net) CBM well. We are planning to drill approximately 12 to 14
operated wells over the remainder of the year, depending on well
type and depth, focused primarily in the Leitchville and Queensdale
areas of Saskatchewan. Due to the strong crude oil prices and
continued weakness in natural gas prices, Canetic will remain
focused on our large inventory of oil prospects for the remainder
of 2007 and into 2008. Areas of activity for the remainder of the
year will be in Williston Basin and Southwest Saskatchewan
targeting medium to light crude. Limited capital will be spent
developing shallower natural gas opportunities until Canetic sees
strengthening in the natural gas market. However, we expect to
continue to develop and execute on our Hoadley natural gas program
beginning in late 2007 or early 2008. Capital Expenditures Three
Months Ended Nine Months Ended September 30 September 30
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Capital Expenditures ($000s) 2007 2006 2007 2006
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Land 3,582 3,812 7,527 12,615 Geological and geophysical (38) 154
2,112 2,109 Drilling and completion 69,873 79,595 256,386 212,923
Production equipment and facilities 14,614 20,863 59,253 29,566
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Net development expenditures 88,031 104,424 325,278 257,213
StarPoint acquisition - - - 2,511,746 Acquisition of property
interests - 967,204 - 967,204 Property acquisitions 14,465 4,480
16,637 28,349 Property dispositions (6,005) - (55,768) (5,000)
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Net capital expenditures 96,491 1,076,108 286,147 3,759,512 Office
1,609 3,780 6,557 6,843 Asset retirement obligation change in
estimate 593 767 2,086 2,239 Capitalized compensation 2,785 (2,240)
8,884 4,414
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Total capital expenditures 101,479 1,078,415 303,674 3,773,008
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During the nine months ended September 30, 2007, expenditures for
development activities totalled $325.3 million as compared to
$257.2 million for the same period in 2006. A total of 188 gross
(96.6 net) wells have been drilled, including 84 gross (41.1 net)
natural gas wells and 92 gross (53.0 net) oil wells, 7 gross (1.0
net) service wells, and 5 gross (1.5 net) dry and abandoned wells.
The increase in development expenditures reflects the inventory of
locations associated with our asset base resulting from the
acquisitions made in previous years and a decision by Canetic to
become more focused on internal growth opportunities. Of the total
wells drilled to September 30, 2007, 69 gross (63.6 net) were
operated by Canetic resulting in 46 gross (43.5 net) oil wells, 22
gross (19.1 net) natural gas wells, and 1 gross (1.0 net) dry and
abandoned ("D&A") well. Canetic has also changed the profile of
its operated drilling program in 2007 over 2006, targeting deeper
more prolific horizons and consequently higher cost wells. During
the nine months ended September 30, 2007, we completed net property
dispositions totalling $55.8 million representing approximately
1,000 boe per day, primarily natural gas, in Northeast Alberta.
Proceeds from the dispositions have been utilized to fund a portion
of our 2007 capital expenditure program. COMMODITY PRICE RISK
MANAGEMENT The prices we receive for petroleum and natural gas can
fluctuate significantly due to supply and demand fundamentals which
are influenced by weather patterns, the economic environment, or
political uncertainty. Our commodity price risk management program
is designed to provide price protection on a portion of our future
production in the event of adverse commodity price movements, while
retaining the opportunity to participate in favourable price
movements. This practice is designed to allow us to generate stable
funds flow for distributions and achieve positive economic returns
on capital development and acquisition activities. Given
appropriate market conditions we may hedge up to 50 percent of our
production at any given time. For the nine months ended September
30, 2007 we have realized a gain on financial derivatives of $16.5
million compared to a loss of $12.8 million for the same period in
2006. During the third quarter 2007, we recorded a realized
financial derivative gain of $12.2 million as compared to a gain of
$0.8 million for the same period in 2006. The following commodity
commitments have been put in place for the remainder of 2007 and
beyond:
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Annual Annual Average Average Commodity Contracts Q4 2007 2008 2009
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Natural Gas
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Fixed Price Volume (Gj/d) 20,000 11,667 - Fixed Price Average
($/Gj) $ 7.51 $ 6.53 - Collars Volume (Gj/d) 86,667 22,500 - Collar
Floors ($/Gj) $ 6.92 $ 7.00 - Collar Caps ($/Gj) $ 10.74 $ 11.23 -
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Total Volume Hedged (Gj/d) 106,667 34,167 -
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Crude Oil
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CDN Denominated Fixed Price Volumes (bbl/d) 8,000 250 - CDN
Denominated Fixed Price Average ($CDN/bbl) $ 67.26 $ 72.20 - U.S.
Denominated Fixed Price Volume (bbl/d) 1,500 - - U.S. Denominated
Fixed Price Average ($US/bbl) $ 48.11 - - Collars Volume (bbl/d)
6,000 12,000 - Collar Floors ($US/bbl) $ 58.00 $ 64.17 - Collar
Caps ($US/bbl) $ 80.76 $ 81.49 -
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Total Volume Hedged (bbl/d) 15,500 12,250 -
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CANADIAN TAX LEGISLATION AFFECTING INCOME TRUSTS Under the SIFT
Rules, certain of our future distributions that would have
otherwise been deductible by the Trust for tax purposes will be
subject to a special tax at a rate of 31.5 percent (the
"Distribution Tax"). As expected, the Distribution Tax will not
apply to the Trust until January 1, 2011. Currently, the Trust has
approximately $1.7 billion of tax pools that may be used to offset
future taxes. In the period leading to 2011, our objective will be
to preserve and maximize tax pools that will be available to reduce
or defer the incidence of cash taxes in 2011 and subsequent years.
Given our current tax pool position and our expectations for growth
of these pools leading to 2011, we currently anticipate our
effective tax rate will be significantly less than the 31.5 percent
statutory rate in 2011 and subsequent years. Estimated Income Tax
Pools ($000s) September 30, 2007
-------------------------------------------------------------------------
Undepreciated capital costs 561,600 Canadian oil and gas property
expense 505,736 Canadian exploration expense 23,390 Canadian
development expense 349,832 Non-capital losses 270,960 Other 38,016
-------------------------------------------------------------------------
Total estimated income tax pools 1,749,534
-------------------------------------------------------------------------
Please refer to the section of Canetic's Management's Discussion
and Analysis ("MD&A"), dated September 30, 2007, entitled
"Income Taxes" for a more complete discussion of the potential
impacts and changes anticipated to result from implementation of
the SIFT Rules and related Distribution Tax. OUTLOOK Looking
forward, we are very excited about the opportunity presented by our
announced strategic combination with Penn West. Through this
combination we will have created what we believe to be Canada's
flagship energy trust and a world-class platform to compete in
Canadian and global energy markets. The combination will form the
largest conventional oil and natural gas trust in North America and
the dominant independent light oil producer in the Western Canadian
Sedimentary Basin with anticipated production in 2008 of over
200,000 boe per day and conventional proven plus probable reserves
in excess of 800 million boe. The increased size of the combined
entity will facilitate the future development of its extensive
inventory of conventional and unconventional opportunities
including the multi-billion barrel (discovered heavy oil resources
in place) Peace River Oil Sands Project, coalbed methane, shale gas
and enhanced oil recovery from some of Canada's largest legacy
light oil pools. We anticipate that the larger size of the combined
trust will not only increase the opportunity base for future growth
but will also enhance the liquidity of its units on both the
Toronto and New York stock exchanges, increase its weighting in
major indices, including the S&P/TSX 60 Index, and lead to
greater attention from both equity and income investors. We also
expect that the increased liquidity and enhanced financial strength
of the combined trust will enable meaningful expansion both
domestically and outside Canada as we look to position the trust
for 2011 and beyond. At closing the combined trust will have tax
pools in excess of $5.5 billion and safe harbour capacity for the
issuance of new units under the undue expansion rules of
approximately $8.7 billion in 2008 and approximately $15 billion in
total. We believe that the combined trust will have the size and
scale needed to develop and grow in today's dynamic market. The
combination brings together two organizations with complementary
strategies, asset bases and management teams which should translate
into a strong shared future. We believe the combined trust will be
greater than the sum of its parts and look forward to unlocking its
potential and delivering upon the value proposition it represents
for our unitholders. We encourage our unitholders to read all
information pertaining to the strategic business combination (press
releases, presentations and information circular). These items and
additional information as it arises will be posted to our website
at http://www.canetictrust.com/. If you have any questions
regarding released information please do not hesitate to contact
our investor relations department at 1-877-539-6300. (signed)
(signed) Jack C. Lee J. Paul Charron Chairman President & Chief
Executive Officer November 8, 2007 Canetic's complete third quarter
2007 unaudited Financial Statements and Notes and Management's
Discussion and Analysis ("MD&A") 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.sec.gov/. All
references are to Canadian dollars unless otherwise indicated.
Natural gas volumes recorded in thousand cubic feet ("mcf") or
million cubic feet ("mmcf") are converted to barrels of oil
equivalent ("boe") using the ratio of six (6) thousand cubic feet
to one (1) barrel of oil ("bbl"). BOEs may be misleading,
particularly if used in isolation. A BOE conversion ratio of six
(6) mcf: one (1) bbl is based on an energy equivalent conversion
method primarily applicable at the burner tip and does not
represent a value equivalent at the wellhead. ADVISORY Certain
statements contained in this news release constitute
forward-looking statements or information (collectively
"forward-looking statements") within the meaning of applicable
securities law. These statements relate to future events or future
performances. All statements other than statements of historical
fact may be forward-looking statements. Statements relating to
"reserves" or "resources" are deemed to be forward-looking
statements as they involve the implied assessment, based on certain
estimates and assumptions, that the reserves and resources
described can be profitably produced in the future. The use of any
of the words "anticipate", "continue", "estimate", "expect", "may",
"will", "project", "could", "should", "believe", "intend",
"propose", "budget", and similar expressions are intended to
identify forward-looking statements. These statements involve known
and unknown risks, uncertainties and other factors that may cause
actual results or events to differ materially from those
anticipated in such forward-looking statements. We believe the
expectations reflected in the forward-looking statements are
reasonable, but no assurance can be given that these expectations
will prove to be correct and such forward-looking statements are
not guarantees of future performance and should not be unduly
relied upon. These statements speak only as of the date of this
news release. In particular, this news release contains or
references documents containing forward-looking statements
pertaining to the following: business strategies; production
volumes; reserves volumes; drilling plans; expected outages and
impact thereof; operating and other costs and expenses; commodity
prices; future cash distribution levels and taxability; payout
ratios; capital spending including timing, allocation and amounts
of capital expenditures and the sources of funding thereof; sources
of funding operations and distributions and the sufficiency
thereof; estimates of funds flow from operations; royalty rates;
interest rates; asset retirement obligations; hedging and other
risk management programs; debt levels, future tax treatment of
income trusts such as the Trust and unitholders; the acquisition of
Titan and strategic combination with Penn West and the benfits to
be derived there from and timing thereof; income tax pools, and
liquidity and financial capacity. The forward-looking statements
contained in this news release and referenced documents are based
on a number of expectations and assumptions that may prove to be
incorrect. In addition to other assumptions identified in this news
release and referenced documents, assumptions have been made
regarding, among other things: that the Trust will continue to
conduct its operations in a manner consistent with past operations;
the continuance of existing (and in certain circumstances,
proposed) tax and royalty regimes; the general continuance of
current industry conditions; the accuracy of the estimates of the
Trust's reserves volumes; the ability of Canetic to obtain
equipment, services and supplies in a timely manner to carry out
our activities; the ability of Canetic to market oil and natural
gas successfully; the timely receipt of required regulatory and
other approvals; the ability of Canetic to obtain financing on
acceptable terms; currency, exchange and interest rates; future oil
and gas prices; the failure of Canetic to obtain the required
approvals for mergers and acquisitions and future cost assumptions.
No assurance can be given that these factors, expectations and
assumptions will prove to be correct. The actual results could
differ materially from those anticipated in these forward-looking
statements as a result of the risk factors set forth below and
elsewhere in this news release and referenced documents: volatility
in market prices for oil and natural gas; risks and liabilities
inherent in oil and natural gas including operations, exploration,
development, exploitation, production, marketing and transportation
risks; uncertainties associated with estimating oil and natural gas
reserves; competition for, among other things, capital,
acquisitions of reserves, undeveloped lands, and skilled personnel;
incorrect assessments of the value of acquisitions; geological,
technical, drilling and processing problems; risks and
uncertainties involving geology of oil and gas deposits;
unanticipated operating results or production declines;
fluctuations in foreign exchange, currency or interest rates, and
stock market volatility; general economic conditions; changes in
laws and regulations including but not limited to those pertaining
to income tax, environmental and regulatory matters; changes in
royalty rates including the implementation of "The New Royalty
Framework" in Alberta discussed above; failure to realize the
anticipated benefits of acquisitions; health, safety and
environmental risks; and the other factors described in Canetic's
public filings from time to time (including under "Risk Factors" in
our Annual Information Form) available in Canada at
http://www.sedar.com/ and in the United States at
http://www.sec.gov/. Readers are cautioned that this list of risk
factors should not be construed as exhaustive. The forward-looking
statements contained in this news release and referenced documents
are expressly qualified by the following cautionary statement:
Canetic undertakes no obligation to publicly update or revise any
forward-looking statements except as expressly required by
applicable securities law. NON-GAAP MEASURES Throughout this news
release certain supplemental financial measures that are not
specifically determined in accordance with GAAP are used to assist
in analyzing the operations of the Trust. In addition to the
primary measures of net earnings (loss) and net earnings (loss) per
unit and cash flows from operating activities determined in
accordance with GAAP, we believe that certain measures not
determined in accordance with GAAP assist the reader in assessing
performance and understanding the Trusts results. These non-GAAP
measures as presented do not have any standardized meaning
prescribed by GAAP and therefore may not be comparable with
calculations of similar measures for other companies or trusts.
These measures should not be considered alternatives to net
earnings (loss) and net earnings (loss) per unit or cash flows from
operating activities as calculated in accordance with GAAP. - Funds
flow from operations - defined as net earnings (loss) plus non-cash
items before deducting changes in non-cash working capital and
asset retirement costs incurred. We use this measure to analyze
operating performance and leverage. This measure is an indicator of
the Trust's ability to generate funds flow in order to fund
distributions, working capital, principal debt repayments and
capital expenditures. Readers should refer to the "Funds Flow From
Operations" section of Canetic's MD&A for a reconciliation of
funds flow from operations to net earnings (loss). - Net debt -
defined as long-term debt and working capital excluding financial
derivatives. This measure is used to analyze liquidity and capital
resources in order to meet the Trusts' financing needs to fund
capital expenditures, acquisitions and short term funding needs.
Readers should refer to the "Liquidity and Capital Resources"
section of Canetic's MD&A for a reconciliation of net debt. -
Operating and cash netbacks - defined as revenue and expense items
divided by production per boe per day. This measure is used
throughout the Oil and Gas industry to analyze margin and cash flow
on each boe of production. Readers should refer to the "Netbacks"
section of Canetic's MD&A for the calculation of operating and
cash netbacks. - Total capitalization - defined as net debt
including convertible debentures plus unitholders' equity. Similar
to net debt, this measure is an indictor of the Trust's ability to
analyze liquidity and capital resources in order to meet the
Trust's financing needs to fund capital expenditures, acquisitions
and short term funding needs. This measure is an indicator of
overall Trust leverage. Total capitalization is not intended to
represent the total funds from equity and debt received by the
Trust. Readers should refer to the "Liquidity and Capital
Resources" section of Canetic's MD&A for a reconciliation of
total capitalization. ADDITIONAL INFORMATION Additional information
regarding the Trust and its business operations, including the
Trust's Annual Information Form for the year ended December 31,
2006, is available on the Trust's SEDAR company profile at
http://www.sedar.com/ or the EDGAR company profile at
http://www.sec.gov/. Canetic is one of Canada's largest oil and gas
royalty trusts. Canetic trust units and debentures are listed on
the Toronto Stock Exchange under the symbols CNE.UN, CNE.DB.A,
CNE.DB.B, CNE.DB.C, CNE.DB.D, and CNE.DB.E and the trust units are
listed on the New York Stock Exchange under the symbol CNE.
CONSOLIDATED BALANCE SHEETS As At As At September 30, December 31,
($CDN thousands) unaudited 2007 2006
-------------------------------------------------------------------------
ASSETS Current Assets Accounts receivable $ 228,946 $ 261,498
Prepaid expenses and deposits 33,694 34,647 Financial derivative
asset (Note 11) 23,641 -
-------------------------------------------------------------------------
286,281 296,145 Property, plant and equipment, net of amortization
(Note 5) 4,370,061 4,597,654 Goodwill (Note 3) 922,024 922,024
Deferred financing charges, net of amortization (Note 2) - 8,996
Financial derivative asset (Note 11) - 6,157
-------------------------------------------------------------------------
Total assets $ 5,578,366 $ 5,830,976
-------------------------------------------------------------------------
LIABILITIES AND UNITHOLDERS' EQUITY Current Liabilities Accounts
payable and accrued liabilities $ 230,636 $ 260,206 Income taxes
payable 11,632 10,979 Distributions payable 43,720 51,933
Convertible debentures (Note 6) 6,863 1,697 Financial derivative
liability (Note 11) 25,204 1,124
-------------------------------------------------------------------------
318,055 325,939 Bank debt 1,374,002 1,289,678 Convertible
debentures, net of deferred transaction costs (Note 6) 245,128
258,959 Other long-term liabilities (Note 9) 8,040 7,272 Financial
derivative liability (Note 11) 1,742 - Future income taxes (Note
14) 549,296 250,339 Asset retirement obligations (Note 7) 194,410
191,874
-------------------------------------------------------------------------
2,690,673 2,324,061 Commitments and guarantees (Note 13)
UNITHOLDERS' EQUITY Capital (Note 8) 4,287,538 4,224,470
Convertible debentures (Note 6) 6,584 6,584 Deficit (Note 10)
(1,406,429) (724,139)
-------------------------------------------------------------------------
2,887,693 3,506,915
-------------------------------------------------------------------------
Total liabilities and unitholders' equity $ 5,578,366 $ 5,830,976
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to consolidated financial statements.
CONSOLIDATED STATEMENTS OF EARNINGS (LOSS), COMPREHENSIVE INCOME
(LOSS) AND DEFICIT Three Months Ended Nine Months Ended September
30 September 30
-------------------------------------------------------------------------
($CDN thousands except per unit amounts) unaudited 2007 2006 2007
2006
-------------------------------------------------------------------------
REVENUE Petroleum and natural gas sales $ 346,092 $ 368,502 $
1,084,686 $ 1,060,053 Royalty expense (60,499) (62,432) (194,788)
(194,651)
-------------------------------------------------------------------------
285,593 306,070 889,898 865,402
-------------------------------------------------------------------------
EXPENSES Operating 72,401 66,713 215,004 178,226 Transportation
5,909 4,980 17,816 13,716 General and administrative 12,891 9,628
41,396 28,163 Interest on bank debt 18,340 13,908 50,053 34,197
Interest on convertible debentures 4,515 1,908 13,936 4,024
Depletion, depreciation and amortization 179,043 168,639 531,267
469,129 Accretion of asset retirement obligations (Note 7) 3,870
2,851 11,609 7,759 (Gain) loss on financial derivatives (Note 11)
(2,347) (73,297) (8,115) (66,928)
-------------------------------------------------------------------------
294,622 195,330 872,966 687,848
-------------------------------------------------------------------------
Earnings before taxes (9,029) 110,740 16,932 177,554 Current income
taxes (recovery) 596 2,540 3,043 2,268 Capital taxes 3,276 5,113
7,903 9,167 Future income tax expense (recovery) (Note 14) (28,599)
424 298,956 (78,614)
-------------------------------------------------------------------------
(24,727) 8,077 309,902 (67,179)
-------------------------------------------------------------------------
NET (LOSS) EARNINGS AND COMPREHENSIVE (LOSS) INCOME 15,698 102,663
(292,970) 244,733 Deficit, beginning of period (1,291,621)
(499,843) (724,139) (363,712) Distributions declared (130,505)
(149,918) (389,320) (428,119)
-------------------------------------------------------------------------
Deficit, end of period $(1,406,429) $ (547,098) $(1,406,429) $
(547,098)
-------------------------------------------------------------------------
Net (loss) earnings per unit (Note 12) Basic $ 0.07 $ 0.49 $ (1.29)
$ 1.23 Diluted $ 0.07 $ 0.48 $ (1.29) $ 1.21 Weighted average units
outstanding (Note 12) Basic 228,328 210,226 227,389 199,640 Diluted
231,002 217,337 227,389 204,415
-------------------------------------------------------------------------
See accompanying notes to consolidated financial statements.
CONSOLIDATED STATEMENTS OF CASH FLOWS Three Months Ended Nine
Months Ended September 30 September 30
-------------------------------------------------------------------------
($CDN thousands) unaudited 2007 2006 2007 2006
-------------------------------------------------------------------------
OPERATING ACTIVITIES Net (loss) earnings $ 15,698 $ 102,663 $
(292,970) $ 244,733 Adjustments for: Unit-based compensation 1,606
(1,856) 6,048 16,814 Depletion, depreciation and amortization
179,043 168,639 531,267 469,129 Accretion of asset retirement
obligations 3,870 2,851 11,609 7,759 Unrealized (gain) loss on
financial derivatives 9,827 (72,453) 8,342 (79,759) Future income
tax expense (recovery) (28,599) 424 298,956 (78,614) Accretion of
deferred transaction costs 159 - 763 - Asset retirement costs
incurred (4,096) (4,639) (11,160) (10,563) Changes in non-cash
operating working capital 4,654 (56,985) 21,128 (83,676)
-------------------------------------------------------------------------
182,462 138,644 573,983 485,823
-------------------------------------------------------------------------
FINANCING ACTIVITIES Proceeds from (repayment of) bank debt 31,264
329,224 84,324 479,747 Proceeds from issuance of units, net of
issue costs 30,087 453,016 51,466 469,366 Proceeds from issuance of
convertible debentures, net of issue costs - 220,800 - 220,800
Distributions to unitholders (130,017) (144,859) (397,534)
(416,974)
-------------------------------------------------------------------------
(68,666) 858,181 (261,744) 752,939
-------------------------------------------------------------------------
INVESTING ACTIVITIES Acquisition of petroleum and natural gas
properties (14,465) (4,480) (16,637) (28,349) Disposition of
petroleum and natural gas properties 6,005 - 55,768 5,000 Corporate
acquisitions, net of cash - (897,458) - (933,458) Capital
expenditures (105,036) (94,887) (351,370) (281,955)
-------------------------------------------------------------------------
(113,496) (996,825) (312,239) (1,238,762)
-------------------------------------------------------------------------
Cash beginning and end of period $ - $ - $ - $ -
-------------------------------------------------------------------------
The Trust paid the following cash amounts: Interest paid $ 20,040 $
14,986 $ 65,058 $ 41,881 Income and capital taxes paid $ 1,022 $
4,413 $ 9,779 $ 14,888
-------------------------------------------------------------------------
See accompanying notes to consolidated financial statements.
DATASOURCE: Canetic Resources Trust CONTACT: or to receive a
complete copy of Canetic's third quarter operating and financial
results, including the MD&A and Financial Statements free of
charge, please visit our website at http://www.canetictrust.com/ or
contact Canetic investor relations by email at: or toll free
telephone at 1-877-539-6300
Copyright