Attention Business/Financial Editors:
Penn West announces fourth quarter and year end results
CALGARY, Feb. 21 /CNW/ - PENN WEST ENERGY TRUST (TSX - PWT.UN; NYSE -
PWE) is pleased to announce its results for the fourth quarter and year ended
December 31, 2007
------------------------------------------------------------------------
Canetic and Vault Closings
- On January 11, 2008, Penn West Energy Trust ("Penn West") closed its
acquisition of Canetic Resources Trust ("Canetic"). The total
acquisition cost was $3.6 billion, funded through the issuance of
approximately 124.3 million trust units. In addition, $1.9 billion of
debt and estimated working capital deficit including transaction
costs was assumed. The acquisition provides for the strategic
combination of Penn West and Canetic to form Canada's largest energy
trust. The combined asset portfolio includes an industry leading
ownership in Western Canada's highest quality conventional oil and
natural gas pools and also includes a number of non-conventional
growth opportunities including oil sands, coal bed methane, shale gas
and enhanced oil recovery. Because the acquisition was completed
subsequent to year end, the results of Canetic will not be included
in the operating or financial results of Penn West until the first
quarter of 2008.
- On January 10, 2008, Penn West closed its acquisition of Vault Energy
Trust ("Vault"). The total acquisition cost was approximately
$159 million, funded through the issuance of approximately
5.6 million trust units, and approximately $227 million was assumed
in debt and estimated working capital deficit including transaction
costs. The acquisition added approximately 6,200 barrels of oil
equivalent per day weighted 65 percent natural gas and 35 percent
oil, 120,000 net undeveloped acres to Penn West's already significant
land base and approximately $500 million to Penn West's tax pool
position.
Operations
- Production averaged 128,024 boe per day in the fourth quarter of 2007
compared to 125,345 boe per day in the third quarter of 2007.
Property acquisitions of approximately $90 million, producing
approximately 1,600 boe per day, closed late in 2007, thus minimally
increasing reported fourth quarter production.
- Crude oil and NGL production averaged 73,332 barrels per day and
natural gas production averaged 328 mmcf per day in the fourth
quarter of 2007.
- Penn West invested $211 million on capital development including
$20 million of net acquisitions, and drilled 43 net wells in the
fourth quarter with a success rate of 99 percent.
- Pro forma productive capacity at December 31, 2007, taking the
acquisitions that closed subsequent to year-end, was approximately
206,000 boe per day, comprised of 105,000 barrels per day of crude
oil, 540 mmcf per day of natural gas and 11,000 barrels per day of
natural gas liquids.
Financial
- Funds flow of $347 million ($1.44 per unit, basic) in the fourth
quarter of 2007 was unchanged from the third quarter of 2007.
- Net income in the fourth quarter of 2007 was $127 million ($0.53 per
unit, basic) compared to net income of $137 million ($0.57 per unit,
basic) in the third quarter of 2007.
Distributions
- Penn West's Board of Directors recently resolved to keep the Trust's
distribution level at $0.34 per unit, per month, for the next three
months based on current forecasts of commodity prices, production and
planned capital expenditures.
Long-term Project Updates
- In 2007 at our Peace River Oil Sands Project, we completed the
drilling of 29 horizontal wells and 20 stratigraphic test wells and
tied-in 11 production pads in Seal Main to Penn West owned
production facilities. Geological and engineering studies are ongoing
and include plans to drill an additional 24 stratigraphic test wells
before the end of 2008, execution and interpretation of two 3-D
seismic programs and extensive core analysis, all of which are aimed
at further delineation of the project's resources. The application of
development technology such as multi-leg horizontal wells and re-
entries utilizing various configurations are yielding promising
results in our continuing efforts to increase well productivity and
reduce the capital intensity of future phases of the play.
- At our Pembina CO(2) pilot project, monitoring and evaluation is
continuing and we drilled two vertical infill wells in the fourth
quarter of 2007 to gather additional petrophysical data. The
horizontal pilot expansion at Pembina remains targeted to be on-
stream in the first quarter of 2008. The CO(2) pilot at South Swan
Hills is currently under construction and is likewise targeted to be
on-stream in the first quarter of 2008. Penn West is a participant in
the Alberta Saline Aquifer Project along with 19 other industry
participants.
Senior Management Team
- In February 2008, the Penn West Board of Directors named Murray Nunns
as President and Chief Operating Officer and David Middleton as
Executive Vice-President of Operations and Corporate Development. Mr.
Nunns, a former director of Penn West, is a Professional Geologist
with 29 years of growth oriented oil and natural gas experience
with a history of consistent success as an exploration and
operational executive. Mr. Middleton has held a number of senior
management positions with Penn West since 1999 and will have a new,
more concentrated role including the development of Penn West's
enhanced recovery programs. Penn West also announced the resignation
of J. Paul Charron and Richard Tiede, effective February 8, 2008.
HIGHLIGHTS
Three months ended Year ended
December 31 December 31
----------------------------------------------------
% %
2007 2006 change 2007 2006 change
-------------------------------------------------------------------------
Financial
(millions, except
per unit amounts)
Gross revenues(1) $ 644.0 $ 578.5 11 $2,461.8 $2,100.9 17
Funds flow 347.2 303.3 14 1,331.5 1,176.8 13
Basic per unit 1.44 1.23 17 5.56 5.86 (5)
Diluted per unit 1.43 1.22 17 5.51 5.78 (5)
Net income 127.0 122.9 3 175.5 665.6 (74)
Basic per unit 0.53 0.44 20 0.73 3.32 (78)
Diluted per unit 0.52 0.44 18 0.73 3.27 (78)
Total expenditures,
net 210.7 159.4 32 1,140.2 577.9 97
Long-term debt at
period-end 1,943.2 1,285.0 51 1,943.2 1,285.0 51
Distributions
paid(2) $ 246.4 $ 241.3 2 $ 976.0 $ 781.8 25
Operations
Daily production
Natural gas
(mmcf/d) 328.1 354.6 (7) 329.4 312.5 5
Light oil and NGL
(bbls/d) 51,070 48,233 6 50,175 39,514 27
Conventional heavy
oil (bbls/d) 22,262 22,586 (1) 22,019 20,776 6
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Total production
(boe/d) 128,024 129,915 (1) 127,098 112,369 13
-------------------------------------------------------------------------
Average sales price
Natural gas
(per mcf) $ 6.34 $ 6.97 (9) $ 6.85 $ 6.75 1
Light oil and NGL
(per bbl) 76.99 57.43 34 68.75 65.02 6
Conventional heavy
oil (per bbl) 48.69 37.57 30 45.26 43.07 5
Netback per boe
Sales price $ 55.44 $ 46.88 18 $ 52.73 $ 49.58 6
Risk management (1.02) 1.53 (167) 0.06 1.64 (96)
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Net sales price 54.42 48.41 12 52.79 51.22 3
Royalties 9.97 9.48 5 9.72 9.46 3
Operating expenses 11.35 10.61 7 11.04 10.39 6
Transportation 0.56 0.51 10 0.52 0.60 (13)
-------------------------------------------------------------------------
Netback $ 32.54 $ 27.81 17 $ 31.51 $ 30.77 2
-------------------------------------------------------------------------
The above information includes non-GAAP measures not defined under
generally accepted accounting principles ("GAAP"), including funds flow
and netback. Funds flow is cash flow from operating activities before
changes in non-cash working capital and asset retirement expenditures.
Please refer to the calculation of funds flow table on the first page of
the Management's Discussion and Analysis for a reconciliation of cash
flow from operating activities to funds flow. Funds flow is used to
assess the ability to fund distributions and planned capital programs.
Barrels of oil equivalent (boe) are based on six mcf of natural gas
equalling one barrel of oil (6:1). This could be misleading if used in
isolation as it is based on an energy equivalency conversion method
primarily applied at the burner tip and may not represent a value
equivalency at the wellhead. Netback is a per-unit-of-production measure
of operating margin used in capital allocation decisions.
(1) Gross revenues include realized gains and losses on commodity
contracts.
(2) Includes distributions paid and reinvested in trust units under the
distribution reinvestment plan.
DRILLING PROGRAM
Three months ended Year ended
December 31 December 31
--------------------------------------------------------
2007 2006 2007 2006
--------------------------------------------------------
Gross Net Gross Net Gross Net Gross Net
-------------------------------------------------------------------------
Natural gas 19 9 34 12 114 55 181 105
Oil 43 25 50 38 180 108 193 149
Dry 1 - 3 2 8 6 17 16
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63 34 87 52 302 169 391 270
Stratigraphic and
service 12 9 - - 39 30 20 11
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Total 75 43 87 52 341 199 411 281
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Success Rate(1) 99% 96% 96% 94%
-------------------------------------------------------------------------
(1) Success rate is calculated excluding stratigraphic and service wells.
UNDEVELOPED LANDS
As at December 31
------------------------------
Penn West 2007 2006 % change
-------------------------------------------------------------------------
Gross acres (000s) 3,760 4,176 (10)
Net acres (000s) 3,225 3,715 (13)
Average working interest 86% 89% (3)
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Penn West Pro Forma(1) As at December 31, 2007
-------------------------------------------------------------------------
Gross acres (000s) 5,233
Net acres (000s) 4,124
Average working interest 79%
-------------------------------------------------------------------------
(1) Pro forma data includes Penn West, Canetic, Vault and Titan
Exploration Ltd. ("Titan"), the acquisition of which was 100 percent
completed by Canetic on January 10, 2008.
FARM-OUT ACTIVITY
Three months ended Year ended
December 31 December 31
---------------------------------------
2007 2006 2007 2006
---------------------------------------
Wells drilled on farm-out lands(1) 24 57 171 169
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(1) Wells drilled on Penn West lands, including re-completions and re-
entries, by independent operators pursuant to farm-out agreements.
CORE AREA ACTIVITY
Net wells drilled
for the three Net wells drilled Undeveloped land as at
Core months ended for the year ended December 31, 2007
Area December 31, 2007 December 31, 2007 (thousands of net acres)
-------------------------------------------------------------------------
Central 18 81 1,253
Plains 21 112 964
Northern 4 6 1,008
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43 199 3,225
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TRUST UNIT DATA
Year ended December 31
------------------------------
(millions of units) 2007 2006 %change
-------------------------------------------------------------------------
Weighted average
Basic 239.4 200.8 19
Diluted 241.5 203.5 19
Outstanding as at December 31
Basic 242.7 237.1 2
Basic plus trust unit rights 257.1 248.4 4
Pro forma outstanding as
at December 31(1)
Basic 372.6 367.0 2
-------------------------------------------------------------------------
(1) Pro forma data includes Penn West and units issued to close the
Canetic and Vault acquisitions.
On January 11, 2008, Penn West issued approximately 124.3 million trust
units on the closing of the Canetic acquisition and approximately 5.6 million
units on the closing of the Vault acquisition on January 10, 2008.
TAX POOLS
Penn West Pro Forma(1)
(millions) As at December 31, 2007
-------------------------------------------------------------------------
Undepreciated capital cost (UCC) $ 1,499.0
Canadian oil and gas property expense (COGPE) 2,113.3
Canadian development expense (CDE) 714.5
Canadian exploration expense (CEE) 15.0
Non-capital losses 1,226.5
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Total $ 5,568.3
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(1) Pro forma data includes Penn West, Canetic, Vault and Titan.
RESERVE DATA
a) Working Interest Reserves using forecast prices and costs
-------------------------------------------------------
Penn West as at Natural Barrels of
December 31, 2007 Light & Natural Gas Oil
Reserve Medium Oil Heavy Oil Gas Liquids Equivalent
Estimates
Category(1)(2) (mmbbl) (mmbbl) (bcf) (mmbbl) (mmboe)
-------------------------------------------------------------------------
Proved
Developed
producing 151.4 41.9 621.1 15.2 312.0
Developed
non-producing 4.5 2.6 43.4 1.0 15.2
Undeveloped 34.5 1.0 38.5 1.1 43.1
-------------------------------------------------------------------------
Total proved 190.4 45.5 703.0 17.3 370.3
Probable 57.2 16.4 197.8 5.1 111.7
-------------------------------------------------------------------------
Total proved
plus probable 247.6 61.9 900.8 22.4 482.0
-------------------------------------------------------------------------
(1) Working interest reserves are before royalty burdens and exclude
royalty interests.
(2) Columns may not add due to rounding.
b) Net After Royalty Interest Reserves using forecast prices and costs
-------------------------------------------------------
Penn West as at Natural Barrels of
December 31, 2007 Light & Natural Gas Oil
Reserve Medium Oil Heavy Oil Gas Liquids Equivalent
Estimates
Category(1)(2) (mmbbl) (mmbbl) (bcf) (mmbbl) (mmboe)
-------------------------------------------------------------------------
Proved
Developed
producing 137.8 37.9 510.5 10.6 271.3
Developed
non-producing 4.2 2.2 35.0 0.7 12.9
Undeveloped 31.0 1.0 31.2 0.8 37.9
-------------------------------------------------------------------------
Total proved 173.1 41.0 576.7 12.0 322.2
Probable 51.2 14.5 162.6 3.7 96.6
-------------------------------------------------------------------------
Total proved
plus probable 224.3 55.5 739.3 15.7 418.8
-------------------------------------------------------------------------
(1) Net after royalty reserves are working interest reserves including
royalty interests and deducting royalty burdens.
(2) Columns may not add due to rounding.
According to the latest independent third-party evaluation, Penn West's
reserves continued to reflect a high concentration of proved developed
reserves. Of total proved reserves, only 12 percent were undeveloped at
December 31, 2007 and 2006. Of total proved plus probable reserves, only nine
percent were undeveloped at December 31, 2007 and 2006.
Penn West's reserves also contained a high-netback product mix. At
December�31, 2007, on a proved plus probable basis, reserves other than heavy
oil were 87 percent of total reserves on a barrel of oil equivalent basis
compared to 88 percent one year earlier.
GLJ Petroleum Consultants Ltd. evaluated Penn West's reserves for all
properties and Sproule Associates Limited evaluated Canetic's, Titan's and
Vault's reserves for all properties. The reserve estimates have been
calculated in compliance with the National Instrument 51-101 Standards of
Disclosure for Oil and Gas Activities ("NI 51-101"). Under NI 51-101, proved
reserve estimates are defined as having a high degree of certainty with a
targeted 90 percent probability in aggregate that actual reserves recovered
over time will equal or exceed proved reserve estimates. For proved plus
probable reserves under NI 51-101, the targeted probability is an equal (50
percent) likelihood that the actual reserves to be recovered will be less than
or greater than the proved plus probable reserves estimate.
Additional reserve disclosure tables, as required under NI 51-101, will
be contained in Penn West's Annual Information Form that will be filed on
SEDAR at www.sedar.com.
c) Reconciliation of Working Interest Reserves using forecast prices and
costs
Oil and Natural Gas Liquids Natural Gas
-----------------------------------------------------
Proved Proved
plus plus
Proved Probable probable Proved Probable probable
Reconciliation
Items(1) (mmbbl) (mmbbl) (mmbbl) (bcf) (bcf) (bcf)
-------------------------------------------------------------------------
December 31, 2006 252.4 70.2 322.6 757.6 203.2 960.8
Extensions 2.2 1.1 3.3 3.7 2.5 6.2
Improved recovery 5.6 4.1 9.8 13.3 1.5 14.8
Technical revisions 4.4 (1.2) 3.2 23.4 (16.6) 6.7
Discoveries 0.3 0.1 0.4 4.2 1.1 5.3
Acquisitions 13.8 4.3 18.0 36.0 13.9 50.0
Dispositions (0.8) (0.3) (1.1) (18.3) (7.8) (26.0)
Economic factors 1.4 0.4 1.8 - - -
Production (26.0) - (26.0) (117.0) - (117.0)
-------------------------------------------------------------------------
December 31, 2007 253.1 78.7 332.0 703.0 197.8 900.7
-------------------------------------------------------------------------
Barrels of Oil Equivalent
--------------------------
Proved
plus
Proved Probable probable
Reconciliation
Items(1) (mmboe) (mmboe) (mmboe)
----------------------------------------------
December 31, 2006 378.7 104.1 482.8
Extensions 2.8 1.6 4.4
Improved recovery 7.9 4.4 12.3
Technical revisions 8.1 (4.0) 4.1
Discoveries 1.0 0.3 1.3
Acquisitions 19.8 6.6 26.3
Dispositions (3.9) (1.6) (5.4)
Economic factors 1.4 0.4 1.8
Production (45.5) - (45.5)
----------------------------------------------
December 31, 2007 370.3 111.7 482.0
----------------------------------------------
(1) Columns may not add due to rounding. Gross interest reserves exclude
royalty interests.
d) Pro forma Penn West Working Interest Reserves using forecast prices
and costs
-------------------------------------------------------
Penn West
Proforma(1)
as at
December 31, 2007 Natural Barrels of
Light & Natural Gas Oil
Reserve Medium Oil Heavy Oil Gas Liquids Equivalent
Estimates
Category(2)(3) (mmbbl) (mmbbl) (bcf) (mmbbl) (mmboe)
-------------------------------------------------------------------------
Proved
Developed
producing 233.5 56.1 1,027.2 27.1 487.9
Developed
non-producing 5.3 3.0 66.3 1.4 20.8
Undeveloped 38.7 1.5 62.2 1.4 52.0
-------------------------------------------------------------------------
Total proved 277.5 60.6 1,155.7 29.9 560.6
Probable 89.7 20.6 414.6 10.2 189.7
-------------------------------------------------------------------------
Total proved
plus probable 367.2 81.2 1,570.3 40.1 750.2
-------------------------------------------------------------------------
(1) Pro forma data includes Penn West, Canetic/Titan and Vault.
(2) Working interest reserves before royalty burdens and excluding
royalty interests.
(3) Columns may not add due to rounding.
e) Net present value of future net revenue using forecast prices and
costs (millions)
Net present value of future net revenue
before income taxes (discounted @)
-----------------------------------------
Reserve Category(2) 5% 10% 15%
-------------------------------------------------------------------------
Proved
Developed producing $ 7,543 $ 5,935 $ 4,980
Developed non-producing 345 255 203
Undeveloped 947 559 357
-------------------------------------------------------------------------
Total proved $ 8,836 $ 6,749 $ 5,540
Probable 2,236 1,352 934
-------------------------------------------------------------------------
Total proved plus probable $ 11,072 $ 8,100 $ 6,474
-------------------------------------------------------------------------
Pro forma(1)
Total proved plus probable $ 17,085 $ 12,774 $ 10,342
-------------------------------------------------------------------------
(1) Pro forma data includes Penn West, Canetic/Titan and Vault.
(2) Columns may not add due to rounding.
Net present values are net of producing wellbore abandonment liabilities
and are based on the price assumptions that are contained in the following
table. It should not be assumed that the discounted estimated future net
revenues represent fair market value of the reserves.
f) Summary of pricing and inflation rate assumptions as of December 31,
2007 using forecast prices and costs
Oil
----------------------------------------------------------
Edmonton Hardisty Cromer
WTI Par Heavy Medium
Cushing, 40 degrees 12 degrees 29 degrees
Oklahoma API API API
Year ($US/bbl) ($CAD/bbl) ($CAD/bbl) ($CAD/bbl)
-------------------------------------------------------------------------
Historical
2003 31.07 43.66 26.26 37.55
2004 41.38 52.96 29.11 45.75
2005 56.58 69.11 34.07 56.62
2006 66.22 73.16 41.87 62.24
2007 72.24 77.02 44.37 66.30
Forecast
2008 90.81 89.63 54.34 77.54
2009 87.00 85.82 52.01 74.24
2010 84.33 83.13 50.38 71.91
2011 82.39 81.18 49.18 70.22
2012 82.13 80.92 49.02 69.99
2013 82.40 81.18 49.71 70.22
2014 83.23 81.99 50.74 70.92
2015 84.08 82.82 51.78 71.63
2016 84.94 83.68 52.84 72.37
2017 86.65 85.37 53.92 73.83
2018 88.38 87.08 55.00 75.31
-------------------------------------------------------------------------
Thereafter
escalating at 2% 2% 2% 2%
-------------------------------------------------------------------------
----------------------------------------------------------
Natural
gas AECO Edmonton Inflation Exchange
gas price propane rate rate
($US equals
Year ($CAD/mcf) ($CAD/bbl) (%) $1 CAD)
-------------------------------------------------------------------------
Historical
2003 6.66 32.14 2.8 0.721
2004 6.88 34.70 1.8 0.768
2005 8.58 43.04 2.2 0.825
2006 7.02 43.97 2.1 0.882
2007 6.65 46.85 2.1 0.935
Forecast
2008 6.63 55.30 0.0 1.00
2009 7.38 52.94 2.0 1.00
2010 7.65 51.25 2.0 1.00
2011 7.65 50.05 2.0 1.00
2012 7.60 49.89 2.0 1.00
2013 7.69 50.05 2.0 1.00
2014 7.88 50.53 2.0 1.00
2015 8.05 51.02 2.0 1.00
2016 8.23 51.53 2.0 1.00
2017 8.41 52.57 2.0 1.00
2018 8.58 53.62 2.0 1.00
-------------------------------------------------------------------------
Thereafter
escalating at 2% 2% 2%
-------------------------------------------------------------------------
g) Future development costs using forecast prices and costs (millions)
Proved Future Proved plus Probable
Year Development Costs Future Development Costs
-------------------------------------------------------------------------
2008 $ 199 $ 260
2009 134 186
2010 95 129
2011 72 92
2012 47 64
2013 and subsequent 182 377
-------------------------------------------------------------------------
Undiscounted total $ 729 $ 1,108
-------------------------------------------------------------------------
Discounted at 10%/yr $ 526 $ 766
-------------------------------------------------------------------------
Pro forma(1)
Undiscounted total $ 913 $ 1,434
Discounted at 10%/yr $ 687 $ 1,052
-------------------------------------------------------------------------
(1) Pro forma data includes Penn West, Canetic/Titan and Vault.
Letter to our Unitholders
-------------------------------------------------------------------------
Penn West Energy Trust ("Penn West") has, since converting to an energy
trust in May, 2005, doubled its producing asset base to create North America's
largest energy trust. Sheer size does not determine success. In order to move
forward, we need to successfully integrate the assets that we have acquired
while continuing to develop an inventory of exploration and development
projects. Looking forward, we believe that success can be built on a business
model that focuses on the following core strategy:
- Exercising financial discipline;
- Managing a significant scale of operations with high working
interests;
- Maintaining a strong and diversified balance sheet;
- Securing and maintaining a high quality, balanced asset base; and
- Developing a suite of conventional and unconventional projects
with mid to long-term economic potential.
In order to better execute our business plan with key focus on
exploration, development and enhanced recovery, we have moved to strengthen
our executive team and focus our energy on maximizing operating efficiency
while we continue to develop our strong asset base and add to our inventory of
future investment opportunities. In February 2008, Murray Nunns joined Penn
West as President and Chief Operating Officer. As a professional geologist
with a track record of success, Murray will chart Penn West's medium to
long-term strategy for developing and enhancing our asset base. In order to
maintain a sharp focus on maximizing operating efficiencies and developing our
enhanced recovery opportunities, David Middleton, as Executive Vice President,
will focus on the day to day operations of Penn West and on providing
strategic direction for the development of our enhanced oil recovery programs,
including the advancement of our initiatives to revitalize our legacy light
oil assets through new technologies including the capture and sequestration of
greenhouse gases.
In the fourth quarter of 2007, oil prices were at record highs in U.S.
dollar terms, natural gas prices remained relatively weak, the Canadian dollar
remained firm against the U.S. dollar and financial markets were highly
volatile with longer-term bond yields falling to cyclical lows.
Penn West executed a $211 million capital program in the fourth quarter
of 2007 with a total of 43 net wells drilled. Production in the fourth quarter
of 2007 was approximately 128,000 barrels of oil equivalent ("boe") per day
weighted 57 percent to oil and natural gas liquids excluding any contribution
from our previously announced Vault Energy Trust ("Vault") or Canetic
Resources Trust ("Canetic") acquisitions. Average operating netbacks continued
to be strong at $32.54 per boe compared to $27.81 per boe in the fourth
quarter of 2006, partially due to our initiatives to contain the industry-wide
increases in operating costs. Netbacks from light oil (oil in excess of 20
degrees API) and natural gas liquids reached $44.33 per boe, or 41 percent
higher than in the fourth quarter of 2006. Funds flow was $347 million ($1.44
per unit basic) in the fourth quarter of 2007, 14 percent higher than in the
same quarter of 2006. Our distribution payout ratio in the fourth quarter of
2007 was 71 percent, consistent with our targets.
Penn West invested extensively in and focused on both its conventional
and non-conventional prospects in 2007. Consistent with many capital programs
in Penn West's 15 year history, a significant portion of our 2007 capital
program was allocated to ensuring the organization is on track for future
success. We executed a $1.2 billion total capital program in 2007 including
$699 million of exploration, development and optimization activities, net
asset acquisitions of $441 million and environmental expenditures of
$51�million. We drilled a total of 199 net wells and invested $210 million
into optimization of producing fields and our production infrastructure. The
$699�million spent on exploration, development and optimization included
approximately $120 million that was focused on land, seismic, enhanced
recovery pilot projects and oil sands exploration. Including these additional
expenditures, our finding, development and acquisition costs were on-target at
approximately $25 per boe excluding the change in future development costs.
Included in 2007 net acquisitions were C1 Energy Ltd. for $21 million and
the $329 million property acquisition in April 2007 of approximately
3,000�barrels of light oil production per day, 6 million cubic feet of natural
gas production per day, 190,000 net acres of undeveloped land, and significant
production infrastructure including a natural gas plant and all-weather roads
in our Peace River Oil Sands project area.
We drilled a total of 29 horizontal and 20 stratigraphic test wells in
the Peace River Oil Sands project in 2007. During the year, a total of 11
production pads in Seal Main were tied into Penn West production facilities to
increase netbacks by eliminating trucking costs. The 2007 Peace River Oil
Sands capital program resulted in further delineation of the project's
resources and included seismic programs, core analysis and a Sproule
Associates Limited study of part of Penn West's 300,000 net acres of
undeveloped lands in the area that essentially confirmed internal resource
estimates. We conducted an intensive study of the reservoir through much of
2007 to enable significantly better horizontal well placements which resulted
in more robust initial well production rates. Our team also continued to test
a variety of new development technologies in the project area including
multi-leg horizontal wells and re-entries using a range of configurations and
the results to date are encouraging.
In 2007, Penn West continued working on its CO(2) enhanced oil recovery
projects with the medium to long-term goal of applying this technology to
pursuing significant additional resource recoveries from Penn West's
industry-leading ownership in Canada's largest legacy light oil pools. The
addition of horizontal wells to the Pembina CO(2) pilot project and the CO(2)
pilot at South Swan Hills are targeted to be on-stream in the first quarter of
2008. Penn West is a participant in the Alberta Saline Aquifer Project
("ASAP"), led by Enbridge Inc., which includes 19 other significant industry
participants. The mandate of the ASAP project will be CO(2) storage in Alberta
and over the long term will be bolstered by $500 million in Alberta and
Government of Canada funding.
On January 10, 2008, Penn West acquired Vault in return for approximately
5.6 million Penn West trust units and cash of $0.51 per Vault warrant, for a
total acquisition cost of $159 million. Vault's liabilities, including its
bank debt, convertible debentures and working capital (totalling an estimated
$227�million), were also assumed. Penn West views the Vault acquisition as
opportunistic as it added 6,200 boe per day weighted 65 percent to natural gas
including assets familiar to Penn West such as Wimborne, Bigoray, Pembina,
Crystal and Westerose. In this transaction Penn West also acquired 120,000 net
acres of land and approximately $500 million of tax pools.
On January 11, 2008, Penn West closed its acquisition of Canetic adding
production of approximately 73,000 boe per day. Just prior to the close of the
Canetic deal, Canetic completed its acquisition of 100 percent of Titan
Exploration Ltd. ("Titan"). On the close of the Canetic deal, Penn West issued
approximately 124.3 million trust units for a total acquisition cost of
$3.6�billion and assumed Canetic's liabilities including its bank debt,
convertible debentures and working capital deficit totalling an estimated
$1.9�billion. On the day prior to the close of the Canetic deal, Penn West
closed its new $4 billion, syndicated, three-year revolving bank facility, and
used the facility to retire all advances on the former Penn West, Canetic and
Vault bank facilities. Looking forward, Penn West remains well capitalized. In
addition to the new $4 billion bank credit facility, Penn West's credit
capacity also includes US$475 million of long-term U.S. private notes
(transacted in May 2007) and approximately $360 million in convertible
debentures assumed on the Vault and Canetic acquisitions. On a combined basis,
Penn West's pro forma proved plus probable reserve base at December 31, 2007
was 750 million boe, of which 561 million boe was proved. The combined pro
forma proved plus probable reserve life index was 10 years.
With the assets from Canetic, Vault and Titan layered into those of Penn
West, Penn West is now larger, stronger and more diverse to meet its
challenges in the foreseeable future. After adding Shirley McClellan as a
director in 2007, we also added Jack Lee, Robert Brawn, Gregory Rich and Daryl
Gilbert to our Board of Directors, bringing them over from Canetic's board.
Former employees of Canetic, Vault and Titan have joined Penn West adding
administrative, technical and managerial depth. The integration of the former
organizations into Penn West is well advanced due to a significant amount of
focus and effort by all staff.
Our Board of Directors recently approved a $960 million exploration and
development capital program for 2008, including the drilling of approximately
270 net wells. The 2008 budget also includes a $55 million allocation to the
Peace River Oil Sands project, $65 million to new ventures/enhanced oil
recovery, $170 million to optimization activities and $50 million to
environmental activities. The combined Penn West production base is expected
to generate 2008 production of between 195,000 and 205,000 boe per day. Using
commodity prices of US$80 per barrel of WTI oil, $6.75�per GJ of natural gas
at AECO and a par USD/CAD exchange rate, 2008 funds flow is expected to be
$2.0 billion to $2.1 billion. In addition, our Board of Directors also
recently approved the continuation of our current distribution rate of $0.34
per unit per month. This distribution level has been maintained since February
2006.
The new stronger Penn West will have greater opportunities to access the
capital markets and to be a selective consolidator in the Western Canada
Sedimentary Basin and elsewhere. Our combined asset base will enable us to add
significant unitholder value in the future and we are excited as we review our
many combined conventional and unconventional opportunities including:
- Exploiting and optimizing a conventional production base of 200,000
boe per day;
- Assessing and applying new technology aimed at increasing ultimate
recovery rates (such as CO(2) miscible flooding) to the largest
portfolio of light oil properties in the Basin;
- Applying secondary and enhanced oil recovery and new
drilling/completion techniques in the 300,000 net acre Peace River
Oil Sands project and elsewhere;
- Exploring the combined Trust's undeveloped land base of 4.1 million
net acres;
- Levering our very significant production infrastructure across the
Basin; and
- Exploring coalbed methane, tight/shale gas and international
opportunities.
On behalf of the Board of Directors, I wish to thank all staff and
management of the combined Trust for their hard work, cooperative spirit and
patience as we complete the integration of Penn West with Canetic, Vault and
Titan, and position the combined Penn West for continuing success.
(signed)
William E. Andrew
Chief Executive Officer
Calgary, Alberta
February 19, 2008
MANAGEMENT'S DISCUSSION AND ANALYSIS
For the three months and year ended December 31, 2007
-------------------------------------------------------------------------
This management's discussion and analysis ("MD&A") of financial
conditions and results of operations should be read in conjunction with the
unaudited interim consolidated financial information of Penn West Energy Trust
("Penn West", "the Trust", "We" or "Our") for the three months and year ended
December 31, 2007 and the audited consolidated financial statements and MD&A
for the year ended December 31, 2006. The date of this MD&A is February 19,
2008.
All dollar amounts contained in this MD&A are expressed in millions of
Canadian dollars unless noted otherwise.
Please refer to our disclaimer on forward-looking statements at the end
of this MD&A. The calculations of barrels of oil equivalent ("boe") are based
on a conversion ratio of six thousand cubic feet of natural gas to one barrel
of crude oil. This could be misleading if used in isolation as it is based on
an energy equivalency conversion method primarily applicable at the burner tip
and may not represent a value equivalency at the wellhead.
Measures including funds flow, funds flow per unit-basic, funds flow per
unit-diluted and netbacks included in this MD&A are not defined in generally
accepted accounting principles ("GAAP") and do not have a standardized meaning
prescribed by GAAP; accordingly, they may not be comparable to similar
measures provided by other issuers. Management utilizes funds flow and
netbacks to assess financial performance, to allocate its capital among
alternative projects and to assess its capacity to fund distributions and
future capital programs. Reconciliations of non-GAAP measures to their nearest
measure prescribed by GAAP are provided below.
Calculation of Funds Flow
Three months ended Year ended
December 31 December 31
(millions, except -------------------------------------------
per unit amounts) 2007 2006 2007 2006
-------------------------------------------------------------------------
Cash flow from operating
activities $ 311.7 $ 261.1 $ 1,241.8 $ 1,106.3
Increase in non-cash
working capital 20.7 32.9 38.2 43.6
Asset retirement
expenditures 14.8 9.3 51.5 26.9
-------------------------------------------------------------------------
Funds flow $ 347.2 $ 303.3 $ 1,331.5 $ 1,176.8
-------------------------------------------------------------------------
Basic per unit $ 1.44 $ 1.23 $ 5.56 $ 5.86
Diluted per unit $ 1.43 $ 1.22 $ 5.51 $ 5.78
-------------------------------------------------------------------------
Quarterly Financial Summary
(millions, except per unit and production amounts) (unaudited)
Penn West Energy Trust
-------------------------------------------
Dec 31 Sep 30 Jun 30 Mar 31
Three months ended 2007 2007 2007 2007
-------------------------------------------------------------------------
Gross revenues(1) $ 644.0 $ 627.1 $ 608.3 $ 582.4
Funds flow 347.2 346.8 326.2 311.3
Basic per unit 1.44 1.44 1.37 1.31
Diluted per unit 1.43 1.43 1.35 1.30
Net income (loss) 127.0 137.4 (185.2) 96.3
Basic per unit 0.53 0.57 (0.77) 0.41
Diluted per unit 0.52 0.57 (0.77) 0.40
Distributions declared 247.0 245.0 243.5 242.4
Per unit $ 1.02 $ 1.02 $ 1.02 $ 1.02
Production
Liquids (bbls/d)(2) 73,332 72,783 70,923 71,716
Natural gas (mmcf/d) 328.1 315.4 334.1 340.6
Total (boe/d) 128,024 125,345 126,599 128,447
-------------------------------------------------------------------------
Penn West Energy Trust
-------------------------------------------
Dec 31 Sep 30 Jun 30 Mar 31
Three months ended 2006 2006 2006 2006
-------------------------------------------------------------------------
Gross revenues(1) $ 578.5 $ 636.0 $ 452.5 $ 433.9
Funds flow 303.3 365.6 264.7 243.2
Basic per unit 1.23 1.55 1.59 1.49
Diluted per unit 1.22 1.53 1.56 1.47
Net income (loss) 122.9 177.8 220.5 144.4
Basic per unit 0.44 0.66 1.34 0.88
Diluted per unit 0.44 0.65 1.31 0.87
Distributions declared 241.5 240.7 167.6 162.0
Per unit $ 1.02 $ 1.02 $ 1.02 $ 0.99
Production
Liquids (bbls/d)(2) 70,819 69,215 48,599 52,226
Natural gas (mmcf/d) 354.6 359.1 267.9 266.9
Total (boe/d) 129,915 129,059 93,242 96,713
-------------------------------------------------------------------------
(1) Gross revenues include realized gains and losses on commodity
contracts.
(2) Includes crude oil and natural gas liquids.
Canetic Acquisition
On January 11, 2008, the close of the acquisition of Canetic Resources
Trust ("Canetic") was completed. Canetic unitholders received 0.515 of a Penn
West unit for each Canetic unit on a tax-deferred basis for Canadian and U.S.
tax purposes plus a one-time special distribution of $0.09�per unit under the
terms of the Combination Agreement.
Estimated total consideration (millions)
-------------------------------------------------------------------------
124.3 million Penn West trust units issued $ 3,572.5
Transaction costs 17.0
Bank debt 1,467.0
Convertible debentures 260.0
Working capital deficiency 153.0
-------------------------------------------------------------------------
Total $ 5,469.5
-------------------------------------------------------------------------
Vault Acquisition
On January 10, 2008 the close of the acquisition of Vault Energy Trust
("Vault") was completed. The acquisition was accomplished through a Plan of
Arrangement wherein Vault unitholders received 0.14 of a Penn West trust unit
for each Vault unit and all Vault exchangeable shares were exchanged for Penn
West trust units based on the exchange ratio for Vault units at the effective
date of the Plan of Arrangement.
Estimated total consideration (millions)
-------------------------------------------------------------------------
5.6 million Penn West trust units issued $ 157.9
Transaction costs 5.0
Bank debt 88.8
Convertible debentures 100.9
Working capital deficiency 33.4
-------------------------------------------------------------------------
Total $ 386.0
-------------------------------------------------------------------------
The New Alberta Royalty Framework
On October 25, 2007, the Government of Alberta (the "Government")
released its new royalty framework which is to become effective January 1,
2009. The new framework maintains or continues certain programs that are
important to Penn West:
- Conventional production from oil sands leases will maintain oil sands
administrative status which benefits our Peace River Oil Sands
project due to the reduced royalty rates;
- Enhanced Oil Recovery ("EOR") and Innovative Energy Technology
incentive programs will continue. Penn West has significant
inventories of legacy light oil interests amenable to EOR and
interests in CO(2) EOR producing and other CO(2) pilot projects; and
- Otherwise Flared Solution Gas Waiver Program will continue, which
supports our long-standing environmental operating and asset
optimization objectives.
On conventional production, the Government confirmed that its new royalty
framework will be sensitive to well productivity and commodity prices at
slightly higher thresholds than the September 18, 2007 proposals of the
Alberta Royalty Review Panel. Penn West, as the largest energy trust in North
America, has a diversity of play types across the Western Canada Sedimentary
Basin. Approximately 60 percent of our production is from Alberta Crown leases
and our historical asset strategies have favoured mature assets. We are
currently assessing the impact that the new royalty framework will have on our
conventional capital allocations for 2008 and beyond. We currently expect that
our conventional producing oil and natural gas strategies and business plans
will only be minimally affected at current commodity prices and at our current
asset mix.
In January 2008, ministers of the Government of Alberta publicly stated
that a possible re- review of the new Alberta Royalty Framework could occur,
with the objective of avoiding "unintended consequences" such as disincentives
to drill certain types of wells; however no details have been formally
announced.
Enactment of the Tax on Income Trusts
On June 12, 2007, the federal legislation (Bill C-52) implementing the
new tax on publicly traded income trusts and limited partnerships (the "SIFT
tax"), referred to as "Specified Investment Flow-Through" ("SIFT") entities
received third reading in the House of Commons and on June 22, 2007, the Bill
received Royal Assent.
For SIFTs in existence on October 31, 2006 including Penn West, the SIFT
tax will be effective in 2011 unless certain rules related to "undue
expansion" are not adhered to. Under the guidance provided, with the recent
close of Vault and Canetic and along with other pending transactions, we can
increase our equity by approximately $15 billion between now and 2011 without
prematurely triggering the SIFT tax.
Under the SIFT tax, distributions from certain types of income will not
be deductible for income tax purposes by SIFTs in 2011, and thereafter, and
any resultant trust level taxable income will be taxed at approximately the
corporate income tax rate. The SIFT rate was initially proposed at
31.5�percent; however, on October 30, 2007, the Government of Canada, in its
Mini-Budget (Bill C-28), proposed reductions to the general corporate tax
rate, thereby reducing the SIFT rate to 29.5 percent in 2011 and 28.0 percent
in 2012 and later. On December 14, 2007 Bill C-28 received royal assent,
resulting in a reduction to the SIFT tax rate as it becomes effective in 2011,
and lowering the rate at which any corporate income taxes will be paid in Penn
West's operating entities. As the Trust currently has a significant tax pool
base and expects to increase its tax pool base until 2011, it is expected that
the Trust could shelter its taxable income for a period after the effective
date of the SIFT tax. Distributions of this nature would not be currently
taxable to unitholders as they would represent a return of capital that would
continue to be an adjustment to a unitholder's adjusted cost base of trust
units. Distributions from income subject to the SIFT tax will be considered
taxable dividends to unitholders and will generally be eligible for the
dividend tax credit. As a result, the SIFT tax will not adversely affect
Canadian investors who hold Penn West units in a non-tax deferred account.
For accounting purposes, the SIFT tax charge during the second quarter of
2007 was $325.5 million reflecting the current estimate of the temporary
differences between the book and tax basis of assets and liabilities expected
to be remaining in the Trust in 2011. The majority of the temporary
differences at the Penn West Trust level resulted from the acquisition of
Petrofund Energy Trust on June 30, 2006.
Our Board of Directors and management are continuously monitoring the
impact of this tax on our business strategies. We expect future technical
interpretations and details will further clarify the legislation. At the
present time, Penn West believes some or all of the following actions will or
could result in the future due to the SIFT tax:
- If structural or other similar changes are not made, the distribution
yield net of the SIFT tax in 2011 and beyond to taxable Canadian
investors will remain approximately the same; however, the
distribution yield to tax-deferred Canadian investors (RRSPs, RRIFs,
pension plans, etc.) would fall by an estimated 29.5 percent in 2011
and 28.0 percent in 2012 and beyond. For U.S. investors, the
distribution yield net of the SIFT and withholding taxes would fall
by an estimated 25.1 percent in 2011 and 23.8 percent in 2012 and
beyond;
- A portion of Penn West's funds flow could be required for the payment
of the SIFT tax, or other forms of tax, and would not be available
for distribution or reinvestment;
- Penn West could convert to a corporate structure with yield in the
form of dividends to facilitate investing a higher proportion or all
of its funds flow in exploration and development projects. Such a
conversion could result in the reduction, or the elimination, of the
current distribution program in favour of higher capital investment
and/or a dividend payment program; and
- Penn West might determine that it is more economic to remain in the
trust structure, at least for a period of time, and shelter its
taxable income using tax pools and pay all or a portion of its
distributions on a return of capital basis, likely at a lower payout
ratio. Further, as the SIFT tax rate exceeds the corporate income tax
rate that would be applicable to Penn West, the tax strategy might
involve paying some corporate tax resulting in all or a portion of
those distributions being paid on a return of capital basis at a
lower payout ratio.
The Trust continues to review all organizational structures and
alternatives to minimize the impact of the SIFT tax on its unitholders. While
there can be no assurance that the negative effect of the tax can be minimized
or eliminated, Penn West and its advisors will continue to work diligently on
these issues.
Business Environment
The current business environment reflects high oil prices offset by weak
natural gas prices, a strong Canadian dollar relative to the U.S. dollar,
accessible yet volatile capital markets due to turmoil in debt capital markets
caused by asset-backed commercial paper and sub-prime mortgage issues and low
interest rates by historical standards, offset by significantly higher credit
spreads on corporate debt.
Continuing demand for commodities including crude oil from growing
economies such as China and India, increasing oil consumption in many of the
oil exporting countries and continuing political instability in parts of the
world resulted in oil prices remaining strong in 2007. The price of West Texas
Intermediate ("WTI"), the primary benchmark for light crude oil prices,
averaged US$72.34 per barrel in 2007, up by approximately nine percent from
2006.
Heavy oil differentials widened slightly in 2007, a result of continued
refinery upsets throughout the year. The Canadian Bow River differential to
WTI widened by eight percent from 2006.
AECO natural gas prices weakened in 2007, decreasing by five percent to
$5.94 per mcf from $6.28 per mcf in 2006. Weak natural gas prices reflected
record North American storage levels resulting from warmer than average North
American temperatures coupled with record liquified natural gas ("LNG")
imports driven by warmer than average weather in other parts of the world.
Recently, the outlook for natural gas prices has begun to improve as global
demand for natural gas has continued to outpace supply due to colder weather,
resulting in lower North American LNG deliveries and leading to more balanced
supply/demand fundamentals.
Lower natural gas prices and a strengthening of the Canadian dollar
relative to the U.S. dollar continued to partially offset the benefit of
stronger oil prices. Oil sales contracts are generally based on WTI prices
denominated in U.S. dollars; therefore the strengthening Canadian dollar
reduced Canadian dollar-denominated oil prices. The average exchange rate
increased from CAD$1.00 equals US$0.8882 in 2006 to CAD$1.00 equals US$0.9300
in 2007 and is currently approximately at parity.
Royalties came under scrutiny by the Alberta government in 2007 leading
to the announcement of the new royalty rate framework for the province with an
effective date of January 1, 2009. Other provinces have maintained current
royalty structures; however, future changes, both positive and/or negative in
nature, may occur.
Operating cost initiatives continue to be a focus of Penn West. During
2007, the industry encountered a slow-down in drilling activity primarily due
to low natural gas prices and uncertainties resulting from the Alberta royalty
review. Penn West experienced only modest increases in operating costs as a
result of these factors.
We have an experienced management team and strong technical staff who are
committed to exploiting our assets along with realizing operational
efficiencies from our economies of scale. Over the past two years, we have
completed significant acquisitions including Canetic, Petrofund and Vault, all
adding production and reserves throughout the Western Canada Sedimentary Basin
and elsewhere. We are now the largest conventional oil and natural gas trust
in North America, with a dominant position in Canada's legacy light oil pools.
These conventional opportunities combined with our unconventional resource
plays including our Peace River Oil Sands project, coal bed methane, shale gas
and enhanced oil recovery opportunities create the diversity and the
flexibility that will help us to adjust to changing economic, political and
environmental conditions.
Penn West strives to generate and preserve unitholder value by:
- Continuing the development of our high-quality assets, with a balance
between low-risk, cost efficient resource plays and further
development of our unconventional opportunities such as our Peace
River Oil Sands project and CO(2) enhanced oil recovery projects;
- Maintaining a stable distribution profile through active risk
management activities, maintaining and optimizing our production
infrastructure, further consolidating our core asset areas and
exploiting opportunities availed by our undeveloped land position;
- Pursuing strategic or accretive acquisitions both domestically and
internationally to further expand our already significant inventory
of assets; and
- Maintaining our strong financial position and balance sheet and
operating with financial discipline.
Unitholder Value Measures
Year ended December 31
--------------------------------
2007 2006 2005
-------------------------------------------------------------------------
Funds flow per unit $ 5.56 $ 5.86 $ 7.28
Distributions per unit $ 4.08 $ 4.05 $ 1.97
Dividends per unit $ - $ - $ 0.07
Ratio of year-end bank
debt to annual funds flow 1.5 1.1 0.5
-------------------------------------------------------------------------
Penn West maintained a distribution of $0.34 per unit per month
throughout 2007 and had continued that level since the rate was increased in
February 2006. Increases in the bank debt to funds flow ratio were primarily
due to property acquisitions during 2007 that led to increased debt levels.
Performance Indicators
Year ended December 31
--------------------------------
2007 2006 2005
-------------------------------------------------------------------------
Return on capital employed(1) 8.9% 12.8% 17.0%
Total assets (millions) $ 8,433 $ 8,070 $ 3,967
Return on equity(2) 3.6% 18.1% 28.3%
-------------------------------------------------------------------------
(1) Net income before financing charges divided by average total
liabilities less current assets.
(2) Net income divided by average unitholders' equity.
During 2007, pre-tax net income was affected by the $201.6 million
unrealized loss on risk management activities in 2007. Further, in the second
quarter of 2007, the enactment of the SIFT tax led to a $325.5 million non-
cash, future income tax charge during the period. During the fourth quarter of
2007, the Government of Canada announced rate reductions that led to a
$106.4�million reduction in the period. Had the SIFT tax not been enacted in
2007 or the tax rate reductions enacted, return on capital employed and return
on equity would have been 13.1 percent and 8.1 percent respectively.
RESULTS OF OPERATIONS
Production
Three months ended Year ended
December 31 December 31
-----------------------------------------------------
% %
Daily production 2007 2006 change 2007 2006 change
-------------------------------------------------------------------------
Natural gas (mmcf/d) 328.1 354.6 (7) 329.4 312.5 5
Light oil and NGL
(bbls/d) 51,070 48,233 6 50,175 39,514 27
Conventional heavy
oil (bbls/d) 22,262 22,586 (1) 22,019 20,776 6
-------------------------------------------------------------------------
Total production
(boe/d)(1) 128,024 129,915 (1) 127,098 112,369 13
-------------------------------------------------------------------------
(1) Barrels of oil equivalent (boe) are based on six mcf of natural gas
being equal to one barrel of oil (6:1)
Production in the fourth quarter of 2007 exceeded the 125,345 boe per day
produced in the third quarter of 2007 due primarily to the resumption of
production at our 100 percent owned Wildboy natural gas plant in November
2007. The plant was running at only partial capacity after a fire at the
adjoining tank farm in mid-May of 2007. We expect that our business
interruption insurance will cover the majority of the lost funds flow,
excluding the deductible portion.
We strive to maintain an approximately balanced portfolio of liquids and
natural gas production provided it is economic to do so. We believe a balance
by product helps to reduce exposure to price volatility that can affect a
single commodity. In the fourth quarter of 2007, crude oil and NGL production
averaged 73,332 barrels per day (57 percent of production) and natural gas
production averaged 328.1 mmcf per day (43 percent of production).
We drilled 43 net wells in the fourth quarter of 2007, mainly in the
Central and Plains areas, compared to 52 in the same period of 2006.
Commodity Markets
Natural Gas
North American natural gas prices remained weak in the fourth quarter of
2007, particularly compared to oil prices. Natural gas storage levels
continued to grow throughout the fall reaching record levels to offset the
increased demand due to the onset of winter. Spot natural gas prices at AECO
in the fourth quarter increased to $6.00 per mcf or approximately seven
percent over the prior quarter. Penn West's average natural gas price in the
fourth quarter of 2007 exceeded AECO spot prices due to the use of fixed
price, short term, physical natural gas contracts. Penn West's realized price
averaged $6.54�per mcf, including gains from commodity contracts.
Crude Oil
WTI oil prices strengthened in the fourth quarter of 2007, with continued
concern over supply and inventory levels coupled with ongoing geo-political
concerns. The crude oil market has been extremely volatile in recent months as
demand appeared to remain impervious to price. As the Canadian dollar
strengthened relative to the U.S. dollar, Edmonton par oil prices traded lower
relative to WTI prices through the quarter. Both heavy and sour Canadian oil
differentials to the Edmonton par light oil price widened over the third
quarter of 2007. Bow River differential to Edmonton averaged $29.50 per barrel
compared to $24.60 in the previous quarter due primarily to lower seasonal
demand and scheduled refinery turnarounds in the quarter. Penn West's average
price for liquids, including realized losses from commodity contracts, was
$65.71 per barrel.
Average Sales Prices Received
Three months ended Year ended
December 31 December 31
-----------------------------------------------------
% %
2007 2006 change 2007 2006 change
-------------------------------------------------------------------------
Natural gas
(per mcf) $ 6.34 $ 6.97 (9) $ 6.85 $ 6.75 1
Risk management
(per mcf) 0.20 0.56 (64) 0.17 0.72 (76)
-------------------------------------------------------------------------
Natural gas net
(per mcf) 6.54 7.53 (13) 7.02 7.47 (6)
-------------------------------------------------------------------------
Light oil and NGL
(per bbl) 76.99 57.43 34 68.75 65.02 6
Risk management
(per bbl) (3.87) 0.01 - (0.97) (1.00) (3)
-------------------------------------------------------------------------
Light oil and NGL
net (per bbl) 73.12 57.44 27 67.78 64.02 6
-------------------------------------------------------------------------
Conventional heavy
oil (per bbl) 48.69 37.57 30 45.26 43.07 5
-------------------------------------------------------------------------
Weighted average
(per boe) 55.44 46.88 18 52.73 49.58 6
Risk management
(per boe) (1.02) 1.53 (167) 0.06 1.64 (96)
-------------------------------------------------------------------------
Weighted average
net (per boe) $ 54.42 $ 48.41 12 $ 52.79 $ 51.22 3
-------------------------------------------------------------------------
Netbacks
Three months ended Year ended
December 31 December 31
-----------------------------------------------------
% %
2007 2006 change 2007 2006 change
-------------------------------------------------------------------------
Natural gas
Production (mmcf/day) 328.1 354.6 (7) 329.4 312.5 5
Operating netback
(per mcf):
Sales price $ 6.34 $ 6.97 (9) $ 6.85 $ 6.75 1
Risk management
(gain)(2) (0.20) (0.56) (64) (0.17) (0.72) (76)
Royalties 1.34 1.63 (18) 1.48 1.53 (3)
Operating costs 1.17 1.04 13 1.12 0.99 13
Transportation 0.21 0.18 17 0.20 0.21 (5)
-------------------------------------------------------------------------
Netback $ 3.82 $ 4.68 (18) $ 4.22 $ 4.74 (11)
-------------------------------------------------------------------------
Light oil and NGL
Production
(bbls/day) 51,070 48,233 6 50,175 39,514 27
Operating netback
(per bbl):
Sales price $ 76.99 $ 57.43 34 $ 68.75 $ 65.02 6
Risk management
loss (gain)(2) 3.87 (0.01) - 0.97 1.00 (3)
Royalties 13.24 10.55 26 11.94 10.87 10
Operating costs 15.55 15.36 1 15.29 15.80 (3)
-------------------------------------------------------------------------
Netback $ 44.33 $ 31.53 41 $ 40.55 $ 37.35 9
-------------------------------------------------------------------------
Conventional
heavy oil
Production (bbls/day) 22,262 22,586 (1) 22,019 20,776 6
Operating netback
(per bbl):
Sales price $ 48.69 $ 37.57 30 $ 45.26 $ 43.07 5
Royalties 7.18 6.46 11 6.79 7.47 (9)
Operating costs 12.32 11.88 4 12.18 11.22 9
Transportation 0.06 0.07 (14) 0.07 0.07 -
-------------------------------------------------------------------------
Netback $ 29.13 $ 19.16 52 $ 26.22 $ 24.31 8
-------------------------------------------------------------------------
Total liquids
Production
(bbls/day) 73,332 70,819 4 72,194 60,290 20
Operating netback
(per bbl):
Sales price $ 68.40 $ 51.09 34 $ 61.59 $ 57.46 7
Risk management
loss (gain)(2) 2.69 (0.01) - 0.67 0.66 2
Royalties 11.40 9.24 23 10.37 9.69 7
Operating costs 14.57 14.25 2 14.34 14.22 1
Transportation 0.02 0.02 - 0.02 0.03 (33)
-------------------------------------------------------------------------
Netback $ 39.72 $ 27.59 44 $ 36.19 $ 32.86 10
-------------------------------------------------------------------------
Combined totals
Production
(boe/day)(1) 128,024 129,915 (1) 127,098 112,369 13
Operating netback
(per boe):
Sales price $ 55.44 $ 46.88 18 $ 52.73 $ 49.58 6
Risk management
loss (gain)(2) 1.02 (1.53) (167) (0.06) (1.64) (96)
Royalties 9.97 9.48 5 9.72 9.46 3
Operating costs 11.35 10.61 7 11.04 10.39 6
Transportation 0.56 0.51 10 0.52 0.60 (13)
-------------------------------------------------------------------------
Netback $ 32.54 $ 27.81 17 $ 31.51 $ 30.77 2
-------------------------------------------------------------------------
(1) Barrels of oil equivalent (boe) are based on six mcf of natural gas
being equal to one barrel of oil (6:1).
(2) Realized component of risk management activities related to oil and
natural gas prices.
Production Revenues
Revenues from the sale of oil, NGL and natural gas consisted of the
following:
Year ended December 31
--------------------------------
(millions) 2007 2006 2005
-------------------------------------------------------------------------
Natural gas $ 856.6 $ 850.9 $ 918.2
Light oil and NGL 1,241.4 923.4 757.0
Conventional heavy oil 363.8 326.6 243.8
-------------------------------------------------------------------------
Gross revenues (1) $ 2,461.8 $ 2,100.9 $ 1,919.0
-------------------------------------------------------------------------
(1) Gross revenues include realized gains and losses on commodity
contracts.
Increases (Decreases) in Production Revenues
(millions)
-------------------------------------------------------------------------
Gross revenues - 2006 $ 2,100.9
Increase in light oil and NGL production 249.2
Increase in light oil and NGL prices
(including realized risk management) 68.9
Increase in conventional heavy oil production 19.5
Increase in conventional heavy oil prices 17.6
Increase in natural gas production 46.1
Decrease in natural gas prices
(including realized risk management) (40.4)
-------------------------------------------------------------------------
Gross revenues - 2007 $ 2,461.8
-------------------------------------------------------------------------
In the fourth quarter of 2007 gross revenues increased by 11 percent to
$644.0 million from $578.5 million in 2006. This was primarily due to a 34
percent increase in light oil and NGL sales prices to $76.99 per bbl in 2007
from $57.43 per bbl in 2006 and a 30 percent increase in conventional heavy
oil sales price to $48.69 per bbl in 2007 from $37.57 per bbl in 2006.
Royalties
Year ended December 31
--------------------------------
2007 2006 2005
-------------------------------------------------------------------------
Royalties (millions) $ 450.8 $ 388.0 $ 369.7
Average royalty rate (%) 18% 18% 19%
Per boe $ 9.72 $ 9.46 $ 10.15
-------------------------------------------------------------------------
Expenses
Year ended December 31
--------------------------------
(millions) 2007 2006 2005
-------------------------------------------------------------------------
Operating $ 512.2 $ 426.3 $ 327.4
Transportation 24.1 24.5 22.7
Financing 92.4 49.3 23.2
Unit-based compensation $ 20.5 $ 11.3 $ 77.2
-------------------------------------------------------------------------
Year ended December 31
--------------------------------
(per boe) 2007 2006 2005
-------------------------------------------------------------------------
Operating $ 11.04 $ 10.39 $ 8.99
Transportation 0.52 0.60 0.62
Financing 2.00 1.20 0.63
Unit-based compensation $ 0.44 $ 0.27 $ 2.12
-------------------------------------------------------------------------
Operating
Penn West continued all of its initiatives to limit increases to
operating cost realizations. Over the past two years, operating cost
escalation occurred industry-wide due to strong demand for skilled labour and
oilfield services, particularly drilling and oilfield service rigs. Penn
West's modest increases in operating costs per barrel of oil equivalent were
generally due to a higher proportion of liquids production in 2007 than in the
comparative 2006 periods. Currently, with the low natural gas price and the
recent Alberta royalty recommendations, we are experiencing a slow-down in
industry activity that is expected to alleviate some of the high demand for
oilfield services in the near future. The addition of the Petrofund assets
effective July 1, 2006, with higher operating costs than the Penn West assets,
also contributed to the increase.
During the fourth quarter of 2007, operating costs increased by six
percent to $135.1 million from $127.7 million in the same period of 2006, due
to industry-wide cost escalations.
A realized gain of $11.0 million (2006 - $17.3 million) on our
electricity contracts was included in operating costs for the year.
Financing
Penn West Petroleum Ltd. ("the Company") closed the placement of
US$475�million of notes on May 31, 2007. The interest rates on the notes are
fixed at 5.68 to 6.05 percent for terms of 8 to 15 years and average 5.8
percent. During September 2007, the Company entered into foreign exchange
contracts to fix the repayment (in Canadian dollars) on US$250 million at an
exchange rate of approximately one Canadian dollar at par with one U.S.
dollar. In addition, the Company has swaps on $100 million of bank debt that
fix the interest rate at approximately 4.36 percent until March 2008 and on
$100�million of bank debt that fix the interest rate at approximately
4.26�percent until November 2010. The interest rate on the balance of the
Company's long-term debt is currently based on short-term, floating interest
rate debt instruments.
In the fourth quarter of 2007, Penn West incurred $27.2 million of
financing charges compared to $17.8 million in the same period of 2006 due to
increased debt levels.
The 2007 increase in interest expense resulted from both an increase in
the average outstanding debt balance and increases in interest rates over
2006. The U.S. notes contain slightly higher fixed interest rates than the
Company was subject to under its syndicated credit facility using short-term
money market instruments. Penn West believes the long-term nature and the
fixed interest rates inherent in the notes are beneficial for a portion of its
capital structure. The increased average loan balance was principally due to
property acquisitions in 2007.
Unit-Based Compensation
Unit-based compensation expense related to Penn West's Trust Unit Rights
Incentive Plan is based on the fair value of trust unit rights issued,
determined using the Binomial Lattice option-pricing model. The fair value of
rights issued is amortized over the remaining vesting periods on a straight-
line basis. The unit-based compensation expense was $5.5 million for the three
months ended December 31, 2007, of which $1.5 million was charged to operating
expense and $4.0 million was charged to general and administrative expense
(2006 - $3.1 million, $0.8 million and $2.3 million, respectively). The amount
per boe increased in 2007 due to additional options granted in the period.
General and Administrative Expenses
Year ended December 31
--------------------------------
2007 2006 2005
-------------------------------------------------------------------------
Gross (millions) $ 83.3 $ 62.0 $ 45.0
Per boe 1.80 1.51 1.24
Net (millions) 50.8 36.0 23.1
Per boe $ 1.10 $ 0.88 $ 0.64
-------------------------------------------------------------------------
The current workplace environment continues to be highly competitive in
hiring, compensating and retaining employees and consultants. Professional
staff, particularly those with experience and strong technical skills,
continue to be in high demand, leading to increased compensation costs.
Additional regulatory compliance activities have also contributed to increased
costs.
Depletion, Depreciation and Accretion ("DD&A")
Year ended December 31
--------------------------------
(millions, except per boe amounts) 2007 2006 2005
-------------------------------------------------------------------------
Depletion of oil and natural gas assets $ 867.4 $ 635.0 $ 416.5
Accretion of asset
retirement obligation(1) 29.3 19.7 21.1
-------------------------------------------------------------------------
Total DD&A $ 896.7 $ 654.7 $ 437.6
-------------------------------------------------------------------------
DD&A expense per boe $ 19.33 $ 15.96 $ 12.01
-------------------------------------------------------------------------
(1) Represents the accretion expense on the asset retirement obligation
during the period.
DD&A expense in 2007 was higher than in 2006 due to a full year of
production from the Petrofund assets and a higher depletion rate as a result
of the Petrofund acquisition, which closed in June 30, 2006. Penn West
accounted for the merger as a purchase of Petrofund with the purchase price
allocated to the fair value of net identifiable assets acquired. The purchase
price allocation to oil and natural gas assets at fair value significantly
increased our consolidated depletion base per unit. Preliminary estimates for
2008 indicate the 2008 DD&A rate will further increase due to the Vault and
Canetic acquisitions.
Taxes
Year ended December 31
--------------------------------
(millions) 2007 2006 2005
-------------------------------------------------------------------------
Current income $ - $ - $ 54.1
Future income expense (reduction) 75.4 (106.2) (1.1)
-------------------------------------------------------------------------
$ 75.4 $ (106.2) $ 53.0
-------------------------------------------------------------------------
Temporary differences at the Trust level, or differences between book and
tax basis of the assets and liabilities, were previously not recognized under
GAAP as future income taxes because the Trust was required to distribute all
of its taxable income under the terms of its Trust Indenture. Under the SIFT
legislation, in 2011 and beyond, as distributions will no longer be tax
deductible, the Trust will not be able to make distributions to reduce its
taxable income and thus is no longer considered to be exempt from income taxes
for accounting purposes.
During the second quarter of 2007, a $325.5 million charge was recorded
due to the enactment of the SIFT tax legislation during the period. The future
income tax liability was increased to reflect the current temporary
differences expected to be remaining at the Trust level in 2011 using the then
effective SIFT tax rate of 31.5 percent. On October 30, 2007, the Government
of Canada proposed rate reductions which were enacted in Bill C-28 on
December�14, 2007 lowering the SIFT tax rate to 29.5 percent in 2011 and to
28.0 percent for 2012 and beyond and reducing future corporate income tax
rates by an additional 3.5 percent. During the fourth quarter of 2007, a
$106.4 million future income tax reduction was recorded to reflect these
substantively enacted tax rates.
Under our current structure, the operating entities make interest and
royalty payments to the Trust, which transfers taxable income to the Trust to
eliminate income subject to corporate income taxes in the operating entities.
With the new legislation, such amounts transferred to the Trust could be
taxable beginning in 2011 as distributions will no longer be deductible by the
Trust for income tax purposes. At that time, Penn West could claim on its tax
pools and pay all or a portion of its distributions on a return of capital
basis. Such distributions would not be immediately taxable to investors: they
would generally reduce the adjusted cost base of units held by investors
however such distributions would potentially be at a lower payout ratio.
The new legislation is not currently expected to directly affect our
funds flow levels and distribution policies until 2011 at the earliest.
The estimate of future income taxes is based on the current tax status of
the Trust. Future events, which could materially affect future income taxes
such as acquisitions and dispositions and modifications to the distribution
policy, are not reflected under Canadian GAAP until the events occur and the
related legal requirements have been fulfilled. As a result, future changes to
the tax legislation could lead to a material change in the recorded amount of
future income taxes.
Tax Pools
As at December 31
--------------------------------
(millions) 2007 2006 2005
-------------------------------------------------------------------------
Undepreciated capital cost (UCC) $ 826.2 $ 788.3 $ 519.0
Canadian oil and gas property
expense (COGPE) 1,308.6 1,091.0 707.6
Canadian development expense (CDE) 413.7 428.8 329.8
Non-capital losses 697.4 106.1 -
-------------------------------------------------------------------------
Total tax pools $ 3,245.9 $ 2,414.2 $ 1,556.4
-------------------------------------------------------------------------
The increase in the 2007 tax pools reflects capital spending and income
transfers to the Trust throughout the year. The tax pool figures are net of
income deferred in operating partnerships.
Foreign Exchange
In 2007, the Trust had US-dollar-denominated debt totalling $475 million
compared to nil in 2006. The Trust recorded unrealized foreign exchange gains
of $38.2 million in 2007 related to the outstanding U.S. notes. No gains were
realized on these contracts in 2007 as no amounts were settled or converted to
Canadian dollars during the year.
Funds flow and Net Income
Three months ended Year ended
December 31 December 31
-----------------------------------------------------
% %
2007 2006 change 2007 2006 change
-------------------------------------------------------------------------
Funds flow(1)
(millions) $ 347.2 $ 303.3 14 $1,331.5 $1,176.8 13
Basic per unit 1.44 1.23 17 5.56 5.86 (5)
Diluted per unit 1.43 1.22 17 5.51 5.78 (5)
Net income (millions) 127.0 122.9 3 175.5 665.6 (74)
Basic per unit 0.53 0.44 20 0.73 3.32 (78)
Diluted per unit $ 0.52 $ 0.44 18 $ 0.73 $ 3.27 (78)
-------------------------------------------------------------------------
(1) Funds flow is a non-GAAP measure. See "Calculation of Funds flow".
Funds flow realized in 2007 increased from the comparable 2006 period due
to higher production volumes resulting from the Petrofund acquisition,
partially offset by higher operating and financing costs.
In the absence of the $325.5 million non-cash charge taken in the second
quarter of 2007 to reflect the enactment of the SIFT tax and the
$106.4�million rate recovery received in the fourth quarter of 2007, net
income for 2007 would have been $394.6 million.
Year ended December 31
-----------------------------------------------------
2007 2006 2005
-----------------------------------------------------
per boe % per boe % per boe %
-------------------------------------------------------------------------
Oil and natural
gas revenues(1) $ 53.08 100.0 $ 51.22 100.0 $ 52.68 100.0
Net royalties (9.72) (18.3) (9.46) (18.4) (10.15) (19.3)
Operating expenses(2) (11.04) (20.8) (10.39) (20.3) (8.99) (17.1)
Transportation (0.52) (1.0) (0.60) (1.2) (0.62) (1.1)
-------------------------------------------------------------------------
Net operating income 31.80 59.9 30.77 60.1 32.92 62.5
General and
administrative
expenses (1.10) (2.0) (0.88) (1.7) (0.64) (1.2)
Interest (2.00) (3.8) (1.20) (2.3) (0.63) (1.2)
Realized foreign
exchange gain - - - - 2.35 4.4
Current taxes - - - - (1.48) (2.8)
-------------------------------------------------------------------------
Funds flow 28.70 54.1 28.69 56.0 32.52 61.7
Unrealized foreign
exchange gain (loss) 0.82 1.5 - - (2.48) (4.7)
Unit-based
compensation (0.44) (0.8) (0.27) (0.5) (2.12) (4.0)
Risk management
activities(3) (4.35) (8.2) 1.18 2.3 (0.09) (0.2)
Depletion,
depreciation
and accretion (19.33) (36.4) (15.96) (31.2) (12.01) (22.8)
Future income taxes (1.63) (3.0) 2.59 5.1 0.03 -
-------------------------------------------------------------------------
Net income $ 3.77 (7.2) $ 16.23 31.7 $ 15.85 30.0
-------------------------------------------------------------------------
(1) Gross revenues include realized gains and losses on commodity
contracts.
(2) Operating expenses include realized gains on electricity swaps.
(3) Risk management activities relate to the unrealized gain and losses
on derivative instruments.
Goodwill
The goodwill balance of $652.0 million resulted from the acquisition of
Petrofund in June 2006. The Trust has determined that there was no goodwill
impairment as of December 31, 2007.
Capital Expenditures
Three months ended Year ended
December 31 December 31
-------------------------------------------
(millions) 2007 2006 2007 2006
-------------------------------------------------------------------------
Property acquisitions
(dispositions), net $ 19.7 $ 10.9 $ 421.7 $ 5.6
Land acquisition and retention 0.8 0.8 30.2 19.8
Drilling and completions 96.1 86.1 367.2 317.4
Facilities and well equipping 73.0 57.9 254.1 224.6
Geological and geophysical 0.5 1.0 10.2 3.6
CO(2) pilot costs 9.8 1.1 19.8 3.7
Administrative 10.8 1.6 15.8 3.2
-------------------------------------------------------------------------
Capital expenditures 210.7 159.4 1,119.0 577.9
-------------------------------------------------------------------------
Business combination - - 21.2 3,323.3
-------------------------------------------------------------------------
Total expenditures $ 210.7 $ 159.4 $ 1,140.2 $ 3,901.2
-------------------------------------------------------------------------
We drilled 43 net wells in the fourth quarter of 2007, resulting in 25
net oil wells, nine net natural gas wells and nine stratigraphic wells with a
success rate of 99 percent. Our drilling activities were focused primarily in
the Central and Plains areas.
On June 30, 2006, we closed the acquisition of Petrofund. The fair value
of the oil and natural gas properties acquired of $3.3 billion was added to
property, plant and equipment and the remaining $0.7 billion of the purchase
price was attributed to goodwill.
The acquisition of C1 Energy Ltd ("C1") for a total cost of approximately
$21.2 million closed during the third quarter of 2007 and was accounted for as
a purchase. Also, during 2007, we completed a number of other minor property
acquisitions.
In addition to the above noted capital expenditures, for the year ended
December 31, 2007, $5.1 million was capitalized for future income taxes on
acquisitions to reflect the acquisitions with a different tax basis than the
purchase prices and $96.6 million was capitalized for additions to asset
retirement obligations to reflect the additional retirement obligations from
both capital programs and net acquisitions.
CO(2) pilot costs represent capital expenditures related to the Pembina
CO(2) pilot project, including the cost of injectants, for which no reserves
have been booked.
Business Risks
Market Risk Management
We are exposed to normal market risks inherent in the oil and natural gas
business, including commodity price risk, credit risk, interest rate risk,
foreign currency and environmental risk. From time to time, we attempt to
minimize exposure to a portion of these risks by using financial instruments
and by other means.
Commodity Price Risk
Commodity price fluctuations are among the Trust's most significant
exposures. Crude oil prices are influenced by worldwide factors such as OPEC
actions, supply and demand fundamentals, and political events. Oil prices,
North American natural gas supply and demand factors including weather,
storage levels and LNG imports, influence natural gas prices. In accordance
with policies approved by our Board of Directors, we may, from time to time,
manage these risks through the use of costless collars or other financial
instruments up to a maximum of 50 percent of forecast sales volumes, net of
royalties, for a two-year period or up to 75 percent of forecast sales
volumes, net of royalties, for a one-year period.
For a current summary of outstanding oil and natural gas contracts,
please refer to "Financial Instruments" later in this MD&A or our website at
www.pennwest.com, which includes all current contracts including those assumed
in the Canetic and Vault acquisitions which closed in January 2008.
Foreign Currency Rate Risk
Prices received for sales of crude oil are referenced to, or denominated
in, U.S. dollars, and thus realized oil prices are impacted by Canadian to
United States exchange rates. When we consider it appropriate, we may use
financial instruments to fix or collar future exchange rates.
In September 2007, we entered into foreign exchange contracts to fix the
foreign exchange rate on the future repayment of US$250 million of U.S. dollar
denominated private notes at an exchange rate of approximately one Canadian
dollar equalling one U.S. dollar. At December 31, 2007, we had U.S. dollar
denominated debt with a face value of US$225 million outstanding on which the
repayment of principal amount in Canadian dollars is not fixed.
Credit Risk
Credit risk is the risk of loss if purchasers or counterparties do not
fulfill their contractual obligations. All of our receivables are with
customers in the oil and natural gas industry and are subject to normal
industry credit risk. In order to limit the risk of non-performance of
counterparties to derivative instruments, we contract only with organizations
with high credit ratings or by obtaining security in certain circumstances.
Interest Rate Risk
We currently maintain a portion of our debt in floating-rate bank
facilities, which results in exposure to fluctuations in short-term interest
rates that have for a number of years been lower than longer-term rates. From
time to time, we may increase the certainty of our future interest rates by
entering fixed interest rate debt instruments or by using financial
instruments to swap floating interest rates for fixed rates or to collar
interest rates.
In April 2006, we entered into interest rate swaps for two years at
4.36�percent on $100 million of bank debt and in November 2007 we entered into
interest rate swaps for three years at 4.26 percent on $100 million of bank
debt, both of which fixed the interest rates for the stated period of time. We
closed the placement of notes totalling US$475 million on May 31, 2007 that
bear fixed interest rates at an average rate of 5.8 percent for an average
term of 10.1�years.
Liquidity and Capital Resources
Capitalization
Year ended December 31
-----------------------------------------------------
2007 2006 2005
-------------------------------------------------------------------------
(millions) % % %
-------------------------------------------------------------------------
Trust units issued,
at market $ 6,270 74.0 $ 8,435 86.0 $ 6,203 90.5
Bank loans and notes 1,943 22.9 1,285 13.1 542 7.9
Working capital
deficiency(1) 266 3.1 86 0.9 127 1.6
-------------------------------------------------------------------------
Total enterprise
value $ 8,479 100.0 $ 9,806 100.0 $ 6,872 100.0
-------------------------------------------------------------------------
(1) Current assets minus current liabilities.
During 2007 we paid total distributions, including those funded by the
distribution reinvestment plan, of $976.0 million, compared to distributions
of $781.8 million in 2006. This increase was due to the increase in the
distribution rate from $0.31 per unit, per month in February�2006, to the rate
since that time of $0.34 per unit, per month, and the 70.7�million additional
units issued as consideration for Petrofund in June�2006.
Long-term debt at December 31, 2007 was $1,943.2 million compared to
$1,285.0�million at December 31, 2006. In January 2008, our wholly owned
subsidiary, Penn West Petroleum Ltd., amended its unsecured, revolving
syndicated credit facility to an aggregate borrowing limit of $4.0 billion
expiring on January 11, 2011, to enable the cancellation of the credit
facilities of Canetic and Vault. The facility is made up of two revolving
tranches; tranche one of the facility is $3.25�billion and extendible, and
tranche two is $750 million and non-extendible. Stamping fees range from
55-110 basis points and standby fees range from 11.0-22.5 basis points
depending on our ratio of bank debt to income before interest, taxes and
depreciation and depletion ("EBITDA"). The syndicated facility expiry date on
both tranches is January 11, 2011.
On May 31, 2007, the Company closed an offering of notes issued on a
private placement basis in the United States, with an aggregate principal
amount of US$475 million. The Company used the proceeds of the notes to repay
a portion of its outstanding bank debt under its credit facilities. The notes
mature in 8 to 15 years and bear interest at rates between 5.68 and 6.05
percent.
On December 31, 2007, the Company was in compliance with all of the
financial covenants under its syndicated credit facility that closed on
January 10, 2008. The financial covenants under the syndicated credit
facility, which include the unaudited pro forma Canetic, Vault and Titan
Exploration Ltd. ("Titan") historical results, are as follows:
- Consolidated senior debt to EBITDA shall be less than 3:1 except in
certain circumstances and shall not exceed 3.5:1;
- Consolidated total debt to EBITDA shall be less than 4:1; and
- Consolidated senior debt to total trust capitalization shall not
exceed 50 percent except in certain circumstances and shall not
exceed 55 percent.
At December 31, 2007, the pro forma consolidated senior and total debt to
EBITDA ratios were 1.5:1 and 1.6:1 respectively, and the consolidated senior
debt to capitalization ratio was 29.5 percent.
On December 31, 2007, the Company was in compliance with the financial
covenant pursuant to the notes, which is that consolidated total debt to
consolidated total capitalization is not to exceed 55 percent except in
certain circumstances where it is not to exceed 60 percent.
Under the terms of its current trust indenture, the Trust is required to
make distributions to unitholders in amounts at least equal to its taxable
income. Distributions may be monthly or special and in cash or in trust units
at the discretion of our Board of Directors. To the extent that additional
cash distributions are paid and capital programs are not adjusted, debt levels
may increase. In the event that a special distribution in the form of trust
units is declared, the terms of the current trust indenture require that the
outstanding units be consolidated immediately subsequent to the distribution.
The number of outstanding trust units would remain at the number outstanding
immediately prior to the unit distribution, plus those sold to fund the
payment of withholding taxes, and an amount equal to the distribution would be
allocated to the unitholders as a taxable distribution. Penn West has never
declared such a distribution and, at the current time, it forecasts that such
a special distribution will not be required in 2008.
Due to the extent of our environmental programs, we believe no benefit
would arise from the initiation of a reclamation fund. We believe our program
will be sufficient to meet or exceed existing environmental regulations and
best industry practices. In the event of significant changes to the
environmental regulations or the cost of environmental activities, a higher
portion of Funds flow would be required to fund our environmental
expenditures.
Standardized Distributable Cash
Prior to the recent guidance from accounting and regulatory standard
setters on the disclosure of distributable cash, Penn West's disclosures
regarding distributable cash to its investors focused on statistics including
a reconciliation of cash flow from operating activities to distributions
declared and distributions declared as a percentage of cash flow from
operating activities and net income. The Canadian Institute of Chartered
Accountants ("CICA") issued the Interpretive Release "Standardized
Distributable Cash in Income Trusts and Other Flow-Through Entities" in July
2007, which provided further guidance. Penn West also early-adopted the
interpretive release. In the new guidance, sustainability concepts are
discussed and standardized distributable cash is defined as cash flow from
operating activities less adjustments for productive capacity maintenance,
long-term unfunded contractual obligations and the effect of any foreseeable
financing matters, related to debt covenants, which could impair an entity's
ability to pay distributions or maintain productive capacity.
Three months ended Year ended
December 31 December 31
-------------------------------------------
(millions except per unit
amounts and percentages) 2007 2006 2007 2006
-------------------------------------------------------------------------
Cash flow from operating
activities $ 311.7 $ 261.1 $ 1,241.8 $ 1,106.3
Productive capacity
maintenance(1) (191.0) (148.5) (697.3) (572.3)
-------------------------------------------------------------------------
Standardized distributable
cash 120.7 112.6 544.5 534.0
Proceeds from the issue
of trust units(2) 50.2 31.3 163.1 118.6
Debt and working
capital changes 76.1 97.6 270.3 159.2
-------------------------------------------------------------------------
Cash distributions declared $ 247.0 $ 241.5 $ 977.9 $ 811.8
Accumulated cash
distributions, beginning 1,864.2 891.8 1,133.3 321.5
-------------------------------------------------------------------------
Accumulated cash
distributions, ending $ 2,111.2 $ 1,133.3 $ 2,111.2 $ 1,133.3
-------------------------------------------------------------------------
Standardized distributable
cash per unit, basic $ 0.50 $ 0.48 $ 2.27 $ 2.66
Standardized distributable
cash per unit, diluted $ 0.50 $ 0.47 $ 2.25 $ 2.62
Standardized distributable
cash payout ratio(3) 2.05 2.14 1.80 1.52
-------------------------------------------------------------------------
Distributions declared
per unit $ 1.02 $ 1.02 $ 4.08 $ 4.05
Net income as a percentage
of cash distributions
declared 51% 51% 18% 82%
Cash flows from operating
activities as a percentage
of cash distributions
declared 126% 108% 127% 136%
-------------------------------------------------------------------------
(1) Please refer to our discussion of productive capacity maintenance
below.
(2) Consists of proceeds from the Distribution Reinvestment and Optional
Purchase Plan, the Trust Unit Rights Incentive Plan and the Trust
Unit Savings Plan.
(3) Represents cash distributions declared divided by standardized
distributable cash.
We strive to fund both distributions and maintenance capital programs
primarily from funds flow. We initially budget our capital programs at
approximately 40-50 percent of annual funds flow. We believe that proceeds
from the Distribution Reinvestment and Optional Purchase Plan should be used
to fund capital expenditures of a longer-term nature. Over the medium term,
additional borrowings and equity issues may be required from time to time to
fund a portion of our distributions or maintain or increase our productive
capacity. On a longer-term basis, adjustments to the level of distributions
and/or capital expenditures to maintain or increase our productive capacity
may be required based on forecast levels of funds flow, capital efficiency and
debt levels.
Productive capacity maintenance is the amount of capital funds required
in a period for an enterprise to maintain its future cash flow from operating
activities at a constant level. As commodity prices can be volatile and short-
term variations in production levels are often experienced in our industry, we
define our productive capacity as production on a barrel of oil equivalent
basis. A quantifiable measure for these short-term variations is not
objectively determinable or verifiable due to various factors including the
inability to distinguish natural production declines from the effect of
production additions resulting from capital and optimization programs, and the
effect of temporary production interruptions. As a result, the adjustment for
productive capacity maintenance in our calculation of standardized
distributable cash is our capital expenditures during the period excluding the
cost of any asset acquisitions or proceeds of any asset dispositions. We
believe that our current capital programs, based on 40-50 percent of forecast
annual funds flow and our current view of our assets and opportunities,
including particularly our oil sands project and our proposed enhanced oil
recovery projects, and our outlook for commodity prices and industry
conditions, should be sufficient to maintain our productive capacity in the
medium term. We set our hurdle rates for evaluating potential development and
optimization projects according to these parameters. Due to the risks inherent
in the oil and natural gas industry, particularly our exploration and
development activities and variations in commodity prices, there can be no
assurance that capital programs, whether limited to the excess of funds flow
over distributions or not, will be sufficient to maintain or increase our
production levels or cash flow from operating activities. Penn West
historically incurred a larger proportion of its development expenditures in
the first quarter of each calendar year to exploit winter-only access
properties. As we strive to maintain sufficient credit facilities and
appropriate levels of debt, this seasonality is not currently expected to
influence our distribution policies.
Our calculation of standardized distributable cash has no adjustment for
long-term unfunded contractual obligations. We believe our only significant
long-term unfunded contractual obligation at this time is for asset retirement
obligations. Cash flow from operating activities, used in our standardized
distributable cash calculation, includes a deduction for abandonment
expenditures incurred during each period. We believe that our current
environmental programs will be sufficient to fund our asset retirement
obligations over the life of our reserves.
We currently have no financing restrictions caused by our debt covenants.
We regularly monitor our current and forecast debt levels to ensure debt
covenants are not exceeded.
(millions, except ratios) To December 31, 2007
-------------------------------------------------------------------------
Cumulative standardized distributable
cash from operations(1) $ 1,562.9
Issue of trust units 290.0
Bank borrowing and working capital change 258.3
-------------------------------------------------------------------------
Cumulative cash distributions declared(1) $ 2,111.2
-------------------------------------------------------------------------
Standardized distributable cash payout ratio (2) 1.35
-------------------------------------------------------------------------
(1) Subsequent to the trust conversion on May 31, 2005.
(2) Represents cumulative cash distributions declared divided by
cumulative standardized distributable cash.
Financial Instruments
During 2007, Penn West had $201.6 million of unrealized losses on risk
management activities compared to a $48.6 million gain in 2006. The losses in
2007 were primarily due to record oil prices experienced in the latter part of
the year.
As at December 31, 2007 we had WTI crude oil collars on approximately
30,000 barrels per day for 2008 with an average floor price of US$66.17 per
barrel and an average ceiling price of US$81.75 per barrel. In addition, Penn
West has AECO natural gas collars on approximately 67.5 mmcf per day for 2008
with an average floor price of $6.68 per mcf and an average ceiling price of
$7.70 per mcf.
In the second quarter of 2006, we entered into interest rate swaps that
fix the interest rate for two years at approximately 4.36 percent on
$100�million of floating interest rate debt. Further to this, in the fourth
quarter of 2007, we entered into additional interest swaps that fix the
interest rate for three years at 4.26 percent on $100 million of floating
interest rate debt.
In the third quarter of 2007, we entered into foreign exchange forward
contracts to fix the principal repayment on debt amounts totalling
US$250�million at an exchange rate of approximately par.
In January 2008, we entered into 10-year U.S. Treasury forward contracts
on a notional principal amount of $250 million at an average fixed treasury
rate of 3.6778 percent until June 30, 2008.
Other financial instruments outstanding at December 31, 2007 were Alberta
electricity contracts, which fix 2008 electricity costs on 32 megawatts at
$75.02 per megawatt-hour and in both 2009 and 2010 fix electricity costs on
30�megawatts at $76.23 per megawatt hour.
Mark to market amounts on all financial instruments outstanding at
December 31, 2007 are summarized in note 9 to the unaudited interim
consolidated financial information. Canetic and Vault had entered into a
number of financial instruments that were assumed upon closing of these deals.
Please refer to Penn West's website at www.pennwest.com for details of all
financial instruments currently outstanding.
Outlook
This outlook section is included to provide unitholders with information
as to management's expectations as at February 19, 2008 for production,
revenues and net capital expenditures for 2008 and readers are cautioned that
the information may not be appropriate for any other purpose. This information
constitutes forward-looking information. Readers should note the assumptions,
risks and disclaimers under "Forward-Looking Statements".
The outlook for oil prices remains strong, while the outlook for natural
gas prices remains relatively weak and the Canadian dollar remains strong
compared to the U.S. dollar. Including the Canetic and Vault acquisitions,
Penn West forecasts 2008 production of between 195,000 boe per day and 205,000
boe per day. Based on a forecast WTI oil price of US$80.00 per barrel, a $6.75
per GJ natural gas price at AECO and a CAD/USD exchange rate of par for 2008,
funds flow for 2008 is forecast to be between $2.0 billion and $2.1 billion.
Based on this level of funds flow and other factors, we estimate 2008 net
capital expenditures of approximately $960 million.
Sensitivity Analysis
Estimated sensitivities to selected key assumptions on 2008 financial
results, including the impact of the Canetic, Vault and Titan acquisitions,
and before considering hedging impacts, are outlined in the table below.
Impact on
Impact on funds flow(1) net income(1)
-------------------------------------------------------------------------
$ $
Change of: Change millions $/unit millions $/unit
-------------------------------------------------------------------------
Price per barrel
of liquids $1.00 30.3 0.08 21.2 0.06
Liquids production 1,000 bbls/day 14.7 0.04 4.8 0.01
Price per mcf of
natural gas $0.10 17.2 0.05 12.0 0.03
Natural gas production 10 mmcf/day 14.2 0.04 0.8 -
Effective interest rate 1% 31.4 0.08 22.0 0.06
Exchange rate
($US per $CAD) $0.01 23.9 0.06 16.8 0.04
-------------------------------------------------------------------------
(1) The impact on funds flow and net income is computed based on 2008
forecast commodity prices and production volumes. The impact on net
income assumes that the distribution levels are not adjusted for
changes in funds flow thus changing the incremental future income tax
rate.
Contractual Obligations and Commitments
We are committed to certain payments over the next five calendar years as
follows:
There-
(millions) 2008 2009 2010 2011 2012 after
-------------------------------------------------------------------------
Transportation $ 13.9 $ 5.8 $ 2.2 $ 0.1 $ - $ -
Transportation ($US) 2.3 2.3 2.3 2.3 2.3 6.4
Power infrastructure 6.2 4.2 4.2 4.2 4.2 7.6
Drilling rigs 7.7 2.4 1.2 - - -
Purchase
obligations(1) 13.3 13.3 13.3 13.3 13.2 41.1
Office lease $ 19.4 $ 19.6 $ 17.3 $ 16.5 $ 16.2 $ 104.3
-------------------------------------------------------------------------
(1) These amounts represent estimated commitments of $84.4 million for
CO(2) purchases and $23.1 million for processing fees related to
interests in the Weyburn Unit.
Our syndicated credit facility expires on January 11, 2011. If we were
not successful in renewing or replacing the facility, we could be required to
repay all amounts then outstanding on the facility or enter term bank loans.
In addition, we have US$475 million of fixed-term notes expiring between 2015
and 2022. As we strive to maintain our leverage ratios at relatively modest
levels, we believe we will be successful in renewing or replacing our credit
facility on acceptable terms.
Equity Instruments
-------------------------------------------------------------------------
Trust units issued:
As at December 31, 2007 242,663,164
Issued on exercise of trust unit rights 259,050
Issued to employee savings plan 125,628
Issued pursuant to distribution reinvestment plan 1,116,862
Issued on Canetic acquisition 124,348,739
Issued on Vault acquisition 5,550,923
-------------------------------------------------------------------------
As at February 19, 2008 374,064,366
-------------------------------------------------------------------------
Trust unit rights outstanding:
As at December 31, 2007 14,486,084
Granted 11,657,182
Exercised (259,050)
Forfeited (117,570)
-------------------------------------------------------------------------
As at February 19, 2008 25,766,646
-------------------------------------------------------------------------
Accounting Changes and Pronouncements
Effective January 1, 2007, the Trust adopted new Canadian accounting
standards issued by the CICA, these being "Comprehensive Income", "Financial
Instruments - Disclosure and Presentation", "Hedges", "Financial Instruments -
Recognition and Measurement", and "Equity". The adoption of these standards
has had no material impact on the Trust's net income or funds flows.
Financial Instruments
Financial instruments are measured at fair value on the balance sheet
upon initial recognition of the instrument. Measurement in subsequent periods
depends on whether the financial instrument has been classified in one of the
following categories: held-for-trading, available-for-sale, held-to-maturity,
loans and receivables, or other financial liabilities as defined under CICA
Handbook Section 3855.
Subsequent measurement and changes in fair value will depend on initial
classification, as follows: held-for-trading financial assets are measured at
fair value and changes in fair value are recognized in net income; and
available-for-sale financial instruments are measured at fair value with
changes in fair value recorded in Other Comprehensive Income ("OCI") until the
instrument or a portion thereof is derecognized or impaired, at which time the
amounts would be recorded in net income.
As the Trust elected to discontinue hedge accounting in 2005, the
adoption of these standards did not change the Trust's accounting for
financial instruments. Cash and cash equivalents are designated as held-for-
trading and are measured at carrying value, which approximates fair value due
to the short-term nature of these instruments. Accounts receivable and accrued
revenues are designated as loans and receivables. Accounts payable and accrued
liabilities and long-term debt are designated as other liabilities. Risk
management assets and liabilities are derivative financial instruments
classified as held-for-trading.
Embedded Derivatives
An embedded derivative is a component of a contract that affects the
contract terms in relation to another factor, for example rent costs that
fluctuate with oil prices. These "hybrid" contracts are considered to consist
of a "host" contract plus an "embedded derivative". The embedded derivative is
separated from the host contract and accounted for as a derivative if certain
conditions are met. These include:
- The economic characteristics and risks of the embedded derivative are
not closely related to the economic characteristics and risks of the
host contract:
- If the embedded derivative separated meets the definition of a
derivative: and
- The hybrid contract is not measured at fair value or classified as
held-for-trading.
The Trust currently has no material embedded derivatives.
Comprehensive Income
Comprehensive income is defined as the change in equity from transactions
and other events from non-owner sources. It consists of net income and OCI.
OCI refers to items recognized in comprehensive income that are excluded from
net income calculated in accordance with GAAP. The Trust currently has no
items requiring separate disclosure as OCI on a Statement of Comprehensive
Income.
Future Accounting Pronouncements
Three new Canadian accounting standards have been issued: "Financial
Instruments-Disclosure", "Capital Disclosure" and "Goodwill and Intangible
Assets". These will require additional disclosure in the Trust's financial
statements commencing January�1, 2008 related to the Trust's financial
instruments as well as the management of capital and goodwill.
Related-Party Transactions
During 2007, Penn West paid $1.3 million (2006 - $4.1 million) of legal
fees to a law firm of which a partner is also a director of Penn West.
Off-Balance-Sheet Financing
We have off-balance-sheet financing arrangements consisting of operating
leases. The operating lease payments are summarized in the Contractual
Obligations and Commitments section.
Critical Accounting Estimates
Our significant accounting policies are detailed in note 2 to the
unaudited interim consolidated financial information. In the determination of
financial results, we must make certain significant accounting estimates as
follows:
Full Cost Accounting
We use the full cost method of accounting for oil and natural gas
properties. All costs of exploring for and developing oil and natural gas
reserves are capitalized and depleted against associated oil and natural gas
production using the unit-of-production method based on the estimated proved
reserves with forecast commodity pricing.
Our reserves were evaluated by GLJ Petroleum Consultants Ltd., an
independent engineering firm. In 2007 and 2006, our reserves were determined
in compliance with National Instrument 51-101. The evaluation of oil and
natural gas reserves is, by its nature, based on complex extrapolations and
models as well as other significant engineering, capital, pricing and cost
assumptions. Reserve estimates are a key component in the calculation of
depletion and are a key component of value in the ceiling test. To the extent
that the ceiling amount, based in part on our reserves, is less than the
carrying amount of property, plant and equipment, a write-down against income
must be made. We determined there was no ceiling test write- down required at
December 31, 2007.
Asset Retirement Obligations
The discounted, expected future cost of statutory, contractual or legal
obligations to retire long-lived assets is recorded as an asset retirement
liability with a corresponding increase to the carrying amount of the related
asset. The recorded liability increases over time to its future liability
amount through accretion charges to earnings, included in DD&A. Revisions to
the estimated amount or timing of the obligations are reflected as increases
or decreases to our asset retirement obligation. Actual asset retirement
expenditures are charged to the liability to the extent of the then-recorded
liability. Amounts capitalized to the related assets are amortized to income
consistent with the depletion or depreciation of the underlying asset. Note 6
to the unaudited interim consolidated financial information details the impact
of these accounting recommendations.
Financial Instruments
Financial instruments included in the balance sheets, consist of accounts
and taxes receivable, the fair value of the derivative financial instruments,
current liabilities and the bank loan. The fair values of these financial
instruments approximate their carrying amounts due to the short-term maturity
of the instruments, the mark to market values recorded for the financial
instruments and the market rate of interest applied to the bank loan.
All of our accounts receivable are with customers in the oil and natural
gas industry and are subject to normal industry credit risk. We may, from time
to time, use various types of financial instruments to reduce our exposure to
fluctuating oil and natural gas prices, electricity costs, exchange rates and
interest rates. The use of these financial instruments exposes us to credit
risks associated with the possible non-performance of counterparties to the
derivative contracts. We limit this risk by transacting only with financial
institutions with high credit ratings and by obtaining security in certain
circumstances.
Our revenues from the sale of crude oil, natural gas liquids and natural
gas are directly impacted by changes to the underlying commodity prices. To
ensure that funds flows are sufficient to fund planned capital programs and
distributions, costless collars or other financial instruments may be
utilized. Collars ensure that commodity prices realized will fall into a
contracted range for a contracted sales volume. Forward power contracts fix a
portion of future electricity costs at levels determined to be economic by
management.
Goodwill
Goodwill must be recorded on a business combination when the total
purchase consideration exceeds the fair value of the net identifiable assets
and liabilities of the acquired entity. The goodwill balance is not amortized,
however, it must be assessed for impairment at least annually. Impairment is
initially determined based on the fair value of the reporting entity compared
to its book value. Any impairment must be charged to income or loss in the
period the impairment occurs. We determined there was no goodwill impairment
as at December 31, 2007.
Forward-Looking Statements
In the interest of providing Penn West's unitholders and potential
investors with information regarding Penn West, including management's
assessment of Penn West's future plans and operations, certain statements
contained in this document constitute forward-looking statements or
information (collectively "forward-looking statements") within the meaning of
the "safe harbour" provisions of applicable securities legislation. Forward-
looking statements are typically identified by words such as "anticipate",
"continue", "estimate", "expect", "forecast", "may", "will", "project",
"could", "plan", "intend", "should", "believe", "outlook", "potential",
"target" and similar words suggesting future events or future performance. In
addition, 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
exist in the quantities predicted or estimated and can be profitably produced
in the future. In particular, this document contains forward-looking
statements pertaining to, without limitation, the following: the impact on our
business, distribution policies and unitholders of the SIFT tax and the
different actions that we might take in response to the SIFT tax; the impact
on our reserves and business of the new Alberta royalty framework drilling
plans; sufficiency of insurance related to Wildboy costs and losses; tie-in of
wells; environmental regulation compliance costs and strategy; production
estimates; netback estimates; our business strategy, including our strategy in
respect of our Peace River Oil Sands project, and our coal bed methane, shale
gas and enhanced oil recovery projects; product balance; the sufficiency of
our environmental program; funding sources for distributions, distribution
levels and whether a special distribution will be made in 2007; the funding of
our asset retirement obligations; our beliefs and outlook for the maintenance
of productive capacity; our outlook for oil and natural gas prices; our
forecast 2008 net capital expenditures and the allocation and funding thereof;
the section on "Outlook" which sets forth management's expectations as to
production, revenues and net capital expenditures for 2008; the sensitivity of
our assumptions regarding 2008 funds flow and net income to changes in certain
operational and financial metrics; currency exchange rates; our forecast funds
flow; the nature and effectiveness of our risk management strategies; our
belief that we will be successful in renewing or replacing our credit
facilities on acceptable terms when they expire; the quantity and
recoverability of our oil and natural gas reserves and resources, including
the quantity of discovered heavy oil resources in place at the Peace River Oil
Sands Project; and the ability of Penn West to economically develop its
contingent resources at its Peace River Oil Sands Project and convert these
resources into reserves.
With respect to forward-looking statements contained in this document, we
have made assumptions regarding, among other things: future oil and natural
gas prices and differentials between light, medium and heavy oil prices;
future capital expenditure levels; future oil and natural gas production
levels; future exchange rates; the amount of future cash distributions that we
intend to pay; the cost of expanding our property holdings; our ability to
obtain equipment in a timely manner to carry out development activities; the
ability of insurance to offset the financial impact of the fire-related outage
at the Wildboy natural gas plant; 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
exploitation activities. In addition, the "Outlook" section is based on
specific assumptions as to commodity prices and exchange rates, planned
capital expenditures and our success in maintaining production and adding new
production through our exploitation activities.
Although Penn West believes that the expectations reflected in the
forward-looking statements contained in this document, and the assumptions on
which such forward-looking statements are made, are reasonable, there can be
no assurance that such expectations will prove to be correct. Readers are
cautioned not to place undue reliance on forward-looking statements included
in this document, as there can be no assurance that the plans, intentions or
expectations upon which the forward-looking statements are based will occur.
By their nature, forward-looking statements involve numerous assumptions,
known and unknown risks and uncertainties that contribute to the possibility
that the predictions, forecasts, projections and other forward-looking
statements will not occur, which may cause Penn West's actual performance and
financial results in future periods to differ materially from any estimates or
projections of future performance or results expressed or implied by such
forward-looking statements. These risks and uncertainties include, among other
things: volatility in market prices for oil and natural gas; the impact of
weather conditions on seasonal demand and ability to execute capital programs;
risks inherent in oil and natural gas operations; uncertainties associated
with estimating reserves and resources; competition for, among other things,
capital, acquisitions of reserves, resources, undeveloped lands and skilled
personnel; incorrect assessments of the value of acquisitions; geological,
technical, drilling and processing problems; general economic conditions in
Canada, the U.S. and globally; industry conditions, including fluctuations in
the price of oil and natural gas; royalties payable in respect of our oil and
natural gas production; changes in government regulation of the oil and
natural gas industry, including environmental regulation; fluctuations in
foreign exchange or interest rates; unanticipated operating events that can
reduce production or cause production to be shut-in or delayed; failure to
obtain industry partner and other third-party consents and approvals when
required; stock market volatility and market valuations; OPEC's ability to
control production and balance global supply and demand of crude oil at
desired price levels; political uncertainty, including the risks of
hostilities, in the petroleum producing regions of the world; the need to
obtain required approvals from regulatory authorities from time to time;
failure to realize the anticipated benefits of acquisitions, including the
acquisition of Petrofund Energy Trust, the acquisition of C1 Energy Ltd. and
Vault Energy Trust and the acquisition of Canetic Resources Trust; changes in
tax law; changes in the Alberta royalty framework; uncertainty of obtaining
required approvals for acquisitions and mergers; and the other factors
described under "Business Risks" in this document and in Penn West's public
filings (including our Annual Information Form) available in Canada at
www.sedar.com and in the United States at 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 document speak only as
of the date of this document. Except as expressly required by applicable
securities laws, Penn West does not undertake any obligation to publicly
update or revise any forward-looking statements, whether as a result of new
information, future events or otherwise. The forward-looking statements
contained in this document are expressly qualified by this cautionary
statement.
Additional Information
Additional information relating to Penn West including Penn West's Annual
Information Form is available on SEDAR at www.sedar.com.
Penn West Energy Trust
Consolidated Balance Sheets
December 31, December 31,
(CAD millions, unaudited) 2007 2006
-------------------------------------------------------------------------
Assets
Current
Accounts receivable $ 277.5 $ 268.7
Risk management (note 9) - 54.0
Future income tax 44.3 -
Other 45.7 56.0
-------------------------------------------------------------------------
367.5 378.7
-------------------------------------------------------------------------
Property, plant and equipment (note 4) 7,413.5 7,039.0
Goodwill 652.0 652.0
-------------------------------------------------------------------------
8,065.5 7,691.0
-------------------------------------------------------------------------
$ 8,433.0 $ 8,069.7
-------------------------------------------------------------------------
Liabilities and unitholders' equity
Current
Accounts payable and accrued liabilities $ 359.3 $ 384.1
Distributions payable 82.5 80.6
Risk management (note 9) 147.6 -
-------------------------------------------------------------------------
589.4 464.7
Long-term debt (note 5) 1,943.2 1,285.0
Asset retirement obligations (note 6) 413.5 339.1
Future income taxes 917.4 792.6
-------------------------------------------------------------------------
3,863.5 2,881.4
-------------------------------------------------------------------------
Unitholders' equity
Unitholders' capital (note 7) 3,877.1 3,712.4
Contributed surplus (note 7) 35.3 16.4
Retained earnings 657.1 1,459.5
-------------------------------------------------------------------------
4,569.5 5,188.3
-------------------------------------------------------------------------
$ 8,433.0 $ 8,069.7
-------------------------------------------------------------------------
Subsequent Events (note 3 and 5)
See accompanying notes to the unaudited interim consolidated financial
information.
Penn West Energy Trust
Consolidated Statements of Income and Retained Earnings
Three months ended Years ended
December 31 December 31
-------------------------------------------
(CAD millions, except per unit
amounts, unaudited) 2007 2006 2007 2006
-------------------------------------------------------------------------
Revenues
Oil and natural gas $ 656.0 $ 560.3 $ 2,458.8 $ 2,033.7
Royalties (117.4) (113.0) (450.8) (388.0)
-------------------------------------------------------------------------
538.6 447.3 2,008.0 1,645.7
Risk management gain (loss)
(note 9)
Realized (12.0) 18.2 3.0 67.2
Unrealized (134.8) 4.8 (182.0) 42.8
-------------------------------------------------------------------------
391.8 470.3 1,829.0 1,755.7
-------------------------------------------------------------------------
Expenses
Operating (note 8) 135.1 127.7 517.7 429.1
Transportation 6.6 6.1 24.1 24.5
General and administrative
(note 8) 16.0 13.7 65.8 44.5
Financing (note 5) 27.2 17.8 92.4 49.3
Depletion, depreciation and
accretion 242.2 214.6 896.7 654.7
Risk management (gain) loss -
unrealized (note 9) 0.3 (10.6) 19.6 (5.8)
Unrealized foreign exchange
gain (1.6) - (38.2) -
-------------------------------------------------------------------------
425.8 369.3 1,578.1 1,196.3
-------------------------------------------------------------------------
Income (loss) before taxes (34.0) 101.0 250.9 559.4
-------------------------------------------------------------------------
Taxes
Future income tax expense
(reduction) (161.0) (21.9) 75.4 (106.2)
-------------------------------------------------------------------------
Net income 127.0 122.9 175.5 665.6
Retained earnings,
beginning of period 777.1 1,578.1 1,459.5 1,605.7
Distributions declared (247.0) (241.5) (977.9) (811.8)
-------------------------------------------------------------------------
Retained earnings, end
of period $ 657.1 $ 1,459.5 $ 657.1 $ 1,459.5
-------------------------------------------------------------------------
Net income per unit
Basic $ 0.53 $ 0.44 $ 0.73 $ 3.32
Diluted $ 0.52 $ 0.44 $ 0.73 $ 3.27
Weighted average units
outstanding (millions)
Basic 241.8 236.7 239.4 200.8
Diluted 243.5 239.5 241.5 203.5
-------------------------------------------------------------------------
See accompanying notes to the unaudited interim consolidated financial
information.
Penn West Energy Trust
Consolidated Statements of Cash Flows
Three months ended Years ended
December 31 December 31
------------------------------------------
(CAD millions, unaudited) 2007 2006 2007 2006
-------------------------------------------------------------------------
Operating activities
Net income $ 127.0 $ 122.9 $ 175.5 $ 665.6
Depletion, depreciation
and accretion (note 4) 242.2 214.6 896.7 654.7
Future income tax expense
(reduction) (161.0) (21.9) 75.4 (106.2)
Unit-based compensation
(note 8) 5.5 3.1 20.5 11.3
Risk management (gain)
loss (note 9) 135.1 (15.4) 201.6 (48.6)
Unrealized foreign
exchange gain (1.6) - (38.2) -
Asset retirement expenditures (14.8) (9.3) (51.5) (26.9)
Change in non-cash
working capital (20.7) (32.9) (38.2) (43.6)
-------------------------------------------------------------------------
311.7 261.1 1,241.8 1,106.3
-------------------------------------------------------------------------
Investing activities
Acquisition of property,
plant and equipment (95.5) (12.7) (576.1) (18.2)
Disposition of property,
plant and equipment 75.8 1.8 133.2 12.6
Additions to property,
plant and equipment (191.0) (148.5) (697.3) (572.3)
Petrofund acquisition costs - 4.0 - (25.0)
Change in non-cash
working capital (24.9) (28.3) 14.9 11.7
-------------------------------------------------------------------------
(235.6) (183.7) (1,125.3) (591.2)
-------------------------------------------------------------------------
Financing activities
Proceeds from issuance of
notes (note 5) - - 509.1 -
Increase in bank loan 120.1 132.6 187.3 132.6
Issue of equity 6.4 4.2 32.0 22.5
Distributions paid (202.6) (214.2) (844.9) (685.7)
Settlement of future
income tax liabilities
on trust conversion - - - 15.5
-------------------------------------------------------------------------
(76.1) (77.4) (116.5) (515.1)
-------------------------------------------------------------------------
Change in cash - - - -
Cash, beginning of period - - - -
-------------------------------------------------------------------------
Cash, end of period $ - $ - $ - $ -
-------------------------------------------------------------------------
Interest paid $ 34.6 $ 14.5 $ 94.5 $ 44.4
Income taxes paid (recovered) $ (6.9) $ 0.9 $ (2.4) $ 8.6
-------------------------------------------------------------------------
See accompanying notes to the unaudited interim consolidated financial
information.
Notes to the Unaudited Interim Consolidated Financial Information
(All tabular amounts are in millions except numbers of units, per unit
amounts, percentages and various figures in Note 9)
1. Structure of Penn West
Penn West Energy Trust ("Penn West" or the "Trust") is an open-ended,
unincorporated investment trust governed by the laws of the Province of
Alberta. The purpose of Penn West is to indirectly explore for, develop
and hold interests in petroleum and natural gas properties through
investments in securities of subsidiaries and royalty interests in oil
and natural gas properties. Penn West owns 100 percent of the common
shares, directly or indirectly, of the entities that carry on the oil and
natural gas business of Penn West. The activities of these entities are
financed through interest-bearing notes from Penn West and third-party
debt as described in the notes to the unaudited interim consolidated
financial statements.
Pursuant to the terms of net profit interest agreements (the "NPIs"),
Penn West is entitled to payments from certain subsidiary entities equal
to essentially all of the proceeds of the sale of oil and natural gas
production less certain specified deductions. Under the terms of the
NPIs, the deductions are in part discretionary, include the requirement
to fund capital expenditures and asset acquisitions, and are subject to
certain adjustments for asset dispositions.
Under the terms of its trust indenture, Penn West is required to make
distributions to unitholders in amounts at least equal to its taxable
income consisting of interest on notes, the NPIs, and any inter-corporate
distributions and dividends received, less certain expenses and
deductions.
2. Significant accounting policies and basis of presentation
This unaudited interim consolidated financial information has been
prepared in accordance with Canadian generally accepted accounting
principles and is consistent with the accounting policies described in
the notes to the audited consolidated financial statements of Penn West
for the year ended December 31, 2006, except as described below. This
financial information should accordingly be read in conjunction with Penn
West's audited consolidated financial statements and notes thereto for
the year ended December 31, 2006.
Effective January 1, 2007, the Trust adopted new Canadian accounting
standards being "Comprehensive Income", "Financial Instruments -
Disclosure and Presentation", "Hedges", "Financial Instruments -
Recognition and Measurement", and "Equity". The adoption of these
standards has had no material impact on the Trust's net income or funds
flows.
Financial Instruments
Financial instruments are measured at their fair value on the balance
sheet upon initial recognition of the instrument. Measurement in
subsequent periods depends on whether the financial instrument has been
classified in one of the following categories: held-for-trading,
available-for-sale, held-to-maturity, loans and receivables, or other
financial liabilities.
Subsequent measurement and changes in fair value will depend on the
classification of the instrument: held-for-trading financial assets are
measured at fair value and changes in fair value are recognized in net
income; available-for-sale financial instruments are measured at fair
value with changes in fair value recorded in Other Comprehensive Income
("OCI") until the instrument or a portion thereof is derecognized or
impaired at which time the amounts would be recorded in net income.
As the Trust elected to discontinue hedge accounting in 2005, the
adoption of these standards did not change the Trust's accounting for
financial instruments. Cash and cash equivalents are designated as held-
for-trading and are measured at carrying value, which approximates fair
value due to the short-term nature of these instruments. Accounts
receivable and accrued revenues are designated as loans and receivables.
Accounts payable and accrued liabilities and long-term debt are
designated as other financial liabilities. All risk management assets and
liabilities are derivative financial instruments classified as held-for-
trading.
Embedded Derivatives
An embedded derivative is a component of a contract that affects the
terms in relation to another factor, for example rent costs that
fluctuate with oil prices. These "hybrid" contracts are considered to
consist of a "host" contract plus an embedded derivative. The embedded
derivative is separated from the host contract and accounted for as a
derivative only if certain conditions are met. These include:
- the economic characteristics and risks of the embedded derivative are
not closely related to the economic characteristics and risks of the
host contract,
- if the embedded derivative separated meets the definition of a
derivative,
- the hybrid contract is not measured at fair value or classified as
held for trading.
The Trust currently has no material embedded derivatives.
Comprehensive Income
Comprehensive income is defined as the change in equity from transactions
and other events from non-owner sources. It consists of net income and
OCI. OCI refers to items recognized in comprehensive income that are
excluded from net income calculated in accordance with generally accepted
accounting principles. The Trust currently has no items requiring
separate disclosure as OCI on a statement of Comprehensive Income.
Future Accounting Pronouncements
Three new Canadian accounting standards have been issued, "Financial
Instruments-Disclosure", "Capital Disclosure" and "Goodwill and
Intangible Assets", which will require additional disclosure in the
Trust's financial statements commencing January�1, 2008 related to the
Trust's financial instruments as well as the management of capital and
goodwill.
3. Business combinations
Canetic acquisition
On January 11, 2008, Penn West closed its acquisition of Canetic
Resources Trust ("Canetic") for a total acquisition cost of approximately
$3.6 billion, funded through the issuance of 124.3 million trust units,
calculated based on the volume weighted average trading price of the
units around the date of the announcement, discounted by five percent.
Bank debt and estimated working capital deficiency of $1.6 billion,
including transaction costs, and convertible debentures with a fair value
of $260.0 million was also assumed.
Vault acquisition
On January 10, 2008, Penn West closed its acquisition of Vault Energy
Trust (Vault") for a total acquisition cost of approximately
$158.7 million funded through the issuance of 5.6 million trust units and
cash paid for the warrants. The trust unit value was calculated based on
the volume weighted average trading price of the units around the date of
the announcement, discounted by five percent. Also assumed was bank debt
plus estimated working capital deficiency of $126.4 million, including
transaction costs, and convertible debentures with a fair value of
$100.9 million.
4. Property, plant and equipment
December 31, December 31,
2007 2006
-------------------------------------------------------------------------
Oil and natural gas properties, including
production and processing
equipment $ 10,925.1 $ 9,683.2
Accumulated depletion and depreciation (3,511.6) (2,644.2)
-------------------------------------------------------------------------
Net book value $ 7,413.5 $ 7,039.0
-------------------------------------------------------------------------
Other than Penn West's net share of capital overhead recoveries, no
general and administrative expenses are capitalized. In 2007, additions
to property, plant and equipment included a $96.6 million (2006 -
$55.9 million) increase related to additions to asset retirement
obligations and a $5.1 million (2006 - $1.7 million) addition for future
income taxes recorded on minor property acquisitions.
An impairment test was performed on the costs capitalized to oil and
natural gas properties at December 31, 2007 and 2006. The estimated
undiscounted future net funds flows from proved reserves, using forecast
prices, exceeded the carrying amount of the oil and natural gas property
interests less the cost of unproved properties.
5. Long-term debt
December 31, December 31,
2007 2006
-------------------------------------------------------------------------
Bankers' acceptances and prime rate loans $ 1,472.3 $ 1,285.0
US Senior unsecured notes
5.68%, US$160 million, maturing May 31, 2015 158.6 -
5.80%, US$155 million, maturing May 31, 2017 153.7 -
5.90%, US$140 million, maturing May 31, 2019 138.8 -
6.05%, US$20 million, maturing May 31, 2022 19.8 -
-------------------------------------------------------------------------
Total long-term debt $ 1,943.2 $ 1,285.0
-------------------------------------------------------------------------
As at December 31, 2007, Penn West Petroleum Ltd. (the "Company") had an
unsecured, extendible, three-year revolving syndicated credit facility
with an aggregate borrowing limit of $2.1 billion, with an expiry date of
August 25, 2010. In January 2008, our wholly owned subsidiary, Penn West
Petroleum Ltd., amended its unsecured, revolving syndicated credit
facility to an aggregate borrowing limit of $4.0 billion expiring on
January 11, 2011, in part to enable the cancellation of this facility and
the credit facilities of Canetic and Vault. The facility is made up of
two revolving tranches; tranche one of the facility is $3.25 billion and
extendible and tranche two is $750 million and non-extendible. The credit
facility contains provisions for stamping fees on bankers' acceptances
and LIBOR loans and standby fees on unutilized credit lines that vary
depending on certain consolidated financial ratios.
Financing costs include interest expense on long-term debt, including the
syndicated credit facility, of $90.1 million for the year ended
December 31, 2007 (2006 - $47.7 million).
Letters of credit totaling $0.3 million were outstanding on December 31,
2007 (December 31, 2006 - $0.4 million) that reduced the amount otherwise
available to be drawn on the syndicated facility.
The US$475 million senior unsecured notes are subject to the financial
covenant that consolidated debt to consolidated capitalization shall not
exceed 55 percent except in the event of a material acquisition where it
is not to exceed 60 percent. The estimated fair value of the principal
and interest obligations under the notes at December 31, 2007 was
$457.8 million.
In January 2008, we entered into 10-year U.S. Treasury forward contracts
on a notional principal amount of $250 million at an average fixed
treasury rate of 3.6778 percent until June 30, 2008.
6. Asset retirement obligations
The total inflated and undiscounted amount to settle Penn West's asset
retirement obligations at December 31, 2007 was $2.6 billion
(December 31, 2006 - $2.2 billion). The asset retirement obligation was
determined by applying an inflation factor of 2.0 percent (2006 - 2.0
percent) and the inflated amount was discounted using a credit-adjusted
rate of 7.0 percent (2006 - 7.0 percent) over the expected useful life of
the underlying assets, currently extending up to 50 years into the future
with an average life of 23 years. Future cash flows from operating
activities are expected to fund the obligations.
Changes to asset retirement obligations were as follows:
2007 2006
-------------------------------------------------------------------------
Balance, beginning of period $ 339.1 $ 192.4
Liabilities incurred during the period 35.7 30.2
Petrofund Energy Trust liabilities assumed
on acquisition - 98.0
Increase in liability due to change in estimate 60.9 25.7
Liabilities settled during the period (51.5) (26.9)
Accretion charges 29.3 19.7
-------------------------------------------------------------------------
Balance, end of period $ 413.5 $ 339.1
-------------------------------------------------------------------------
7. Unitholders' equity
Unitholders' capital Units Amount
-------------------------------------------------------------------------
Balance, December 31, 2005 163,290,013 $ 561.0
Issued on exercise of trust unit rights(1) 407,750 10.6
Issued to employee trust unit savings plan 295,449 12.3
Issued to distribution reinvestment plan 2,459,870 96.1
Issued on Petrofund acquisition 70,673,137 3,032.4
-------------------------------------------------------------------------
Balance, December 31, 2006 237,126,219 3,712.4
Issued on exercise of trust unit rights(1) 665,155 16.1
Issued to employee trust unit savings plan 532,840 17.5
Issued to distribution reinvestment plan 4,338,950 131.1
-------------------------------------------------------------------------
Balance, December 31, 2007 242,663,164 $ 3,877.1
-------------------------------------------------------------------------
Year ended Year ended
December 31, December 31,
Contributed surplus 2007 2006
-------------------------------------------------------------------------
Balance, beginning of period $ 16.4 $ 5.5
Unit-based compensation expense 20.5 11.3
Net benefit on rights exercised (1) (1.6) (0.4)
-------------------------------------------------------------------------
Balance, end of period $ 35.3 $ 16.4
-------------------------------------------------------------------------
(1) Upon exercise of trust unit rights, the net benefit is reflected as a
reduction of contributed surplus and an increase to unitholders'
capital.
Units Outstanding Year ended December 31
------------------------------------
(millions of units) 2007 2006
-------------------------------------------------------------------------
Weighted average
Basic 239.4 200.8
Dilutive impact of unit rights 2.1 2.7
-------------------------------------------------------------------------
Diluted 241.5 203.5
Outstanding as at December 31
Basic 242.7 237.1
Basic plus trust unit rights 257.1 248.4
-------------------------------------------------------------------------
For the year ended December 31, 2007, 7.0 million trust unit rights (2006
- 1.7 million) were excluded in calculating the weighted average number
of diluted trust units outstanding, as they were considered anti-
dilutive.
8. Unit-based compensation
Trust unit rights incentive plan
Penn West has a unit rights incentive plan that allows Penn West to issue
rights to acquire trust units to directors, officers, employees and other
service providers. Under the terms of the plan, the number of trust units
reserved for issuance shall not exceed 10 percent of the aggregate number
of issued and outstanding trust units of Penn West. Unit rights are
granted at prices administered to be equal to the volume-weighted average
trading price of the trust units on the Toronto Stock Exchange for the
five trading days immediately prior to the date of grant. If certain
conditions are met, the exercise price per unit may be reduced by
deducting from the grant price the aggregate of all distributions, on a
per unit basis, paid by Penn West after the grant date. Rights granted
under the plan prior to November 13, 2006 vest over a five-year period
and expire six years after the date of the grant. Rights granted
subsequent to this date generally vest over a three-year period and
expire four years after the date of the grant.
Year ended Year ended
December 31, 2007 December 31, 2006
------------------------------------------------
Weighted Weighted
average average
Number of exercise Number of exercise
Trust unit rights unit rights price unit rights price
-------------------------------------------------------------------------
Outstanding, beginning
of period 11,284,872 $ 27.76 9,447,625 $ 28.45
Granted 5,189,346 33.24 3,257,622 39.77
Exercised (665,155) 21.91 (407,750) 24.65
Forfeited (1,322,979) 29.88 (1,012,625) 33.38
-------------------------------------------------------------------------
Balance before reduction
of exercise price 14,486,084 29.80 11,284,872 30.89
Reduction of exercise price
for distributions paid - (4.11) - (3.13)
-------------------------------------------------------------------------
Outstanding,
end of period 14,486,084 $ 25.69 11,284,872 $ 27.76
-------------------------------------------------------------------------
Exercisable,
end of period 2,742,359 $ 22.53 1,125,300 $ 23.16
-------------------------------------------------------------------------
Penn West recorded unit-based compensation expense of $20.5 million for
the year ended December 31, 2007, of which $5.5 million was charged to
operating expense and $15.0 million was charged to general and
administrative expense (2006 - $11.3 million, $2.8 million and
$8.5 million respectively). Unit-based compensation expense is based on
the fair value of rights issued and is amortized over the remaining
vesting periods on a straight-line basis.
The Binomial Lattice option-pricing model was used to determine the fair
value of trust unit rights granted with the following weighted average
assumptions:
Year ended December 31 2007 2006(2)
-------------------------------------------------------------------------
Average fair value of trust unit
rights granted (per unit) $ 6.38 $ 8.10
Expected life of trust unit rights (years) 3.0 4.5
Expected volatility (average) 24.9% 23.8%
Risk-free rate of return (average) 4.2% 4.1%
Distribution yield(1) 13.1% 9.9%
-------------------------------------------------------------------------
(1) Represents distributions declared as a percentage of the market price
of trust units and does not account for any portion of distributions
that represent a return of capital.
(2) Rights granted prior to November 13, 2006 vest over a five-year
period. Rights granted subsequent to November 13, 2006 vest over a
three-year period.
Trust unit savings plan
Penn West has an employee trust unit savings plan for the benefit of all
employees. Under the savings plan, employees may elect to contribute up
to 10 percent of their salary and Penn West matches these contributions
at a rate of $1.50 for each $1.00. Both the employee's and Penn West's
contribution are used to acquire Penn West trust units. These trust units
may be issued from treasury at the five-day volume weighted average
month-end trading price on the Toronto Stock Exchange or purchased in the
open market at prevailing market prices.
9. Risk Management
Changes in the fair value of all outstanding financial commodity, power,
interest rate and foreign exchange contracts are reflected on the balance
sheet with a corresponding unrealized gain or loss in income.
The following table reconciles the changes in the fair value of financial
instruments outstanding on December 31, 2007:
Risk management 2007 2006
-------------------------------------------------------------------------
Balance, beginning of period $ 54.0 $ 8.5
Unrealized gain (loss)
on financial instruments:
Commodity collars (182.0) 51.3
Electricity swaps (18.3) (5.6)
Interest rate swaps 0.5 (0.2)
Foreign exchange forwards (1.8) -
-------------------------------------------------------------------------
Fair value, end of period $ (147.6) $ 54.0
-------------------------------------------------------------------------
Penn West had the following financial instruments outstanding as at
December 31, 2007:
Notional Market
volume Remaining term Pricing value
-------------------------------------------------------------------------
Crude oil collars
WTI Collars 10,000 bbls/d Jan/08 - Jun/08 US$ 60.00 to
$94.55/bbl $ (9.2)
WTI Collars 20,000 bbls/d Jan/08 - Dec/08 US$ 67.50 to
$79.18/bbl (109.8)
WTI Collars 10,000 bbls/d Jul/08 - Dec/08 US$ 67.00 to
$79.23/bbl (24.9)
Natural gas
collars
AECO Collars 9,200 mcf/d Jan/08 - Mar/08 $8.18 to
$12.15/mcf 1.1
AECO Collars 46,200 mcf/d Jan/08 - Oct/08 $6.64 to
$7.79/mcf (0.7)
AECO Collars 46,200 mcf/d Apr/08 - Oct/08 $6.60 to
$7.19/mcf (2.0)
Electricity swaps
Alberta Power
Pool Swaps 32 MW 2008 $75.02/MWh -
Alberta Power
Pool Swaps 30 MW 2009 $76.23/MWh 0.1
Alberta Power
Pool Swaps 30 MW 2010 $76.23/MWh (0.7)
Interest rate
swaps
$100.0 Jan/08 - Mar/08 4.356% 0.3
$100.0 Jan/08 - Nov/10 4.264% -
Foreign exchange
forwards
8-year term US$80.0 2015 1.00934 CAD/USD (0.6)
10-year term US$80.0 2017 1.00165 CAD/USD (0.6)
12-year term US$70.0 2019 0.99125 CAD/USD (0.2)
15-year term US$20.0 2022 0.98740 CAD/USD (0.4)
-------------------------------------------------------------------------
Total $ (147.6)
-------------------------------------------------------------------------
A realized gain of $11.0 million (2006 - $17.3 million) on the
electricity contracts has been included in the operating costs.
Realized gains and losses on the interest rate swaps are charged to
interest expense. In the period the fixed rate and the floating rate were
approximately equal resulting in no reportable gain or loss being charged
to interest rate expense in relation to the interest rate swaps.
10. Income taxes
On June 12, 2007, the Government of Canada enacted new tax legislation on
publicly traded income trusts. Under the new rules, effective for the
2011 tax year, distributions of certain types of income will no longer be
deductible for income tax purposes by certain SIFT entities, including
Penn West, and any resultant taxable income at the trust level will be
taxed at an approximate of the corporate tax rate. At the time the
legislation was enacted, the SIFT tax rate was 31.5 percent, which led to
the recording of an additional $325.5 million future income tax liability
and future income tax expense in the second quarter of 2007. In
accordance with GAAP, prior to the enactment, the temporary differences
in the Trust were not reflected in future income taxes. The Trust's
temporary differences were primarily due to excess of the net book value
of oil and natural gas properties assigned on the Petrofund acquisition,
closing on June 30, 2006, over its tax pools. In the fourth quarter of
2007, the Government of Canada enacted tax rate reductions which included
a lower SIFT Tax rate of 29.5 percent in 2011, 28.0 percent in 2012 and
subsequent, and a total reduction to future corporate income tax rates of
3.5 percent. As a result of the substantive enactment of the above
legislation, a $106.4 million future income tax reduction was recorded
during the fourth quarter of 2007.
11. Related-party transactions
During 2007, Penn West paid $1.3 million (2006 - $4.1 million) of legal
fees in the normal course of business to a law firm of which a partner is
also a director of Penn West.
Investor Information
-------------------------------------------------------------------------
Penn West trust units and debentures are listed on the Toronto Stock
Exchange under the symbols PWT.UN, PWT.DB.A, PWT.DB.B, PWT.DB.C, PWT.DB.D,
PWT.DB.E and PWT.DB.F and Penn West trust units are listed on the New York
Stock Exchange under the symbol PWE.
A conference call will be held to discuss Penn West's results at
9:00�a.m. Mountain Standard Time, 11:00 a.m. Eastern Standard Time, on
February�22, 2008. The North American conference call number is 1-800-731-5774
toll-free or 416-644-3419 in the Toronto area. A taped recording will be
available until March 2, 2008 by dialing 877-289-8525 or 416-640-1917 and
entering pass code 21261574 followed by the pound sign. This call will be
broadcast live on the Internet and may be accessed directly on the Penn West
website www.pennwest.com or at the following URL:
http://www.newswire.ca/en/webcast/viewEvent.cgi?eventID!54680.
%SEDAR: 00022266E
%CIK: 0001334388
For further information: PENN WEST ENERGY TRUST, Suite 2200, 425 - First
Street S.W., Calgary, Alberta, T2P 3L8, Phone: (403) 777-2500, Fax: (403)
777-2699, Toll Free: (866) 693-2707, Website: www.pennwest.com; Investor
Relations, Phone: (888) 770-2633, E-mail: investor_relations@pennwest.com;
William Andrew, CEO, Phone: (403) 777-2502, E-mail:
bill.andrew@pennwest.com
