pengrowth 2002 q1
DESCRIPTION
Pengrowth's 2002 first quarter reportTRANSCRIPT
E N E R G Y T R U S T
Vision Courage Commitment Performance
F I R S T Q U A R T E R R E S U L T SM A R C H 3 1 , 2 0 0 2
H I G H L I G H T S
Production was 13% higher for the first quarter of 2002 at 41,859 boe per day, as compared to 37,026 boe per day
for the first quarter of 2001. First quarter 2002 production was weighted 44% to crude oil,
44% to natural gas and 12% to natural gas liquids.
•Long-term debt at March 31, 2002 was $339.1 million, compared to $345.5 million at year-end 2001,
representing a $6.4 million reduction.
•First-quarter 2002 capital spending totaled $11.4 million versus $13.9 million for the same period in 2001
and included $7.9 million allocated to drilling, completions and tie-ins, $2.9 million for facilities
and $0.6 million for lease acquisition costs.
•At the end of April, prices for both crude oil and natural gas were higher than first-quarter 2002 averages,
which is expected to result in increased distributable income over the near term.
Pengrowth’s average realized price declined by 43% to $24.32 per boe in the first quarter of 2002
from $42.90 per boe in the first quarter of 2001.
•Distributable income for the first quarter 2002 decreased 54% from the same period in 2001 to $33.1 million,
while distributable income on a per unit basis was 64% lower at $0.41.
•On April 10, 2002 Pengrowth was successfully listed on the New York Stock Exchange (NYSE).
The listing is a major milestone in the Trust’s history, potentially expanding access to U.S. capital markets.
Note regarding currency: All figures contained within this report are quoted in Canadian dollars
unless otherwise indicated.
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2 P E N G R O W T H E N E R G Y T R U S T
Financial and Operating Highlights
(thousands, except per unit amounts) (unaudited)
Quarter ended March 31 2002 2001 % Change
INCOME STATEMENTOil and gas sales $ 91,634 $ 142,961 -36%Net income $ 442 $ 41,908 -99%Net income per unit $ 0.005 $ 0.655 -99%Distributable income $ 33,118 $ 72,071 -54%
Distributable income per trust unitBased on weighted average units outstanding $ 0.403 $ 1.126 -64%Based on actual distributions paid or declared $ 0.410 $ 1.140 -64%
Weighted average number of units outstanding 82,266 63,988 +29%
BALANCE SHEETWorking capital $ (22,663) $ (24,411) -7%Property, plant and equipment and other assets $1,175,673 $ 1,078,910 +9%Long-term debt $ 339,085 $ 346,847 -2%Unitholders' equity $ 785,387 $ 615,340 +28%
UNIT TRADINGHigh $ 16.23 $ 21.25 Low $ 13.25 $ 18.70 Close $ 16.13 $ 19.85
Value $ 165,670 $ 176,250 -6%Volume 11,395 8,784 +30%
DAILY PRODUCTIONCrude oil (barrels) 18,510 20,433 -9%Natural gas (thousands of cubic feet) 110,050 73,654 +49%Natural gas liquids (barrels) 5,001 4,352 +15%Other 5 - Total production (BOE) 6:1 41,859 37,026 +13%
PRODUCTION INCREASE(6:1 boe) (year over year) +13% +7%
PRODUCTION PROFILE (6:1 conversion) % of totalCrude oil 44% 55%Natural gas 44% 33%Natural gas liquids 12% 12%
AVERAGE PRICESCrude oil (per barrel) $ 32.62 $ 40.35 -19%Natural gas (per mcf ) $ 2.84 $ 8.30 -66%Natural gas liquids (per barrel) $ 22.71 $ 40.94 -45%Average price per BOE 6:1 $ 24.32 $ 42.90 -43%
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P E N G R O W T H E N E R G Y T R U S T 3
NOTE REGARDING FORWARD-LOOKING STATEMENTSThis discussion and analysis contains forward-looking statements.These statements relate to future events or our future performance.
In some cases, you can identify forward-looking statements by terminology such as “may”, “will”, “should”, “expect”, “plan”, “anticipate”,
“believe”,“estimate”,“predict”,“potential”,“continue”, or the negative of these terms or other comparable terminology.These statements are
only predictions. A number of factors, including the business risks discussed below, may cause actual results to vary materially from
these estimates. Actual events or results may differ materially. In addition, this discussion contains forward-looking statements
attributed to third party industry sources. Readers should not place undue reliance on these forward-looking statements.
Distributable Income
Distributable income decreased 54% to $33.1 million for the first quarter of 2002, compared to $72.1 million in the first quarter
of 2001. Distributable income per unit decreased 64% to $0.41 per trust unit in the first quarter of 2002 compared to $1.14 per trust
unit in the first quarter of 2001. Lower distributable income during the quarter is due primarily to lower crude oil and natural
gas prices.
The following is a summary of recent monthly distributions and future key dates:
Ex-Distribution Record Date Distribution Distribution AmountDate * Payment Date per Trust Unit
December 27, 2001 December 31, 2001 January 15, 2002 $ 0.13January 30, 2002 February 1, 2002 February 15, 2002 0.13February 27, 2002 March 1, 2002 March 15, 2002 0.13March 27, 2002 April 1, 2002 April 15, 2002 0.13April 29, 2002 May 1, 2002 May 15, 2002 0.15May 30, 2002 June 3, 2002 June 15, 2002June 26, 2002 June 28, 2001 July 15, 2002July 29, 2002 July 31, 2002 August 15, 2002August 28, 2002 August 30, 2002 September 15, 2002September 26, 2002 September 30, 2002 October 15, 2002October 29, 2002 October 31, 2002 November 15, 2002November 28, 2002 December 2, 2002 December 15, 2002
*To benefit from the monthly cash distribution, unitholders must purchase or hold trust units prior to the ex-distribution date.
Pengrowth Annual Cash Distributions(cents Canadian)
Management’s Discussion and Analysis
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PricesSubstantially all of the decline in distributable income for the first quarter can be attributed to lower natural gas and crude oil prices.
Pengrowth’s average price per BOE of production decreased 43% from $42.90/boe in the first quarter of 2001 to $24.32/boe in the
first quarter of 2002.
Average Prices C$ Three months ended March 31,2002 2001 % Change
Crude oil (per bbl) 32.62 40.35 -19%
Natural gas (per mcf ) 2.84 8.30 -66%
Natural gas liquids (per boe) 22.71 40.94 -45%
Total per boe (6:1) 24.32 42.90 -43%
Pengrowth’s average crude oil price declined by 19% in the first quarter of 2002 compared to the first quarter of 2001, reflecting a
21% decrease in the WTI benchmark price for crude oil over the same period, after adjustment for the weaker Canadian exchange
rate relative to the U.S. dollar in 2002.
Pengrowth’s average natural gas price declined by 66% from $8.30 per mcf in the first quarter of 2001 to $2.84 per mcf in the first
quarter of 2002. This decrease reflects the decline in North American natural gas prices from the record high prices experienced in
the first quarter of 2001.The AECO monthly gas index price fell 69% and the NYMEX Henry Hub gas price index decreased 67% over
the same period.
ProductionTotal BOE production increased 13% in the first quarter of 2002, compared to the first quarter of 2001.
Daily Production Three months ended March 312002 2001 % Change
Crude oil (bbls/d) 18,510 20,433 -9%
Natural gas (mcf/d) 110,050 73,654 +49%
Natural gas liquids (bbls/d) 5,001 4,352 +15%
Total boe/d (6:1) 41,859 37,026 +13%
Pengrowth’s production portfolio in the first quarter of 2002 was weighted 44% towards crude oil, 44% natural gas and the
remaining 12% natural gas liquids.
Oil production volumes have declined as a result of lower natural production at existing properties, the sale of the Virginia Hills
property in January of 2002, and other non-core asset dispositions in the first quarter of 2002.
4 P E N G R O W T H E N E R G Y T R U S T
AECO Gas Price($C/mcf)
WTI Oil Price($US/bbl)
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P E N G R O W T H E N E R G Y T R U S T 5
First quarter natural gas production volumes have increased
49% compared to the first quarter of 2001.This increase can
be attributed to the acquisition of the Sable Offshore
Energy Project in June 2001 and an increased interest in the
Kaybob Notikewan Unit effective March 2001.
Natural gas liquids volumes increased 15% in the first quarter
of 2002 compared to the first quarter of 2001, reflecting the
addition of volumes from Sable, offset in part by declines at
other properties and greater use of production volumes for
re-injection at Judy Creek.
Price Risk Management Program
Pengrowth has entered into financial swap transactions that fix the price on:
7,000 mmbtu per day SOEP natural gas until the end of 2004 at an estimated average Goldboro netback price of US$2.77 per mmbtu
5,000 mmbtu per day of SOEP natural gas for the years 2003 and 2004 at an estimated Goldboro netback price of $5.03 per mmbtu
(all SOEP pricing subject to variations in transportation costs).
4,000 barrels of oil per day of crude oil, including foreign exchange risk, for the remainder of 2002 at an average price of $36.85 per barrel
6,785 mcf per day of Alberta natural gas for the remainder of 2002 at an average plantgate price of $2.99 per mcf.
In the first quarter of 2002, Pengrowth realized a net hedging gain of $0.3 million related to fixed price gas contracts (as compared
to monthly AECO average spot prices) and natural gas financial swap contracts. Net hedging gains realized on crude oil price swap
transactions were $0.5 million.
Interest Rate Swaps
Pengrowth has entered into interest rate swaps on $125 million of its long term debt for three year periods ending in November 2004
($75 million), December 2004 ($25 million) and March 2005 ($25 million), at an average interest rate of 4.09% before stamping fees.
The estimated fair value of these interest rate swaps at March 31, 2002 (the amount that Pengrowth would receive to terminate these
contracts) was $2.5 million.
Net IncomeNet income for the first quarter of 2002 decreased 99% to $0.4 million compared to $41.9 million for the first quarter of 2001. The
majority of the decline is attributable to lower commodity prices in the first quarter of 2002.
Operating CostsFor the first three months of 2002, operating costs were $27.5 million ($7.31 / boe), compared to $21.6 million ($6.49/boe) for the
first three months of 2001. The increase in operating costs is attributable to property acquisitions since the first quarter of 2001,
including Kaybob Notikewan in March 2001 and the Sable acquisition in June 2001, offset in part by lower operating costs at many
existing properties, due to lower electricity costs in Alberta in 2002 compared to the prior year.
Average Daily Production(boe/day)
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6 P E N G R O W T H E N E R G Y T R U S T
Injectants for Miscible FloodDuring the first three months of 2002, Pengrowth purchased $3.3 million of injectants for miscible floods and expensed a related
$12.1 million against distributable income. Pengrowth amortizes the cost of injectants purchased from third parties against
distributable income over the period of expected future economic benefit, which is currently 30 months. In recent months,
amortization has exceeded purchases and the balance of deferred injectant costs is being drawn down. Based on current miscible
flood programs and prevailing gas prices, this trend is expected to continue for the remainder of 2002.At March 31, 2002, the balance
of unamortized injectant costs was $54.2 million.
Disposition of Non-Core PropertiesAs part of Pengrowth’s on going program of reviewing its portfolio of properties, a number of minor properties were offered for sale
in the first quarter of 2002. On January 17, Virginia Hills Unit was sold for proceeds of $4.5 million prior to adjustments. Subsequent
to quarter end, on April 30, a disposition package including Pengrowth’s interest in Strachan, North Pembina Cardium Unit, Minehead
and Niton were sold for total proceeds of $40.2 million, before adjustments. Net proceeds of these dispositions have been applied
towards long term debt. Total first quarter production recorded from these four properties was as follows:
Oil (bpd) 412
Gas (mcf/d) 6,065
NGLs (bpd) 268
Total (boepd 6:1) 1,690
Financial ResourcesPengrowth’s long-term debt at March 31, 2002 was $339.1 million, compared to $345.5 million at December 31, 2001. The decrease
in debt is attributable to amortization of injectants and dispositions of non-core properties offset by capital spending:
Long-term Debt Continuity $ millions
Balance at December 31, 2001 $345.5
Difference between solvent purchases and expenses (8.8)
Dispositions, net of adjustments (5.0)
Capital expenditures, excluding acquisitions 11.4
Proceeds from the issue of trust units pursuant to option exercises and DRIP (0.9)
Change in working capital and Remediation Trust Fund (3.1)
Balance at March 31, 2002 $339.1
The ratio of debt to trailing 12-month distributable income at March 31, 2002 was 1.9 times. After the sale of non-core properties on
April 30, 2002, as discussed above, this ratio is reduced to approximately 1.7 times. Distributable income covered interest expense by
10 times in the first three months of 2002.
Reconciliation of Distributions to Funds Generated from OperationsThe following table demonstrates Pengrowth’s current policy of distributing all of the funds generated by operations, after adjusting
for the manner in which Pengrowth amortizes miscible injectant costs. The practice of amortizing injectant costs over 30 months
creates a temporary difference that reverses over time.
A comparison of the “Distributions” amount shown on Pengrowth’s Consolidated Statement of Cash Flow to “Funds Generated from
Operations”also requires an adjustment for the two-month time lag between when funds are generated by the business and when
they are paid to unitholders.
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P E N G R O W T H E N E R G Y T R U S T 7
Reconciliation of Distributions to Funds Generated From Operations
Consolidated Statement of Cash Flow Three months ended March 31, 2002
$ millions
Distributions per Statement of Cash Flow $32.1
Subtract: Distributions paid in 2002 but earned in 2001
(Distributions payable December 31, 2001) (22.2)
Add: Distributions earned in the first quarter but unpaid at March 31, 2002
(February and March distributions and any balance unpaid) 23.2
Total Adjusted Distributions for the period (Distributable Income) $33.1
Purchase of injectants for miscible floods (3.3)
Amortization of injectants for miscible flood 12.1
Items included in Distributable Income but not in Net Income
(e.g. remediation trust fund contributions in excess of expenses) 0.4
Funds Generated From Operations $42.3
Capital SpendingCapital expenditures for the three months ending March 31, 2002 totaled $11.4 million as compared with $13.9 million for the same
period in 2001. Of the $11.4 million, $7.9 million was spent on drilling, completion and tie-ins, $2.9 million was spent on facilities and
$0.6 was spent on lease acquisition costs. The majority of these costs were spent on development programs at Judy Creek ($3.4
million) McLeod River ($1.1 million), Sable ($1.0 million), Weyburn ($1.1 million), and Goose River ($1.8 million).
First quarter development activities at Pengrowth’s major properties include the following:
At Judy Creek:Initiatives were undertaken by field operations to optimize on-site solvent usage and thereby reduce solvent purchases.
Shut-off of a high permeability streak in an ‘A’ Pool well increased oil production by 100 bpd.
Zonal isolation jobs on two ‘B’ pool wells increased oil production by 82 bpd.
Pengrowth is continuing to study CO2 potential for Judy Creek and other Swan Hills properties in which we hold a working interest.
Judy Creek – Swan Hills Development Activity
Review of Development Activities
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8 P E N G R O W T H E N E R G Y T R U S T
At McLeod River:Pengrowth drilled, completed and tied in one natural gas well (100% interest).The well came on production on March 28, 2002 and
is currently producing 1.5 mmcf/day.
One natural gas well was re-completed, resulting in an increase in production of 300 mcf/d, net to Pengrowth.
Pengrowth received approval to co-mingle two new wells, which resulted in increased production of 300 mcf/d, net to Pengrowth.
At Nipisi:Received regulatory approval to initiate water injection at a well drilled in 2001; commenced injection in late March.
At Enchant:Pengrowth farmed out two LSD’s and one well was drilled at no cost to Pengrowth.
Some offsetting acreage was acquired with a partner at the March 6 land sale. Development plans are currently being evaluated.
A solution gas pipeline was constructed to an Anadarko facility which will result in reduced processing fees and down time.
At Weyburn Unit:The CO2 miscible flood program continued to show positive results during the first quarter of 2002, with incremental oil production
from 19 producers in Phase 1A now exceeding 500 barrels per day, net to Pengrowth.
The operator is proceeding with the development of Phase 1B which will ultimately encompass 17 injection patterns. The first two
injection patterns in Phase 1B are scheduled to commence injection in August and the next two in September, with the associated
producers expected to come on stream in September 2002 and January 2003 respectively.
During the first quarter, eight horizontal wells were drilled to complete existing waterflood patterns. Each well has been rig released
and is anticipated to have oil potential.
McLeod River - 2001/2002 Drilling Activity
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P E N G R O W T H E N E R G Y T R U S T 9
At Goose River:Two new wells which were drilled in the third quarter of 2001 are now tied in and are producing at a combined rate of 360 bbls of
oil per day (152 bbls per day net to Pengrowth).
Miscible pattern number 3 is performing better than expectations.
Sable UpdateSable raw gas production averaged 545 mmcf per day (45.8 mmcf per day net to Pengrowth) during the first quarter of 2002. This
compares with average raw gas production of 480 mmcf per day (40.3 mmcf per day net) during the first quarter of 2001.
Pengrowth has also entered into a contract to supply 25,000 Mmbtu of natural gas to a U.S. based power plant currently under
construction. The contract begins upon plant startup which is expected to occur in the Autumn of 2002.
2002 Tax Estimate UpdatePengrowth estimates that in the current commodity price environment, approximately 50% of distributions paid in 2002 will be
taxable to unitholders, with the remainder of distributions treated as return of capital and thus tax deferred. The taxability may be
reduced if Pengrowth makes additional acquisitions and issues new equity during the balance of the year.
New Capital MarketsOn April 10, 2002, Pengrowth Energy Trust successfully
listed on the New York Stock Exchange (NYSE).The listing
represents a significant milestone in Pengrowth’s history
and will serve unitholders by expanding the Trust’s
access to U.S. capital markets.
Pengrowth units now trade on both the Toronto Stock
Exchange (PGF.UN) and the NYSE (PGH). Stock quotes
for both exchanges can be obtained on the
Pengrowth website at www.pengrowth.com.
Current OutlookAs at the end of April, both crude oil and natural gas prices have increased over the average prices seen in the first quarter of 2002.
As at April 30, 2002 WTI at Cushing closed trading at $US27.29, compared to the first quarter average of US$21.67. Similarly Henry
Hub natural gas closed trading at $US3.80 per Mmbtu, compared to the first quarter average of $US2.33. This recent recovery in
crude oil and natural gas prices is expected to result in increased distributable income over the near term.
James S. Kinnear
President and Chief Executive Officer
Pengrowth Energy Trust
May 2, 2002
For further information, please contact:
Dan Belot, Manager, Investor Relations, Calgary Telephone: (403) 233-0224 Facsimile: (403) 294-0051 Toll Free: 1-800-223-4122
Sally Elliott, Investor Relations, Toronto Telephone: (416) 362-1748 Facsimile: (416) 362-8191 Toll Free: 1-888-744-1111
Website: http://www.pengrowth.com E-mail: [email protected]
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1 0 P E N G R O W T H E N E R G Y T R U S T
Consolidated Balance Sheets
(Stated in thousands of dollars)
As at As at
March 31 December 31
2002 2001
ASSETS (unaudited) (audited)
CURRENT ASSETS
Cash $ - $3,797
Marketable securities (Note 6) 1,666 -
Accounts receivable 31,219 27,859
Inventory 437 2,687
33,322 34,343
REMEDIATION TRUST FUND 6,658 6,470
PROPERTY, PLANT AND EQUIPMENT
AND OTHER ASSETS 1,175,673 1,208,526
$1,215,653 $1,249,339
LIABILITIES AND UNITHOLDERS' EQUITY
CURRENT LIABILITIES
Bank indebtedness $ 2,537 $ -
Accounts payable and accrued liabilities 29,862 31,359
Distributions payable to unitholders 23,245 22,207
Due to Pengrowth Management Limited 341 523
Current portion of Long-Term Debt (Note 3) 28,000 -
83,985 54,089
LONG-TERM DEBT (Note 3) 311,085 345,456
FUTURE SITE RESTORATION COSTS 35,196 32,591
TRUST UNITHOLDERS' EQUITY (Note 4) 785,387 817,203
$ 1,215,653 $ 1,249,339
See accompanying notes to the consolidated financial statements.
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P E N G R O W T H E N E R G Y T R U S T 1 1
Consolidated Statements of Income and Distributable Income
(Stated in thousands of dollars)
(Unaudited)
Three Months ended March 31 2002 2001
REVENUES
Oil and gas sales $ 91,634 $ 142,961
Processing and other income 1,687 1,677
Crown royalties (11,968) (27,030)
Alberta Royalty Tax Credit 125 125
Freehold royalties and mineral taxes (1,411) (2,519)
80,067 115,214
Interest and other income 427 159
NET REVENUE 80,494 115,373
EXPENSES
Operating 27,525 21,633
Amortization of injectants for miscible floods 12,178 10,685
Interest 3,038 4,839
General and administrative 2,230 2,177
Management fee 1,396 2,829
Capital taxes 403 479
Depletion and depreciation 30,447 28,810
Future site restoration 2,829 1,991
80,046 73,443
INCOME BEFORE THE FOLLOWING 448 41,930
Royalty Income Attributable to royalty units other than those held
by Pengrowth Energy Trust 6 22
NET INCOME 442 41,908
Add: Depletion, depreciation and future site restoration 33,276 30,801
Deduct: Alberta Royalty Credit accrued for period (125) (125)
Remediation expenses and trust fund contributions (475) (513)
DISTRIBUTABLE INCOME $ 33,118 $ 72,071
NET INCOME PER UNIT (Note 4) Basic $ 0.005 $ 0.655
Diluted $ 0.005 $ 0.640
DISTRIBUTABLE INCOME PER UNIT (Note 4)
Based on weighted average units outstanding $ 0.403 $ 1.126
Based on actual distributions paid or declared $ 0.410 $ 1.140
See accompanying notes to the consolidated financial statements.
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1 2 P E N G R O W T H E N E R G Y T R U S T
Consolidated Statements of Cash Flow(Stated in thousands of dollars)
(Unaudited)
Three Months ended March 31 2002 2001
CASH PROVIDED BY (USED FOR):
OPERATING
Net income $ 442 $ 41,908
Items not involving cash
Depletion, depreciation and future site restoration 33,276 30,801
Amortization of injectants 12,178 10,685
Purchase of injectants (3,336) (18,087)
Expenditures on remediation (224) (300)
Funds generated from operations 42,336 65,007
Distributions (32,080) (74,848)
Changes in non-cash operating working capital (Note 5) (10,742) (8,127)
(486) (17,968)
FINANCING
Change in long-term debt (6,371) 59,900
Proceeds from issue of trust units 860 3,538
(5,511) 63,438
INVESTING
Expenditures on property, plant and equipment (11,390) (13,916)
Proceeds on property dispositions 4,954 -
Change in Remediation Trust Fund (188) (211)
Marketable securities (1,666) -
Change in non-cash investing working capital (Note 5) 7,953 (48)
Deposit on acquisition – (12,130)
Expenditures on property acquisitions - – (22,027)
(337) (48,332)
DECREASE IN CASH (6,334) (2,862)
CASH AND TERM DEPOSITS AT BEGINNING OF PERIOD 3,797 4,533
CASH AND TERM DEPOSITS (BANK INDEBTEDNESS) AT END OF PERIOD $ (2,537) $ 1,671
See accompanying notes to the consolidated financial statements.
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P E N G R O W T H E N E R G Y T R U S T 1 3
Consolidated Statements of TrustUnitholders’ Equity
(Stated in thousands of dollars)
(Unaudited)
Three Months ended March 31 2002 2001
Unitholders' equity at beginning of period $ 817,203 $ 641,965
Units issued, net of issue costs 860 3,538
Net income for period 442 41,908
Distributable income (33,118) (72,071)
TRUST UNITHOLDERS' EQUITY AT END OF PERIOD $ 785,387 $ 615,340
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1 4 P E N G R O W T H E N E R G Y T R U S T
(Unaudited)
MARCH 31, 2002
(Tabular amounts are stated in thousands of dollars except per unit amounts)
1. SIGNIFICANT ACCOUNTING POLICYThe interim consolidated financial statements of Pengrowth Energy Trust and Pengrowth Corporation (collectively referred to
as “Pengrowth”) have been prepared by management in accordance with accounting principles generally accepted in Canada.
The interim consolidated financial statements have been prepared following the same accounting policies and methods of
computation as the consolidated financial statements for the fiscal year ended December 31, 2001. The disclosures provided
below are incremental to those included with the annual consolidated financial statements. The interim consolidated financial
statements should be read in conjunction with the consolidated financial statements and the notes thereto in Pengrowth’s
annual report for the year ended December 31, 2001.
2. CHANGE IN ACCOUNTING POLICYEffective January 1, 2002, Pengrowth adopted the new standard on accounting for options or similar unit based compensation.
Pengrowth prospectively adopted the new standard. For options or similar instruments granted to non-employees, an amount
equal to the grant date fair value of the instrument will be recorded as a charge to earnings over the vesting period, if any. For
options granted to employees of Pengrowth, the standard provides that Pengrowth may elect not to use this fair value method
but to disclose the impact of the fair value method on a pro forma basis.There was no impact on these financial statements of
adopting the new standard, as Pengrowth did not grant any additional options during the three months ended March 31, 2002.
The new standard also requires recognition of compensation cost with respect to Stock Appreciation Rights granted to
employees. No compensation cost results from application of the above provisions for the three months ended March 31, 2002
or for the year ended December 31, 2001.
3. LONG-TERM DEBTPengrowth has a $415 million revolving credit facility syndicated among nine financial institutions with an extendible 364 day
revolving period and a three year amortization term period. In addition, it has a $35 million demand operating line of credit.
Total borrowing capacity is reduced by outstanding letters of credit in the amount of approximately $9 million. On June 15,
2002, the amount of letters of credit outstanding will increase by $25 million.
In September 2001, the Canadian Institute of Chartered Accountants issued further guidance on the classification of the current
portion of long-term debt obligations. Under this guidance the current portion of the 364 day revolving facility is the amount
that would be required to be paid in the next twelve months if the facility was not renewed by the lenders. The facility is
scheduled for review by the syndicate in June 2002, whereupon it is expected to be renewed for a further 364 days, subject to
satisfactory review by the syndicate.
4. TRUST UNITSThe authorized capital of Pengrowth is 500,000,000 trust units.
March 31, 2002 December 31, 2001
Trust Units Issued Number of units Amount Number of units Amount
Balance, beginning of period 82,240,069 $ 1,280,599 63,852,198 $ 974,724
Issued for cash – – 17,622,500 311,974
Less: issue expenses – – – (18,727)
Issued for cash on exercise of stock options 14,800 186 628,828 10,060
Issued for cash under
Distribution Reinvestment (“DRIP”) Plan 48,096 674 136,543 2,568
Balance, end of period 82,302,965 $ 1,281,459 82,240,069 $ 1,280,599
Notes to Consolidated Financial Statements
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P E N G R O W T H E N E R G Y T R U S T 1 5
The per unit amounts for net income and distributable income are based on weighted average units outstanding for the period.
The weighted average units outstanding for the three months ended March 31, 2002 were 82,266,485 units (March 31, 2001 –
63,988,090 units). In computing diluted net income per unit, 24,162 units were added to the weighted average number of units
outstanding during the period ended March 31, 2002 (March 31, 2001– 360,978) for the dilutive effect of employee stock
options. The per unit amount of distributions paid or declared reflect actual distributions paid or declared based on units
outstanding at the time.
Trust Unit Option Plan
As at March 31, 2002, options to purchase 2,940,293 trust units were outstanding (December 31, 2001 – 3,106,635) that expire
at various dates to August 31,2006.
March 31, 2002 December 31, 2001
Trust Unit Options Number of Weighted Number of Weighted
Options Average Options Average
Exercise Exercise
Price Price
Outstanding at beginning of period 3,106,635 $ 17.78 2,893,554 $ 17.45
Granted - - 905,979 17.66
Exercised (14,800) 12.55 (628,828) 16.00
Cancelled (151,542) 17.38 (64,070) 18.98
Outstanding at period-end 2,940,293 17.82 3,106,635 17.78
Exercisable at period-end 2,124,212 17.77 2,238,406 17.69
Amendments to the trust unit option plan were approved by trust unitholders at the annual meeting of Pengrowth unitholders
on April 23, 2002. The maximum number of units which may be reserved for option grants has been increased from 7 million
to 10 million, provided that the number of options granted does not exceed 10 per cent of issued and outstanding trust units.
The expiry date for all issued and unexercised options, and any options subsequently granted under the plan, has been
increased from five years to seven years.
5. CHANGE IN NON-CASH OPERATING WORKING CAPITALMarch 31, 2002 March 31, 2001
Accounts receivable $ (3,360) $ (5,029)
Inventory 2,250 (3,791)
Accounts payable and accrued liabilities (9,450) 832
Due to Pengrowth Management Limited (182) (139)
$ (10,742) $ (8,127)
CHANGE IN NON-CASH INVESTING WORKING CAPITALMarch 31, 2002 March 31, 2001
Accounts payable for capital accruals $ 3,933 (48)
Deposit on disposition of properties 4,020 --
$ 7,953 $ (48)
The cash payments made for taxes for the quarter ending March 31, 2002 were $355,000 (March 31, 2001 - $430,000) and for
interest were $3,403,500 (March 31, 2001 – $9,002,000).
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1 6 P E N G R O W T H E N E R G Y T R U S T
6. FINANCIAL INSTRUMENTS
Interest Rate Risk
As at March 31, 2002, Pengrowth had entered into interest rate swaps on $125 million of its long term debt for periods of three
years ending November 30, 2004 ($75 million), December 31, 2004 ($25 million) and March 4, 2005 ($25 million) at an average
interest rate of 4.09% (before stamping fees).
The estimated fair value of the interest rate swaps has been determined based on the amount that Pengrowth would receive
or pay to terminate the contracts at period end. At March 31, 2002, the amount that Pengrowth would receive to terminate the
interest rate swaps is $2,517,000.
Forward and Futures Contracts
Pengrowth has a price risk management program whereby the commodity price associated with a portion of its future
production is fixed. Pengrowth sells forward a portion of its future production through a combination of fixed price sales
contracts with customers and commodity swap agreements with financial counterparties. The forward and futures contracts
are subject to market risk from fluctuating commodity prices and exchange rates, however gains or losses on the contracts are
offset by changes in the value of Pengrowth’s production.
As at March 31, 2002, Pengrowth had fixed the price applicable to future production as follows:
Financial Swap Contracts
Crude Oil Natural Gas
Volume Price Volume Fixed Price
(bbl/d) C$/bbl (MMbtu/d) US/MMbtu
2002 4,000 $36.89 7,000 $3.90
2003 - - 7,000 $3.90
2004 - - 7,000 $3.90
As well, Pengrowth has natural gas fixed price sales contracts which fixed the price on 6,785 mcf/d for 2002 at a price of $2.99
Cdn/mcf.
The estimated fair value of the crude oil financial swap contracts and the natural gas fixed price sales contracts have been
determined based on the amounts Pengrowth would receive or pay to terminate the contracts at period-end.At March 31, 2002
the amount Pengrowth would pay to terminate the crude oil and natural gas contracts would be $4,708,000 and $1,614,000,
respectively.
Fair Value of Financial Instruments
The carrying value of financial instruments included in the balance sheet, other than bank debt and marketable securities,
approximate their fair value due to their short maturity. The fair value of the marketable securities at March 31, 2002 was
$1,902,000 (March 31, 2001 – nil). The fair value of the Remediation Trust Fund was $6,656,000 (March 31, 2001 – $5,759,000).
7. SUBSEQUENT EVENTOn April 30, 2002 Pengrowth sold oil and gas properties for gross proceeds of $40.2 million.
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P E N G R O W T H E N E R G Y T R U S T 1 7
DIRECTORS OF PENGROWTH CORPORATION
Thomas A. Cumming
Business Consultant
James S. Kinnear
President, Pengrowth Management Limited
Francis G. Vetsch
President, Quantex Resources Ltd.
Stanley H. Wong
President, Carbine Resources Ltd.
John B. Zaozirny
Counsel, McCarthy Tetrault
Michael A. Grandin
Corporate Director
Director Emeritus
Thomas S. Dobson
President, T.S. Dobson Consultant Ltd.
OFFICERS OF PENGROWTH CORPORATION
James S. Kinnear
President and Chief Executive Officer
Gordon M. Anderson
Vice President and
Interim Chief Financial Officer
Henry D. McKinnon
Vice President, Operations
Lynn Kis
Vice President, Engineering
Charles V. Selby
Corporate Secretary
Chris Webster
Treasurer
Lianne Bigham
Controller
TRUSTEE
Computershare Trust Company of Canada
BANKERS
Bank Syndicate Agent: Royal Bank of Canada
AUDITORS
KPMG LLP
ENGINEERING CONSULTANTS
Gilbert Laustsen Jung Associates Ltd.
PENGROWTH AND A STRONG COMMUNITY
Pengrowth Management Limited believes in
enhancing the community where our
employees live and work. Pengrowth supports
causes and institutions both financially and
through volunteer efforts and is proud of these
associations and partnerships with many
community-building non-profit organizations.
Pengrowth has a substantial investment in
our community and although 100 percent of
the costs are attributed to Pengrowth
Management, Pengrowth Energy Trust
unitholders benefit through the visibility
associated with these vital partnerships.
STOCK EXCHANGE LISTINGS
The Toronto Stock Exchange Symbol
PGF.UN
The New York Stock Exchange Symbol
PGH
PENGROWTH ENERGY TRUST
Head Office
Suite 700, 112 – 4 Avenue S.W.
Calgary, Alberta T2P 0H3 Canada
Telephone: (403) 233-0224
Toll-Free: 1 800 223-4122
Facsimile: (403) 265-6251
Email: [email protected]
Website: http://www.pengrowth.com
Toronto Office
Suite 1200, 141 Adelaide Street W.
Toronto, Ontario M5H 3L5 Canada
Telephone: (416) 362-1748
Toll-Free: 1 888 744-1111
Facsimile: (416) 362-8191
Halifax Office
Purdy’s Wharf Business Centre
407 – 1959 Upper Water Street
Halifax, NS B3J 3N2 Canada
Telephone: (902) 425-8778
Facsimile: (902) 425-7887
INVESTOR RELATIONS
For investor relations enquiries, please contact:
Dan Belot, Manager Investor Relations
Telephone: (403) 213-8650
Toll-Free: 1 800 223-4122
Facsimile: (403) 294-0051
Email: [email protected]
OR
Sally Elliott, Investor Relations, Toronto
Telephone: (416) 362-1748
Toll-Free: 1-888-744-1111
Facsimile: (416) 362-8191
ABBREVIATIONS
bbl barrel
bcf billion cubic feet
boe* barrels of oil equivalent
boe per day* barrels of oil equivalent per
day
lt long.tonnes
mbbls thousand barrels
mmbbls million barrels
mboe* thousand barrels of oil equiv-
alent
mmboe* million barrels of oil equiva-
lent
mcf thousand cubic feet
mmcf million cubic feet
mcf per day thousand cubic feet per day
mmcf per day million cubic feet per day
Pengrowth Energy Trust (EnergyTrust)
Pengrowth Corporation (Corporation)
*6 mcf of gas = 1 barrel of oil
Corporate Information
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