SECURITIES AND EXCHANGE COMMISSION
FORM 6-K
Report of Foreign Private Issuer
Pursuant to Rule 13a-16 or 15d-16 of the
Securities Exchange Act of 1934
For the period May 7, 2005 to May 10, 2005
PENGROWTH ENERGY TRUST
Petro-Canada Centre East Tower
2900, 111
5th
Avenue S.W.
Calgary, Alberta T2P 3Y6 Canada
(address of principal executive offices)
[Indicate by check mark whether the registrant files or will file annual reports under cover Form 20-F or Form 40-F.]
Form 20-F o Form 40-F þ
[Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Security Exchange Act of 1934.
Yes o No þ
[If Yes is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b):___________]
DOCUMENTS FURNISHED HEREUNDER:
1. First Quarter Report for the period ended March 31, 2005
2. Certification of Interim Filings CEO
3. Certification of Interim Filings CFO
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
PENGROWTH ENERGY TRUST by its administrator PENGROWTH CORPORATION |
||||
May 10, 2005 | By: | /s/ Gordon M. Anderson | ||
Name: | Gordon M. Anderson | |||
Title: | Vice President |
F I R S T Q U A R T E R R E S U L T S
M A R C H 3 1 , 2 0 0 5
H I G H L I G H T S
First quarter distributable cash before withholding reached record levels increasing by
38 percent to $127.8 million compared to $92.9 million in the first quarter of 2004. Actual cash
distributions to unitholders in the first quarter of 2005 totaled Cdn $0.69 per trust unit
reflecting a payout ratio of 84 percent of funds generated from operations as compared to 90
percent for the same period in 2004. Based upon the current forward market for commodity prices, it
is proposed to maintain the monthly cash distribution of $0.23 per trust unit through the second
quarter while continuing to reduce the payout ratio.
Pengrowth completed the successful acquisition of an additional 11.89 percent working interest in
Swan Hills Unit No. 1 with the trusts working interest now totaling 22.34 percent. The
acquisition increased Pengrowths reserves base by approximately five percent and added an estimated 12.0 million boe of
proved plus probable reserves.
Continued strength in commodity prices, crude oil in particular, has contributed to solid
operating results. Pengrowths average realized light oil price increased 34 percent from $40.57
in the first quarter of 2004 to $54.42 in the first quarter of 2005 and on a total barrels of
oil equivalent basis, Pengrowths average realized price increased 12 percent from $39.91 to
$44.53 for the same periods, respectively.
Total production in the first quarter of 2005 averaged 59,082 boe per day, an increase of 29
percent over the first quarter of 2004 due mainly to the additional production associated with the
Murphy Assets, an additional shipment of condensate at SOEP during the quarter and one months
production associated with the Swan Hills Unit No. 1 acquisition.
During the first quarter, Pengrowth announced an Arrangement Agreement with Crispin Energy
Inc. to acquire all of the issued and outstanding shares of Crispin. This represents the first
public corporate acquisition for Pengrowth and closed on April 29, 2005. The transaction is
expected to be accretive to unitholders and add proved reserves of 3.9 mmboe and proved plus
probable reserves of 5.2 mmboe. The transaction will also increase Pengrowths exposure to a coal
bed methane play and will increase Pengrowths Canadian resident trust unit ownership above the
ownership threshold of 50.25 percent.
Note regarding currency: All figures contained within this report are quoted in Canadian
dollars unless otherwise indicated.
- 2 - PENGROWTH ENERGY TRUST
Summary of Financial and Operating Results
Three Months ended | ||||||||||||
March 31 | % | |||||||||||
(thousands, except per unit amounts) | 2005 | 2004 | Change | |||||||||
INCOME STATEMENT |
||||||||||||
Oil and gas sales |
$ | 236,768 | $ | 165,880 | ** | 43 | ||||||
Net income |
$ | 56,314 | $ | 38,652 | 46 | |||||||
Net income per unit |
$ | 0.37 | $ | 0.31 | 19 | |||||||
Funds generated from operations |
$ | 126,407 | $ | 91,798 | 38 | |||||||
Funds generated from operations per unit |
$ | 0.82 | $ | 0.73 | 12 | |||||||
Cash withheld |
$ | 12,782 | $ | 9,289 | 38 | |||||||
Distributable cash before withholding * |
$ | 127,804 | $ | 92,895 | 38 | |||||||
Distributable cash before withholding per unit * |
$ | 0.83 | $ | 0.74 | 12 | |||||||
Distributable cash * |
$ | 115,022 | $ | 83,606 | 38 | |||||||
Actual distributions paid or declared |
$ | 105,998 | $ | 82,955 | 28 | |||||||
Actual distributions paid or declared per unit |
$ | 0.69 | $ | 0.63 | 10 | |||||||
Weighted average number of units outstanding |
153,388 | 125,220 | 22 | |||||||||
BALANCE SHEET |
||||||||||||
Working capital |
$ | (97,897 | ) | $ | 194,650 | (150 | ) | |||||
Property, plant and equipment and other assets |
$ | 2,061,105 | $ | 1,507,905 | 37 | |||||||
Long-term debt |
$ | 441,920 | $ | 262,260 | 69 | |||||||
Unitholders equity |
$ | 1,414,203 | $ | 1,315,025 | 8 | |||||||
Unitholders equity per unit |
$ | 9.21 | $ | 9.72 | (5 | ) | ||||||
Number of units outstanding at period end |
153,621 | 135,324 | 14 | |||||||||
DAILY PRODUCTION |
||||||||||||
Crude oil (barrels) |
20,443 | 21,516 | (5 | ) | ||||||||
Heavy oil (barrels) |
6,046 | | | |||||||||
Natural gas (thousands of cubic feet) |
157,491 | 117,348 | 34 | |||||||||
Natural gas liquids (barrels) |
6,345 | 4,594 | 38 | |||||||||
Total production (BOE) 6:1 |
59,082 | 45,668 | 29 | |||||||||
TOTAL PRODUCTION (MBOE) 6:1 |
5,317 | 4,156 | 29 | |||||||||
PRODUCTION INCREASE (year over year) |
29 | % | -10 | % | ||||||||
PRODUCTION PROFILE (6:1 conversion) |
||||||||||||
Crude oil |
35 | % | 47 | % | ||||||||
Heavy oil |
10 | % | | |||||||||
Natural gas |
44 | % | 43 | % | ||||||||
Natural gas liquids |
11 | % | 10 | % | ||||||||
AVERAGE PRICES |
||||||||||||
Crude oil (per barrel) |
$ | 54.42 | $ | 40.57 | ** | 34 | ||||||
Heavy oil (per barrel) |
$ | 24.39 | $ | | | |||||||
Natural gas (per mcf) |
$ | 6.84 | $ | 6.82 | ** | | ||||||
Natural gas liquids (per barrel) |
$ | 50.48 | $ | 37.08 | ** | 36 | ||||||
Average price per BOE 6:1 |
$ | 44.53 | $ | 39.91 | ** | 12 |
PENGROWTH ENERGY TRUST - 3 -
Summary of Trust Unit Trading Data
Three Months ended | ||||||||||||||||
March 31 | ||||||||||||||||
(thousands, except per unit amounts) | 2005 | 2004 | ||||||||||||||
TRUST UNIT TRADING (Class A) |
||||||||||||||||
PGH (NYSE) after unit re-class*** |
||||||||||||||||
High |
$ | 22.94 | US | $ | | US | ||||||||||
Low |
$ | 18.11 | US | $ | | US | ||||||||||
Close |
$ | 20.00 | US | $ | | US | ||||||||||
Value |
$ | 515,131 | US | $ | | US | ||||||||||
Volume (thousands of units) |
24,621 | | ||||||||||||||
PGF.A (TSX) *** |
||||||||||||||||
High |
$ | 28.29 | $ | | ||||||||||||
Low |
$ | 22.15 | $ | | ||||||||||||
Close |
$ | 24.03 | $ | | ||||||||||||
Value |
$ | 53,267 | $ | | ||||||||||||
Volume (thousands of units) |
2,049 | | ||||||||||||||
TRUST UNIT TRADING (Class B) |
||||||||||||||||
PGF.B (TSX) *** |
||||||||||||||||
High |
$ | 19.90 | $ | | ||||||||||||
Low |
$ | 16.10 | $ | | ||||||||||||
Close |
$ | 17.05 | $ | | ||||||||||||
Value |
$ | 543,701 | $ | | ||||||||||||
Volume (thousands of units) |
29,219 | | ||||||||||||||
TRUST UNIT TRADING (before unit re-class) |
||||||||||||||||
PGH (NYSE) before unit re-class*** |
||||||||||||||||
High |
$ | | US | $ | 16.60 | US | ||||||||||
Low |
$ | | US | $ | 12.10 | US | ||||||||||
Close |
$ | | US | $ | 13.70 | US | ||||||||||
Value |
$ | | US | $ | 525,609 | US | ||||||||||
Volume (thousands of units) |
| 36,899 | ||||||||||||||
PGF.UN (TSX) *** |
||||||||||||||||
High |
$ | | $ | 21.25 | ||||||||||||
Low |
$ | | $ | 15.55 | ||||||||||||
Close |
$ | | $ | 17.98 | ||||||||||||
Value |
$ | | $ | 567,785 | ||||||||||||
Volume (thousands of units) |
| 30,620 |
***July 27, 2004, all trust units were re-classified into Class A or Class B trust units.
Class A trust Units trade on the NYSE under PGH and on the TSX under PGF.A. Class B trust units trade only on the TSX under PGF.B.
- 4 - PENGROWTH ENERGY TRUST
Presidents Message
Pengrowth is pleased to announce the unaudited quarterly results for the three months ended March 31, 2005. The first quarter of 2005 was characterized by a high level of activity and strong results driven by robust commodity prices and increased production.
During the quarter Pengrowth realized several milestones that contributed to the continued favourable performance of the trust, including the generation of record levels of distributable cash before withholding at $127.8 million, an increase of 38% over first quarter 2004. Distributions to unitholders remained stable at Cdn $0.23 per trust unit per month.
The strength and resiliency of commodity prices during the quarter is highlighted in Pengrowths average realized price of $44.53 per barrel of oil equivalent (boe) compared to $39.91 in the first quarter of 2004. The rise was largely attributable to significant gains in the trusts average realized price for light crude oil and natural gas liquids which increased by 34 percent and 36 percent, respectively, when compared to the same period in 2004. These gains were somewhat mitigated by relatively flat natural gas prices and the higher price of diluent required in association with the trusts heavy oil production.
The successful acquisition of a further 11.89 percent working interest in Swan Hills Unit No.1 at the end of February brought Pengrowths total working interest to 22.34 percent and was funded through existing credit facilities. Incremental oil and gas production from this acquisition in combination with the additional output associated with the Murphy Assets and an additional shipment of condensate at Sable led to the significant increase in production levels in the first quarter of 2005 to an average of 59,082 boe per day, an increase of 29 percent when compared to 45,668 boe per day during the same period in 2004.
Also in the quarter, Pengrowth announced an Arrangement Agreement with Crispin Energy Inc., marking the trusts first acquisition of a public corporation. The acquisition is expected to be accretive to unitholders on a production and distributable cash per trust unit basis and will add proved plus probable reserves of 5.2 million boe. On April 28, 2005, Crispin shareholders voted to accept the Plan of Arrangement with over 99 percent of shareholders voting in favour of the transaction. The Plan of Arrangement closed on April 29, 2005.
The acquisition included Crispins producing properties which are located primarily in the Three Hills area of central Alberta, one of Pengrowths focus areas, as well as an additional 39,000 net acres of undeveloped land, including an approximate 25,000 net acres in the Horseshoe Canyon Coal Bed Methane prospect areas of Twining and Mikwan. The transaction includes an arrangement whereby Pengrowth will engage, for a minimum of six months, members of Crispins experienced senior management team, led by Mr. Murray Nunns and Mr. William Bradley, to provide additional technical expertise and assist Pengrowth in the identification and assessment of acquisition, development and optimization opportunities. The transaction will also increase the proportion of Class B trust units outstanding from the current level of slightly less than 50 percent to approximately 51 percent, enabling Pengrowth to achieve the Canadian majority ownership threshold of 50.25 percent prior to June 1, 2005 in accordance with Pengrowths advance tax ruling further clarifying Pengrowths continued status as a Mutual Fund Trust.
To the extent that Class A trust units in the future represent less than the ownership threshold of 49.75 percent, conversion of a limited number of Class B trust units to Class A trust units will be permissible under the Trust Indenture. Pengrowth intends to implement a new form of reservation system in order to provide all unitholders with an equal and orderly opportunity to convert Class B trust units into Class A trust units. Pengrowth is currently working with Computershare to implement this system.
In order to retain internally generated funds for its increased development activities, Pengrowth sought and received unitholder approval in 2002 to withhold up to 20 percent of gross revenue, and beginning with the January 15, 2003 distribution, implemented a withholding program targeting withholdings of approximately 10 percent of cash available for distribution on a monthly basis.
Distributions to unitholders in the first quarter of 2005 totaled Cdn $0.69 per trust unit, resulting in our lowest payout ratio to date at 84 percent of funds generated from operations. In the context of the current pricing environment and the availability of increased development opportunities in the trusts property portfolio, Pengrowths management has undertaken to review the current withholding policy and make appropriate recommendations to the Board of Directors. The recommendations will be dependent on expectations for forward commodity prices, future capital expenditure requirements, the impact of changes to the level of withholding on the Corporations taxability and the availability of debt and equity capital. Pengrowth currently anticipates distributions to be maintained at Cdn $0.23 per trust unit for the second quarter of 2005, up to and including the August 15, 2005 distribution while the payout ratio may continue to trend lower.
I am pleased to welcome two new members, Mr. Kirby Hedrick and Mr. Terry Poole, to Pengrowths Board of Directors as elected
PENGROWTH ENERGY TRUST - 5 -
at the Annual General Meeting held April 26, 2005. Both gentlemen bring considerable experience and expertise to the Board of Directors and their addition demonstrates Pengrowths continued commitment to excellence in all aspects of it business endeavours.
Pengrowth has also had several recent appointments and changes in Senior Management:
| Effective April 19, 2005, Pengrowth announced the appointment of James J. Emme as Executive Vice-President, Pengrowth Corporation and Vice-President, Pengrowth Management Limited, subject to Canadian immigration approval. In this capacity, Mr. Emme will have broad responsibilities for the operating activities of Pengrowth Corporation and the business development activities of Pengrowth Management Limited. | |||
| Also announced previously was the appointment of Christopher Webster as Chief Financial Officer of Pengrowth Corporation, effective March 21, 2005. Mr. Webster previously held the position of Vice-President, Treasurer for Pengrowth. | |||
| Effective immediately, Charles V. Selby has been appointed as Vice-President and Corporate Secretary. Mr. Selby is a lawyer and Professional Engineer with broad involvement in the business and affairs of Pengrowth Corporation and has served as Corporate Secretary since 1993. | |||
| Effective April 25, 2005, Doug C. Bowles has been appointed as Controller of Pengrowth Corporation, replacing Lianne Bigham who recently resigned to pursue personal interests following a 12-year career with Pengrowth. Mr. Bowles brings over 18 years of accounting experience, including 11 years with ExxonMobil Canada. | |||
| Peter Cheung has been appointed to the position of Treasurer, Pengrowth Corporation effective May 16, 2005. Mr. Cheung previously held the position of Vice President Energy Group, RBC Capital Markets. In this position he provided financial advisory services to clients related to acquisition transactions. He has had experience in corporate finance activity related to equity offerings, corporate credit (bridge financing), derivative products (hedging), structured finance products and bond and currency trading. | |||
| Also effective immediately, Jim MacDonald has been appointed to Director of East Coast Operations, from his previous role as General Manager, reflecting Mr. MacDonalds increasing responsibilities in the east coast and his expanding role in respect to Pengrowths general business activities. He joined Pengrowth in 2002 following a 28-year engineering and management career in various positions with Amoco Canada and Nova Scotia Resources Limited. | |||
| Henry McKinnon has expressed his intention to resign as Vice-President, Operations effective May 13, 2005 to pursue personal interests. Mr. McKinnon made significant contributions to Pengrowths growth and development in his seven year career with Pengrowth. Of particular note were his contributions towards the realization of value in relation to Pengrowths Judy Creek acquisition, completed in 1997, and the successful integration of acquisitions from Calpine and Murphy Oil. Mr. McKinnon has agreed to provide Pengrowth with continued advice and support as required beyond May 13, 2005. |
I would like to take this opportunity to thank Ms. Bigham and Mr. McKinnon for their valued contributions to Pengrowth. Their efforts on behalf of the trust and its unitholders were significant and I wish them all the best in their future endeavours. I am pleased to welcome Mr. Bowles and Mr. Emme to Pengrowth and I would like to recognize the exceptional efforts of our entire Pengrowth team. The first quarter of 2005 proved to be exciting as well as challenging. We look forward to the coming quarter and remain committed to providing enhanced value to Pengrowth unitholders.
James S. Kinnear
Chairman, President and Chief Executive Officer
April 29, 2005
For further information about Pengrowth, please visit our website www.pengrowth.com or contact: Investor Relations, Calgary Telephone: (403) 233-0224 Toll Free: 1-800-223-4122 Facsimile: (403) 294-0051 Investor Relations, Toronto Telephone: (416) 362-1748 Toll Free: 1-888-744-1111 Facsimile: (416) 362-8191
- 6 - PENGROWTH ENERGY TRUST
Managements Discussion and Analysis
The following discussion and analysis of financial results is based on information available to April 29, 2005 and should be read in conjunction with:
| The MD&A and the audited consolidated financial statements for the years ended December 31, 2004 and 2003; and | |||
| The interim unaudited consolidated financial statements as at and for the three months ended March 31, 2005. |
Note Regarding Forward-Looking Statements
This 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.
When converting natural gas to equivalent barrels of oil within this discussion, Pengrowth uses the international standard of 6 thousand cubic feet (mcf) to one barrel of oil equivalent (boe). Production volumes and revenues are reported on a gross basis (before crown and freehold royalties) in accordance with Canadian practice. All amounts are stated in Canadian dollars unless otherwise specified.
Non-GAAP Financial Measures
This discussion and analysis refers to certain financial measures that are not determined in accordance with Canadian GAAP. These measures do not have standardized meanings and may not be comparable to similar measures presented by other trusts or corporations. Although such measures as distributable cash, distributable cash before withholding and operating netbacks do not have standardized meanings prescribed by GAAP, distributable cash is determined by reference to the Distributions and Taxability of Distributions section of this report while the remaining measures are determined by reference to our financial statements. We discuss these measures, which have been applied on a consistent basis, because we believe that they facilitate the understanding of the results of our operations and financial position.
Overview
During the first quarter, Pengrowth successfully completed the acquisition of an additional 11.89 percent working interest in the Swan Hills Unit No.1 property for $87 million. This acquisition increased Pengrowths total interest in the property to 22.34 percent and added estimated proved plus probable reserves, as evaluated effective October 1, 2004 by Gilbert Laustsen Jung Associates Ltd.. (GLJ), of 12.0 million boe, an increase of approximately 5 percent to Pengrowths reserve base. Pengrowth funded the purchase through existing bank facilities.
Continued strength in commodity prices and additional production from the Murphy acquisition, which closed on May 31, 2004, had a favourable impact on 2005 first quarter results relative to the first quarter of 2004.
Net Income
Net income for the first quarter of 2005 was $56.3 million ($0.37 per trust unit) compared to $38.7 million ($0.31 per trust unit) for the previous year. The increase in net income in 2005 compared to the same period last year is due mainly to a 29 percent increase in production volumes and a 12 percent increase in average commodity prices offset in part by higher expenses.
Production
Production for the first quarter of 2005 of 59,082 boe per day is 29 percent higher than the 45,668 boe per day in the first quarter of 2004 and 3 percent higher than fourth quarter 2004 production of 57,425 boe per day. Production from the Murphy properties of 14,019 boe per day contributed significantly to the quarter over quarter increase of 13,414 boe per day. Volumes for the first quarter of 2005 also benefited due to the timing of Sable Offshore Energy Project (SOEP) condensate sales and the contribution of one month of production from the additional interest acquired in Swan Hills Unit No. 1.
PENGROWTH ENERGY TRUST - 7 -
Three months ended March 31 | ||||||||||||
Daily Production | 2005 | 2004 | % Change | |||||||||
Light crude oil (bbls) |
20,443 | 21,516 | (5 | )% | ||||||||
Heavy oil (bbls) |
6,046 | | | |||||||||
Natural gas (mcf) |
157,491 | 117,348 | 34 | % | ||||||||
Natural Gas Liquids (bbls) |
6,345 | 4,594 | 38 | % | ||||||||
Total boe/d |
59,082 | 45,668 | 29 | % | ||||||||
Light oil production volumes decreased 5 percent in the first quarter compared to the first quarter of 2004. The Murphy acquisition and development activities over the past year have contributed to partially offset natural production declines occurring in the northeast B.C. projects of Rigel and Squirrel as well as lower volumes from Judy Creek.
Heavy oil production comes from the recently acquired Murphy properties, including working interests in Tangleflags and Bodo, both in Saskatchewan.
Natural gas production increased 34 percent in the first quarter of 2005 compared to the first quarter of 2004. Additional gas volumes of 40 mmcf per day from the Murphy properties, as well as incremental volumes from development activities mitigated the impact of natural production declines. Of note was increased gas production from the Monogram, Tilley and Cessford areas where shallow gas development in the Milk River, Medicine Hat and Second White Specs formations added a further 9.6 mmcf per day of production compared to first quarter 2004 levels. SOEP gas production decreased in the first quarter of 2005 as compared to the same period in 2004 due mainly to a well workover at the Venture 1 well.
Natural gas liquids (NGL) production increased by 38 percent in the first quarter of 2005 over the first quarter of 2004. The fluctuation in NGL sales from quarter to quarter is due mainly to the timing of condensate sales from SOEP. Two condensate shipments were made in the first quarter of 2005, totaling approximately 135,000 barrels, compared to a partial shipment of 11,000 barrels in the same period last year. Pengrowth would normally anticipate one shipment of condensate per quarter.
Prices
Pengrowths average commodity price per boe for the first quarter of 2005 was 12 percent higher than the first quarter of 2004.
Average realized prices Cdn$ | Three months ended March 31 | |||||||||||
(after the impact of hedging) | 2005 | 2004 | % Change | |||||||||
Light crude oil (per bbl) |
$ | 54.42 | $ | 40.57 | 34 | % | ||||||
Heavy oil (per bbl) |
24.39 | | | |||||||||
Natural gas (per mcf) |
6.84 | 6.82 | | |||||||||
Natural Gas Liquids (per bbl) |
50.48 | 37.08 | 36 | % | ||||||||
Total per boe |
$ | 44.53 | $ | 39.91 | 12 | % | ||||||
Pengrowths average light oil price increased 34 percent in the first quarter of 2005 compared to the first quarter of 2004. Although the West Texas Intermediate (WTI) benchmark price increased 42 percent in the first quarter of 2005 compared to the same period last year, it was partially offset by a 7 percent decrease in the value of the U.S. dollar relative to the Canadian dollar and a small negative adjustment in Pengrowths average field quality differentials relative to benchmark pricing.
- 8 - PENGROWTH ENERGY TRUST
Pengrowths average natural gas price for the first quarter of 2005 remained constant at $6.84 per mcf compared to $6.82 per mcf over the same period last year. Pengrowths average natural gas prices remained relatively stable year over year reflective of the small increase (1.4 percent) in the AECO average price. NYMEX average prices increased by 10.2 percent but this was partially offset by a weaker U.S. dollar relative to the Canadian dollar. Pengrowth did not experience the full effect of increased market prices as certain fixed price gas contracts which were part of the Murphy acquisition partially offset the increase in market prices.
Price Risk Management Program
Pengrowth uses forward and futures contracts to manage its exposure to commodity price fluctuations and to provide a measure of stability to our monthly cash distributions.
In the first quarter of 2005, Pengrowth realized a net hedging loss of $0.1 million related to natural gas financial swap contracts, compared to a net hedging loss of $4.7 million for the same period last year.
With the continued strength in crude oil prices in the first quarter, Pengrowth realized a net hedging loss of $6.6 million on crude oil price swap transactions, compared to a loss of $7.1 million in the first quarter of 2004.
In conjunction with the purchase of the Murphy Assets on May 31, 2004, Pengrowth assumed certain fixed price natural gas sales contracts associated with the Murphy reserves. Under these contracts, Pengrowth is obligated to sell 3,886 MMBTU per day, until April 30, 2009 at an average contract price of Cdn $2.27 per MMBTU.
Pengrowth currently has 10,000 barrels per day of crude oil hedged for the remainder of 2005 at an average price of Cdn $ 54.39 per barrel and a further 4,000 barrels per day is hedged for 2006 at Cdn$ 64.08 per barrel. Western gas production of 2,370 MMBTU per day is hedged at an average price of $8.35 per MMBTU for the period of May 1 to December 31, 2005 and a further 2,370 MMBTU per day is hedged at $8.03 per MMBTU for 2006. Eastern gas production of 18,500 MMBTU per day is hedged at an average delivered price of $9.51 per MMBTU for the remainder of 2005 and 2,500 MMBTU per day is hedged at $10.63 for 2006. The details of Pengrowths commodity hedges are provided in Note 8 to the financial statements.
At March 31, 2005, the mark-to-market value of Pengrowths commodity hedges represented a potential loss of $41.1 million consisting of a loss of $4.7 million on natural gas contracts and $36.4 million for crude oil contracts.
Royalties
Royalties, including crown and freehold royalties, were 16 percent of oil and gas sales in the three months ended March 31, 2005, compared to 15 percent in the first three months of 2004 due to the higher effective rates applicable at higher commodity prices.
Operating Costs
Operating costs were $49.1 million (or $9.23 per boe) for the first quarter of 2005, compared to $31.2 million (or $7.50 per boe) for the first quarter of 2004. Higher operating costs associated with the Murphy properties, charges relating to prior periods and increased fixed expenses all contributed to higher operating costs on a per boe basis compared to the first quarter of 2004.
Injectants for miscible floods
During the first quarter of 2005, Pengrowth purchased $7.6 million of injectants and amortized a related $5.4 million against first quarter net income and distributable cash, compared to $7.3 million and $5.2 million, respectively, in first quarter of 2004. The increase in injectant costs year over year is due mainly to increased injectant volumes at Swan Hills. The majority of ethane and natural gas volumes injected at Judy Creek are proprietary volumes produced from Judy Creek and Swan Hills and then re-injected. Revenue is not recorded for volumes that are produced and subsequently re-injected.
At March 31, 2005, the balance of unamortized injectant costs was $27.2 million.
Operating Netbacks
There is no standardized measure of operating netbacks and therefore, operating netbacks, as presented below, may not be comparable to similar measures presented by other companies. Certain assumptions have been made in allocating operating expenses, other production income, other income and royalty injection credits between light crude oil, heavy oil, natural gas and natural gas liquids production.
Operating netbacks increased by approximately 8 percent reflecting the overall increase in oil and gas prices during the quarter offset partially by the increase in operating costs per boe.
PENGROWTH ENERGY TRUST - 9 -
Combined Netbacks
Three months ended | ||||||||
($ per bbl) | March 31, 2005 | March 31, 2004 | ||||||
Sales Price |
$ | 44.97 | $ | 40.37 | ||||
Other production income |
0.15 | 0.24 | ||||||
GORR royalties |
(0.59 | ) | (0.70 | ) | ||||
44.53 | 39.91 | |||||||
Other income |
0.79 | 0.82 | ||||||
Crown and Freehold Royalties |
(7.04 | ) | (5.90 | ) | ||||
Operating Costs |
(9.23 | ) | (7.50 | ) | ||||
Transportation Costs |
(0.34 | ) | (0.37 | ) | ||||
Amortization of injectants |
(1.01 | ) | (1.25 | ) | ||||
Operating Netback |
$ | 27.70 | $ | 25.71 | ||||
Light Crude Netbacks | Natural Gas Netbacks | |||||||||||||||||
Three months ended | Three months ended | |||||||||||||||||
($ per bbl) | March 31, 2005 | March 31, 2004 | ($ per mcf) | March 31, 2005 | March 31, 2004 | |||||||||||||
Sales Price |
$ | 54.42 | $ | 40.57 | Sales Price | $ | 6.84 | $ | 6.82 | |||||||||
Other production income |
0.42 | 0.51 | GORR royalties | (0.11 | ) | (0.12 | ) | |||||||||||
GORR Royalties |
(0.64 | ) | (0.65 | ) | 6.73 | 6.70 | ||||||||||||
54.20 | 40.43 | Other income | 0.21 | 0.23 | ||||||||||||||
Other income |
0.38 | 0.47 | Crown and Freehold Royalties | (1.16 | ) | (1.04 | ) | |||||||||||
Crown and Freehold Royalties |
(6.47 | ) | (3.43 | ) | Operating Costs | (1.08 | ) | (1.05 | ) | |||||||||
Operating Costs |
(10.74 | ) | (8.59 | ) | Transportation Costs | (0.09 | ) | (0.10 | ) | |||||||||
Transportation Costs |
(0.30 | ) | (0.23 | ) | Operating Netback | $ | 4.61 | $ | 4.74 | |||||||||
Amortization of injectants |
(2.93 | ) | (2.66 | ) | ||||||||||||||
Operating Netback |
$ | 34.14 | $ | 25.99 | ||||||||||||||
Heavy Oil Netbacks | Natural Gas Liquids Netbacks | |||||||||||||||||
Three months ended | Three months ended | |||||||||||||||||
($ per bbl) | March 31, 2005 | March 31, 2004 | ($ per bbl) | March 31, 2005 | March 31, 2004 | |||||||||||||
Sales Price |
$ | 24.39 | $ | | Sales Price | $ | 50.48 | $ | 37.08 | |||||||||
GORR Royalties |
(0.06 | ) | | GORR royalties | (0.68 | ) | (0.89 | ) | ||||||||||
24.33 | | 49.80 | 36.19 | |||||||||||||||
Other income |
0.99 | | Crown and Freehold Royalties | (13.39 | ) | (15.88 | ) | |||||||||||
Crown and Freehold
Royalties |
(2.52 | ) | | Operating Costs | (6.88 | ) | (7.45 | ) | ||||||||||
Operating Costs |
(18.56 | ) | | Transportation Costs | | (0.10 | ) | |||||||||||
Operating Netback |
$ | 4.24 | $ | | Operating Netback | $ | 29.53 | $ | 12.76 | |||||||||
General and Administrative
General and administrative expenses (G&A) were $7.1 million in the first quarter of 2005 compared to $5.8 million for the first quarter of 2004. Included in 2005 first quarter G&A is $0.8 million of non-cash compensation costs related to trust unit rights and phantom trust units (see note 1 to consolidated financial statements) compared to $1.1 million for the first quarter of 2004. Excluding the non-cash component of G&A, 2005 year-to-date G&A has increased over 2004 levels by $1.5 million due to a number of factors including increased financial reporting and regulatory costs and the addition of personnel and larger office space required to manage the Murphy assets. On a per boe basis, first quarter G&A is $1.33 per boe, compared to $1.41 per boe for the first quarter of 2004 largely reflecting the volume increases associated with the Murphy Assets.
Management Fees
Management fees were $3.7 million ($0.70 per boe) for the first quarter of 2005 compared to $2.8 million ($0.66 per boe) for the first quarter of 2004. Management fees recorded in the first quarter of 2005 include an accrual for estimated performance fees of $0.6 million. Under the current management agreement, which came into effect July 1, 2003, the manager will earn a performance fee if Pengrowth trust unit total returns exceed 8 percent per annum on a three year rolling average basis. The maximum fees payable, including the performance fee, is limited to 80 percent of the fees that would otherwise have been payable under the old management agreement for the first three years and 60 percent for the subsequent three years. Although the rate base for the calculation of total fees payable to the manager is less under the current management agreement, higher overall production, prices and distributable cash have resulted in an increase in the management fees.
- 10 - PENGROWTH ENERGY TRUST
Interest
Interest expense increased to $5.4 million in the first quarter of 2005 compared to $4.2 million for the first quarter of 2004. Interest expense includes $0.4 million of fees on a year-to-date basis related to the amortization of U.S. debt issue costs and imputed interest on the note payable to Emera Offshore Incorporated. Higher ending long-term debt levels in the first quarter of 2005 of $441.9 million versus $262.3 million at the end of first quarter 2004 contributed to the increase in interest expense.
Depletion and Depreciation
Depletion and depreciation increased to $69.1 million in the first quarter of 2005 compared to $50.5 million in the first quarter of 2004. On a per boe basis, depletion and depreciation has increased to $13.00 per boe in the first quarter of 2005 compared to $12.15 per boe in the first quarter of 2004. The increase is mainly attributable to the purchase of properties over the past year, including the Murphy Assets in May 2004. With the sustained strength in commodity prices in recent years, the higher cost of acquiring oil and gas properties has increased resulting in a higher depletion rate per boe produced.
Distributions and Taxability of Distributions
Pengrowth generated $127.8 million ($0.83 per average trust unit outstanding) of distributable cash before withholding related to first quarter 2005 operations, compared to $92.9 million ($0.74 per average trust unit outstanding) in 2004. Distributions paid or declared of $106 million (2004 - $83 million) equates to approximately 84 percent of funds generated from operations (2004 - 90 percent). Pengrowths recent practice has been to withhold approximately 10 percent of cash available for distribution to repay debt and/or contribute to capital spending. The Board of Directors may decide to increase (or decrease) the amount withheld in the future, depending on a number of factors, including expectations for future commodity prices, capital expenditure requirements and opportunities, the impact of increased (or decreased) withholdings on the taxability of the Trust and the availability of debt and equity capital. Board discretion with respect to withholding is subject to a maximum withholding amount of 20 percent of gross revenues, as approved by unitholders at the 2002 annual general meeting. Given the level of current commodity prices, Pengrowths increased development opportunities from recent acquisitions and ongoing maintenance requirements, Pengrowth expects monthly distributions to remain at $0.23 per trust unit for the second quarter of 2005.
The following is a summary of recent monthly distributions and future key dates:
Ex-Distribution | Distribution | Distribution Amount | US $ | |||||
Date * | Record Date | Payment Date | per Trust Unit | Amount** | ||||
December 29, 2004 |
December 31, 2004 | January 15, 2005 | $0.23 | $0.19 | ||||
December 30, 2004 (U.S.) |
January 3, 2005 (U.S.) | |||||||
January 28, 2005 |
February 1, 2005 | February 15, 2005 | $0.23 | $0.19 | ||||
February 25, 2005 |
March 1, 2005 | March 15, 2005 | $0.23 | $0.19 | ||||
March 30, 2005 |
April 1, 2005 | April 15, 2005 | $0.23 | $0.19 | ||||
April 28, 2005 |
May 2, 2005 | May 15, 2005 | $0.23 | $0.19 | ||||
May 30, 2005 |
June 1, 2005 | June 15, 2005 | ||||||
May 27, 2005 (U.S.) |
May 31, 2005 (U.S.) | |||||||
June 28, 2005 |
June 30, 2005 | July 15, 2005 | ||||||
July 27, 2005 |
July 29, 2005 | August 15, 2005 | ||||||
July 28, 2005 (U.S.) |
August 1, 2005 (U.S.) | |||||||
August 29, 2005 |
August 31, 2005 | September 15, 2005 | ||||||
September 28, 2005 |
September 30, 2005 | October 15, 2005 | ||||||
September 29, 2005 (U.S.) |
October 3, 2005 (U.S.) | |||||||
October 28, 2005 |
November 1, 2005 | November 15, 2005 | ||||||
November 29, 2005 |
December 1, 2005 | December 15, 2005 |
PENGROWTH ENERGY TRUST - 11 -
Cash distributions are paid to unitholders on the 15th day of the second month following the month of production. Pengrowth paid $0.69 per trust unit as cash distributions during the first quarter of 2005.
There is no standardized measure of distributable cash and therefore distributable cash, as reported by Pengrowth, may not be comparable to similar measures presented by other trusts. The following table provides a reconciliation of distributable cash for the first quarter ended March 31, 2005 and 2004.
($thousands, except per unit amounts) | Three months ended | |||||||
March 31, 2005 | March 31, 2004 | |||||||
Funds generated from operations |
$ | 126,407 | $ | 91,798 | ||||
Change in deferred injectants |
2,179 | 2,055 | ||||||
Change in Remediation Trust Funds |
(263 | ) | (298 | ) | ||||
Amortization of deferred charges |
(395 | ) | (474 | ) | ||||
Other |
(124 | ) | (186 | ) | ||||
Distributable cash before withholding |
127,804 | 92,895 | ||||||
Cash withheld |
(12,782 | ) | (9,289 | ) | ||||
Distributable cash |
115,022 | 83,606 | ||||||
Less: Actual distributions paid or declared |
(105,998 | ) | (82,955 | ) | ||||
Remaining Balance |
$ | 9,024 | $ | 651 | ||||
Actual
distributions paid or declared per unit |
$ | 0.69 | $ | 0.63 | ||||
At this time, Pengrowth anticipates that approximately 75-80 percent of 2005 distributions will be taxable; this estimate is subject to change depending on a number of factors including, but not limited to, the level of commodity prices, acquisitions, dispositions and new equity offerings.
Liquidity and Capital Resources
Pengrowths long term debt at March 31, 2005 was $441.9 million, compared to $345.4 million at December 31, 2004 and $262.3 million at March 31, 2004. During the first quarter, Pengrowth added $95 million of new debt. Of that amount $87 million was utilized to fund the acquisition of the additional interest in the Swan Hills property with the remainder to fund ongoing maintenance and development activities. Capital expenditures, excluding acquisitions, of $46 million were financed through the combination of withholdings on distributions of $13 million, DRIP issues and option proceeds of $10 million, additional debt of $8 million and a reduction in cash and working capital of $15 million.
Approximately $152 million of the $375 million credit facility remains unutilized at March 31, 2005. In addition, Pengrowth has a $35 million demand operating line of credit. The remainder of Pengrowths debt outstanding at the end of the first quarter 2005 is U.S. dollar denominated fixed rate term debt, details of which are provided in Note 2 to the financial statements. Due to the decrease in the value of the Canadian dollar relative to the U.S. dollar, an unrealized loss of $1.5 million has been recorded in the quarter ended March 31, 2005 on the U.S. dollar denominated debt with a total unrealized gain of $48.3 million recorded since the debt issuance in April 2003.
- 12 - PENGROWTH ENERGY TRUST
At the end of the first quarter of 2005, Pengrowth was capitalized with 25 percent total debt (net of cash balances) and 75 percent equity, as compared with 4 percent debt and 96 percent equity at the end of the first quarter of 2004 (based on quarter-end market capitalization). The Trusts net debt to annualized cash flow from operations was approximately 0.9 times at the end of the first quarter of 2005, as compared to 0.2 times at the end of the first quarter of 2004 when significant cash balances were held.
As of April 29, 2005, the number of trust units outstanding was approximately:
(000s) | ||||
Class A trust units |
76,794 | |||
Class B trust units |
76,920 | |||
Undeclared trust units |
56 | |||
Total |
153,770 | |||
As of April 29, 2005, the number of trust units options, rights and phantom trust units was approximately:
(000s) | ||||
Trust unit options |
658 | |||
Rights incentive options |
2,146 | |||
Phantom trust units |
160 | |||
Acquisitions
On February 28, 2005, Pengrowth closed the acquisition of an additional working interest of 11.89 percent in Swan Hills Unit No.1 increasing Pengrowths total working interest in Swan Hills Unit No.1 to 22.34 percent. The purchase price was $87 million, after adjustments from the October 1, 2004 effective date to the closing date. Pengrowths independent engineering evaluator, GLJ, prepared an evaluation with an effective date of October 1, 2004. The acquired reserves that are booked based on this report include total proved reserves of 9.7 million boe and proved plus probable reserves of 12.0 million boe using GLJs forecast of future prices at that time.
Capital Spending
Capital expenditures for the three months ending March 31, 2005 totaled $45.5 million including $10.7 million at Judy Creek, $3.0 million at SOEP, $2.8 million at Squirrel, $2.5 million at Weyburn and $2.3 million at Swan Hills. Capital expenditures increased at Swan Hills due in part to the acquisition of an additional working interest at the unit with capital spent in the first quarter on drilling three hill slide wells which will be completed and tied-in during the second quarter.
Pengrowth expects to spend a total of approximately $159.6 million on development activities in the remaining three quarters of 2005 for a total revised capital program of approximately $205 million for full year 2005. This compares to Pengrowths previous guidance of $171 million provided in the Annual Report and reflects the addition of capital resulting from both the Swan Hills and Crispin acquisitions as well as an additional level of risked capital associated with development opportunities currently viewed as having a greater likelihood of initiation during 2005 than previously estimated. Approximately 50% of first quarter capital expenditures have been funded through the 10% holdback from distributable cash, DRIP issues and options proceeds.
Summary of Quarterly Results
The following table is a summary of quarterly results for 2003, 2004 and the first quarter of 2005. Net income and net income per unit for the first quarter of 2005 increased over the previous quarter, mainly due to the absence of a tax charge in 2005 versus the $14.9 million of future taxes booked in the fourth quarter of 2004. A one percent increase in volumes and a seven percent increase in the average per boe price realized accounted for the remaining increase.
2004 | 2005 | |||||||||||||||||||
Q1 | Q2 | Q3 | Q4 | Q1 | ||||||||||||||||
Oil and gas sales ($000s) |
165,880 | 193,637 | 222,848 | 218,835 | 236,768 | |||||||||||||||
Net income ($000s) |
38,652 | 32,684 | 51,271 | 31,138 | 56,314 | |||||||||||||||
Net income per unit ($) |
0.31 | 0.24 | 0.38 | 0.23 | 0.37 | |||||||||||||||
Net income per unit diluted ($) |
0.31 | 0.24 | 0.38 | 0.23 | 0.37 | |||||||||||||||
Distributable Cash ($000s) |
83,606 | 89,119 | 93,870 | 96,466 | 115,022 | |||||||||||||||
Actual distributions paid or declared per unit ($) |
0.63 | 0.64 | 0.67 | 0.69 | 0.69 | |||||||||||||||
Daily production (boe) |
45,668 | 51,451 | 60,151 | 57,425 | 59,082 | |||||||||||||||
Total Production mboe |
4,156 | 4,682 | 5,534 | 5,283 | 5,317 | |||||||||||||||
Average realized price per boe ($ per boe) |
39.91 | 41.36 | 40.27 | 41.42 | 44.53 | |||||||||||||||
Operating netback per boe ($ per boe) |
25.71 | 25.71 | 22.77 | 24.31 | 27.70 | |||||||||||||||
PENGROWTH ENERGY TRUST - 13 -
2003 | ||||||||||||||||
Q1 | Q2 | Q3 | Q4 | |||||||||||||
Oil and gas sales ($000s) |
204,824 | 169,238 | 162,819 | 154,140 | ||||||||||||
Net income ($000s) |
62,920 | 54,214 | 34,808 | 37,355 | ||||||||||||
Net income per unit ($) |
0.57 | 0.49 | 0.29 | 0.31 | ||||||||||||
Net income
per unit - diluted ($) |
0.57 | 0.48 | 0.29 | 0.30 | ||||||||||||
Distributable Cash ($000s) |
97,221 | 71,774 | 72,951 | 71,469 | ||||||||||||
Actual distributions paid or declared per unit ($) |
0.75 | 0.67 | 0.63 | 0.63 | ||||||||||||
Daily production (boe) |
50,827 | 48,839 | 48,850 | 47,653 | ||||||||||||
Total Production mboe |
4,574 | 4,444 | 4,494 | 4,384 | ||||||||||||
Average realized price per boe ($ per boe) |
44.78 | 38.08 | 36.22 | 35.16 | ||||||||||||
Operating netback per boe ($ per boe) |
26.50 | 21.11 | 20.54 | 20.43 | ||||||||||||
Outlook
Based on first quarter 2005 production results, Pengrowth expects daily average production of approximately 56,500 to 58,500 boe per day for the full year 2005. This estimate incorporates production additions from the Swan Hills acquisition, Pengrowths 2005 development program and the additional production expected as a result of the Crispin acquisition, offset by the impact of normal production declines.
In line with Pengrowths previous guidance total operating costs for 2005 are expected to increase to approximately $200.0 million including a full year of costs from the Murphy Assets and those associated with the Swan Hills and Crispin acquisitions. Assuming Pengrowths average production results for 2005 are as forecast above, Pengrowth now estimates 2005 operating costs per boe of between $9.25 and $9.58 and combined G&A and management fees of approximately $ 1.91 to $1.97 per boe.
Pengrowth currently anticipates capital expenditures for maintenance and development of approximately $205 million for 2005. An additional $188 million was incurred to complete the Crispin and Swan Hills acquisitions. Pengrowth successfully completed the acquisition of Crispin on April 29, 2005. The acquisition has been financed by a unit for share exchange with Crispin shareholders.
Assuming that current levels of commodity prices continue, subject to Board approval, Pengrowth expects monthly distributions during the second quarter will be maintained at $0.23 per unit which represent a 74 percent to 79 percent payout of distributable cash (before withholding).
To the extent that Class A trust units in the future represent less than the ownership threshold of 49.75 percent, conversion of a limited number of Class B trust units to Class A trust units will be permissible under the Trust Indenture. Pengrowth intends to implement a new form of reservation system in order to provide all unitholders with an equal and orderly opportunity to convert Class B trust units into Class A trust units. All registered and beneficial unitholders will have the opportunity to participate in the reservation system by providing an appropriate form to Computershare Trust Company of Canada (Computershare). Pengrowth is currently working with Computershare to implement this system but is delaying the implementation of the conversion program pending further discussions with the Department of Finance. Pengrowth expects the system could be operational in the second half of 2005.
James S. Kinnear
Chairman, President and Chief Executive Officer
April 29, 2005
- 14 - PENGROWTH ENERGY TRUST
Operations Review
REVIEW OF DEVELOPMENT ACTIVITIES (All volumes stated below are net to Pengrowth unless otherwise stated)
OPERATED PROPERTIES:
Judy Creek (100% working interest)
| Drilled one oil producer in A Pool. This well will be completed and placed on production during the second quarter. | |||
| Drilled one vertical waterflood injector in the NW quadrant of A Pool. | |||
| Drilled one horizontal miscible injector in the NW quadrant of A Pool. Solvent injection is scheduled to begin in the third quarter. This is the second horizontal injector in this area of A Pool. The first pattern recovered over 700,000 barrels of oil. | |||
| Ongoing benefits are being seen from the waterflood optimization work performed over the past two years: |
| A previously abandoned oil producer was reactivated and acid fracture stimulated in the first quarter. Completion operations are continuing and the well will be tied in during the second quarter. | |||
| An artificial lift upgrade performed on an A Pool oil producer resulted in an increase of 115 barrels of oil per day. |
| Largest Producing Asset | |||
| 2004 Production: 11,845 boe per day | |||
| 2004 Drilling: 5 Oil Wells and 5 Horizontal Injectors | |||
| 2005 Drilling to date: 1 Oil Well and 2 Injectors (one Horizontal) | |||
| 2005 Drilling Remaining: 6 Oil Wells (NW Quadrant) |
Buick/Prespatou (100% working interest)
| Drilled two wells as a continuation of the program begun late in 2004, for a total of four wells. A compressor station and tie-in to the sales point will be completed after break up, for expected initial production volumes of 2.5 mmcf per day. | |||
| One well will be recompleted in an uphole zone once the compressor station is in operation. |
Squirrel (100% working interest)
| Drilled the sixth well of a multi-well program started in 2004. The well encountered water higher than anticipated in the zone, and is being evaluated for conversion to a water injector for the waterflood. | |||
| Drilled one well to farm-in on a section adjacent to Pengrowths existing land. Initial completion on a secondary zone was unsuccessful, and recompletion to the primary target will be completed after breakup. | |||
| One well was recompleted uphole adding 35 barrels of oil per day. |
Bulrush (79% working interest)
| Drilled two wells, one of which is on stream at 1.0 mmcf per day. The second well encountered a depleted zone, and additional evaluation is underway. | |||
| One well was recompleted to an uphole zone, resulting in 500 mcf per day of additional gas production. |
PENGROWTH ENERGY TRUST - 15 -
Other NEBC (50-100% working interest)
| One well was drilled at Willow and is on stream at 900 mcf per day. | |||
| One well was drilled at Elm, and is on production at 25 barrels of oil per day. | |||
| One well was drilled at Velma; two zones were tested with limited results. | |||
| Two wells were drilled and abandoned: one at Oak (zone was wet), and the second at Beaverdam (zone was tight). The Beaverdam wellbore was sold to the operator of the uphole rights. |
NEBC Recompletions:
| Recompletions in alternate zones were undertaken in Weasel, Redeye, and Beatton. Wells will be brought on stream after break up for anticipated incremental production of 1 mmcf per day. |
| Successful Winter 2004 / 05 drilling program |
|||
| 14 wells drilled: |
- 10 indicated Gas
- 2 indicated Oil
- 2 D&A
| Early spring curtailed program | |||
| Preparing summer drilling program (18 gross wells) |
West Pembina
| Drilled one well at West Pembina. Completion is underway with two potential zones. |
Central Area Recompletions
| Two recompletions were done, one is waiting for tie-in after breakup and expected to add initial production of 1 mmcf per day, and one recompletion was abandoned. |
NON-OPERATED PROPERTIES:
Sable Offshore Energy Project (SOEP) (8.4% working interest)
Production
| First quarter gross raw gas production from the five SOEP fields, Thebaud, Venture, North Triumph, Alma and South Venture averaged 392 mmcf per day (32.9 mmcf per day net). | |||
| Monthly raw production for January, February and March was 371 mmcf per day (31.2 mmcf per day net), 402 mmcf per day (33.8 mmcf per day net), 403 mmcf per day (33.8 mmcf per day net), respectively. | |||
| Pengrowth also received condensate shipments in January and March. |
Tier II Status
| Fabrication has started on the compression topsides, jacket and piles. In-service date for the compressor is scheduled for late 2006. | |||
| As of March 31, 2005 the South Venture 3 well was at a drilled depth of 4,000 meters with a projected total depth of 4,612 meters. | |||
| The South Venture 2 well is expected to be completed and producing by mid-2005. |
Monogram Unit (53.8% working interest)
| The 154 well 2004 shallow gas well program was successful and Pengrowths working interest production volumes have increased from 7.5 mmcf per day in mid 2004 to an average of 16 mmcf per day for the first quarter of 2005. |
- 16 - PENGROWTH ENERGY TRUST
Tilley Milk River Gas Unit (9.7% working interest)
| Pengrowth participated in a successful 100 well shallow gas program in 2004. The 2005 program encompasses 108 wells. A total of 102 wells were drilled prior to spring break up and the remaining 6 will be drilled post break up. A total of 30 wells have been placed on stream to the end of the first quarter and the remainder should commence production after the installation of compression facilities in mid-July. Pengrowths working interest production averaged 3.4 mmcf per day for the first quarter of 2005. |
Weyburn Unit (9.75% working interest)
| 2005 will be an active year for development in this unit with expenditures planned for both the waterflood and enhanced oil recovery areas. Pengrowths working interest production averaged 2,420 barrels of oil per day for the first quarter of 2005. |
PENGROWTH ENERGY TRUST - 17 -
Consolidated Balance Sheets
As at | As at | |||||||
March 31 | December 31 | |||||||
(Stated in thousands of dollars) | 2005 | 2004 | ||||||
(unaudited) | (audited) | |||||||
ASSETS |
||||||||
CURRENT ASSETS |
||||||||
Accounts receivable |
$ | 105,320 | $ | 104,228 | ||||
Inventory |
| 439 | ||||||
105,320 | 104,667 | |||||||
REMEDIATION TRUST FUNDS |
8,572 | 8,309 | ||||||
DEFERRED CHARGES (Note 5) |
3,256 | 3,651 | ||||||
GOODWILL |
170,619 | 170,619 | ||||||
PROPERTY, PLANT AND EQUIPMENT
AND OTHER ASSETS |
2,061,105 | 1,989,288 | ||||||
$ | 2,348,872 | $ | 2,276,534 | |||||
LIABILITIES AND UNITHOLDERS EQUITY |
||||||||
CURRENT LIABILITIES
|
||||||||
Bank indebtedness |
$ | 7,608 | $ | 4,214 | ||||
Accounts payable and accrued liabilities |
89,796 | 80,423 | ||||||
Distributions payable to unitholders |
79,721 | 70,456 | ||||||
Due to Pengrowth Management Limited |
5,426 | 7,325 | ||||||
Note payable |
15,000 | 15,000 | ||||||
Current portion of contract liabilities |
5,666 | 5,795 | ||||||
203,217 | 183,213 | |||||||
NOTE PAYABLE |
20,000 | 20,000 | ||||||
CONTRACT LIABILITIES |
16,896 | 18,216 | ||||||
LONG-TERM DEBT (Note 2) |
441,920 | 345,400 | ||||||
ASSET RETIREMENT OBLIGATIONS (Note 4) |
177,453 | 171,866 | ||||||
FUTURE INCOME TAXES |
75,183 | 75,628 | ||||||
TRUST UNITHOLDERS EQUITY: |
||||||||
Trust Unitholders capital (Note 3) |
2,393,379 | 2,383,284 | ||||||
Contributed surplus (Note 3) |
2,528 | 1,923 | ||||||
Accumulated earnings |
783,371 | 727,057 | ||||||
Accumulated distributable cash |
(1,765,075 | ) | (1,650,053 | ) | ||||
1,414,203 | 1,462,211 | |||||||
SUBSEQUENT EVENT (Note 9) |
||||||||
$ | 2,348,872 | $ | 2,276,534 | |||||
See accompanying notes to the consolidated financial statements.
- 18 - PENGROWTH ENERGY TRUST
Consolidated Statements of Income and Accumulated Earnings
(Stated in thousands of dollars) | Three months ended March 31 | |||||||
(Unaudited) | 2005 | 2004 | ||||||
REVENUES |
||||||||
Oil and gas sales |
$ | 236,768 | $ | 165,880 | ||||
Processing and other income |
4,118 | 2,985 | ||||||
Crown royalties, net of incentives |
(33,963 | ) | (23,021 | ) | ||||
Freehold royalties and mineral taxes |
(3,457 | ) | (1,495 | ) | ||||
203,466 | 144,349 | |||||||
Interest and other income |
112 | 425 | ||||||
NET REVENUE |
203,578 | 144,774 | ||||||
EXPENSES |
||||||||
Operating |
49,079 | 31,160 | ||||||
Transportation |
1,807 | 1,557 | ||||||
Amortization of injectants for miscible floods |
5,392 | 5,204 | ||||||
Interest |
5,433 | 4,177 | ||||||
General and administrative |
7,081 | 5,846 | ||||||
Management fee |
3,708 | 2,754 | ||||||
Foreign exchange loss (Note 6) |
1,360 | 2,371 | ||||||
Depletion and depreciation |
69,149 | 50,512 | ||||||
Accretion (Note 4) |
3,403 | 1,999 | ||||||
146,412 | 105,580 | |||||||
INCOME BEFORE TAXES |
57,166 | 39,194 | ||||||
INCOME TAX EXPENSE (REDUCTION) |
||||||||
Capital |
1,297 | 542 | ||||||
Future |
(445 | ) | | |||||
852 | 542 | |||||||
NET INCOME |
$ | 56,314 | $ | 38,652 | ||||
Accumulated earnings, beginning of period |
727,057 | 573,312 | ||||||
ACCUMULATED EARNINGS, END OF PERIOD |
$ | 783,371 | $ | 611,964 | ||||
NET INCOME PER UNIT (Note 3) |
Basic | $ | 0.367 | $ | 0.309 | |||
Diluted | $ | 0.366 | $ | 0.307 | ||||
See accompanying notes to the consolidated financial statements.
PENGROWTH ENERGY TRUST - 19 -
Consolidated Statements of Cash Flow
(Stated in thousands of dollars) | Three months ended March 31 | |||||||
(Unaudited) | 2005 | 2004 | ||||||
CASH PROVIDED BY (USED FOR): |
||||||||
OPERATING |
||||||||
Net income |
$ | 56,314 | $ | 38,652 | ||||
Depletion, depreciation and accretion |
72,552 | 52,511 | ||||||
Future income taxes |
(445 | ) | | |||||
Contract liability amortization |
(1,449 | ) | | |||||
Amortization of injectants |
5,392 | 5,204 | ||||||
Purchase of injectants |
(7,571 | ) | (7,259 | ) | ||||
Expenditures on remediation |
(1,118 | ) | (1,851 | ) | ||||
Unrealized foreign exchange loss (Note 6) |
1,520 | 2,960 | ||||||
Trust unit based compensation (Note 3) |
817 | 1,107 | ||||||
Amortization of deferred charges (Note 5) |
395 | 474 | ||||||
Funds generated from operations |
126,407 | 91,798 | ||||||
Changes in non-cash operating working capital (Note 7) |
10,013 | (4,876 | ) | |||||
136,420 | 86,922 | |||||||
FINANCING |
||||||||
Distributions |
(105,757 | ) | (78,219 | ) | ||||
Change in long-term debt |
95,000 | | ||||||
Proceeds from issue of trust units |
9,883 | 199,439 | ||||||
(874 | ) | 121,220 | ||||||
INVESTING |
||||||||
Expenditures on property acquisitions |
(89,950 | ) | (787 | ) | ||||
Expenditures on property, plant and equipment |
(45,535 | ) | (24,862 | ) | ||||
Change in remediation trust funds |
(263 | ) | (298 | ) | ||||
Change in non-cash investing working capital (Note 7) |
(3,192 | ) | 4,728 | |||||
(138,940 | ) | (21,219 | ) | |||||
CHANGE IN CASH AND TERM DEPOSITS |
(3,394 | ) | 186,923 | |||||
CASH AND TERM DEPOSITS (BANK INDEBTEDNESS)
AT BEGINNING OF PERIOD |
(4,214 | ) | 64,154 | |||||
CASH AND TERM DEPOSITS (BANK INDEBTEDNESS)
AT END OF PERIOD |
$ | (7,608 | ) | $ | 251,077 | |||
See accompanying notes to the consolidated financial statements.
- 20 - PENGROWTH ENERGY TRUST
Notes To Consolidated Financial Statements
(Unaudited)
March 31, 2005
(Tabular amounts are stated in thousands of dollars except per unit amounts) |
1. | SIGNIFICANT ACCOUNTING POLICIES | |||
The interim consolidated financial statements of Pengrowth Energy Trust include the accounts of Pengrowth Energy Trust, Pengrowth Corporation and its subsidiaries (collectively referred to as Pengrowth). The financial statements 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, 2004. 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 Pengrowths annual report for the year ended December 31, 2004. | ||||
LONG-TERM INCENTIVE PLAN | ||||
Effective January 1, 2005, Pengrowth established a new long-term incentive plan whereby rights incentive options and restricted share units (Phantom trust units) are granted under the plan. The terms of the rights incentive options are consistent with the existing Trust Units Rights Incentive Plan. Compensation expense related to rights incentive options is based on a fair value method using a modified Black Scholes model described in Note 10 of the consolidated financial statements for the fiscal year ended December 31, 2004. | ||||
The terms of the Phantom trust units are described in Note 3. Compensation expense related to Phantom trust units is based on the fair value of the Phantom trust units at the date of grant. The number of Class B trust units awarded at the end of the vesting period is subject to certain performance conditions. Compensation expense incorporates the estimated fair value of the Phantom trust units at the date of grant, managements estimate of the number of Phantom trust units that will accrue over the vesting period and an estimate of the relative performance multiplier. Fluctuations in compensation expense may occur due to changes in estimating the outcome of the performance conditions. An estimate of forfeiture has not been made; rather compensation expense is reduced for actual forfeitures as they occur. Compensation expense is recognized in income over the vesting period with a corresponding increase or decrease to contributed surplus. Upon issuance of the Class B trust units at the end of the vesting period, trust unitholders capital is increased and contributed surplus is reduced. | ||||
2. | LONG-TERM DEBT |
As at | As at | |||||||
March 31, | December 31, | |||||||
2005 | 2004 | |||||||
U.S. dollar denominated debt: |
||||||||
U.S. $150 million senior unsecured notes at 4.93% due April 2010 |
$ | 181,440 | $ | 180,300 | ||||
U.S. $50 million senior unsecured notes at 5.47% due April 2013 |
60,480 | 60,100 | ||||||
241,920 | 240,400 | |||||||
Canadian dollar revolving credit borrowings |
200,000 | 105,000 | ||||||
$ | 441,920 | $ | 345,400 | |||||
PENGROWTH ENERGY TRUST - 21 -
On March 31, 2005 Pengrowth had a $375 million revolving unsecured credit facility syndicated among eight financial institutions with an extendible 364 day revolving period and a two year amortization term period. The facilities are currently reduced by outstanding letters of credit in the amount of approximately $23 million. In addition, it has a $35 million demand operating line of credit. Interest payable on amounts drawn is at the prevailing bankers acceptance rates plus stamping fees, lenders prime lending rates, or U.S. libor rates plus applicable margins, depending on the form of borrowing by the Corporation. The margins and stamping fees vary from 0.25 percent to 1.50 percent depending on financial statement ratios and the form of borrowing. | ||||
The revolving credit facility will revolve until May 30, 2005, whereupon it may be renewed for a further 364 days, subject to satisfactory review by the lenders, or converted into a term facility. One third of the amount outstanding would be repaid in equal quarterly installments in each of the first two years with the final one third to be repaid upon maturity of the term period. The Corporation can post, at its option, security suitable to the banks in lieu of the first years payments. In such an instance, no principal payment would be made to the banks for one year following the date of non-renewal. | ||||
3. | TRUST UNITS | |||
The total authorized capital of Pengrowth is 500,000,000 trust units. |
March 31, 2005 | December 31, 2004 | |||||||||||||||
Number | Number | |||||||||||||||
Trust Units Issued | of units | Amount | of units | Amount | ||||||||||||
Balance, beginning of period |
73,325 | $ | 1,123 | 123,873,651 | $ | 1,872,924 | ||||||||||
Issued for cash |
| | 10,900,000 | 200,560 | ||||||||||||
Less: issue expenses |
| | | (10,710 | ) | |||||||||||
Issued for cash on exercise of trust units
options and rights |
| | 547,974 | 8,735 | ||||||||||||
Issued for cash under Distribution
Reinvestment Plan (DRIP) |
| | 543,888 | 9,636 | ||||||||||||
Trust unit rights incentive plan (non-cash
exercised) |
| | | 259 | ||||||||||||
Royalty units exchanged for trust units |
| | 700 | | ||||||||||||
Balance, prior to conversion |
| | 135,866,213 | $ | 2,081,404 | |||||||||||
Converted to Class A or Class B trust units |
(17,352 | ) | (266 | ) | (135,792,888 | ) | (2,080,281 | ) | ||||||||
Balance, end of period |
55,973 | $ | 857 | 73,325 | $ | 1,123 | ||||||||||
Class A Trust Units:
For the period from | ||||||||||||||||
March 31, 2005 | July 27, 2004 to Dec 31, 2004 | |||||||||||||||
Number | Number | |||||||||||||||
Trust Units Issued | of units | Amount | of units | Amount | ||||||||||||
Balance, beginning of period |
76,792,759 | $ | 1,176,427 | | $ | | ||||||||||
Trust units converted |
1,580 | 24 | 76,792,759 | 1,176,427 | ||||||||||||
Balance, end of period |
76,794,339 | $ | 1,176,451 | 76,792,759 | $ | 1,176,427 | ||||||||||
- 22 - PENGROWTH ENERGY TRUST
Class B Trust Units:
For the period from | ||||||||||||||||
March 31, 2005 | July 27, 2004 to Dec 31, 2004 | |||||||||||||||
Number | Number | |||||||||||||||
Trust Units Issued | Of units | Amount | of units | Amount | ||||||||||||
Balance, beginning of period |
76,106,471 | $ | 1,205,734 | | $ | | ||||||||||
Trust units converted |
15,772 | 242 | 59,000,129 | 903,854 | ||||||||||||
Issued for cash |
| | 15,985,000 | 298,920 | ||||||||||||
Less: issue expenses |
| | | (15,577 | ) | |||||||||||
Issued for cash on exercise of trust units
options and rights |
409,645 | 5,607 | 746,864 | 11,516 | ||||||||||||
Issued for cash under Distribution
Reinvestment (DRIP) Plan |
238,850 | 4,276 | 374,478 | 6,750 | ||||||||||||
Trust unit rights incentive plan (non-cash
exercised) |
| 212 | | 271 | ||||||||||||
Balance, end of period |
76,770,738 | $ | 1,216,071 | 76,106,471 | $ | 1,205,734 | ||||||||||
The total number of trust units outstanding as at March 31, 2005 was 153,621,050 trust units (December 31, 2004 152,972,555).
Per Unit Amounts
The per unit amounts of net income are based on the following weighted average units outstanding for the period. The weighted average units outstanding for the three months ended March 31, 2005 were 153,387,514 units (March 31, 2004 125,219,843 units). In computing diluted net income per unit, 574,190 units were added to the weighted average number of units outstanding during the three months ended March 31, 2005 (March 31, 2004 648,233 units) for the dilutive effect of trust unit options, rights and phantom trust units. For the three months ended March 31, 2005, 1,318,508 (March 31, 2004 691,622) trust unit options and rights were excluded from the diluted net income per unit calculation as their effect is anti-dilutive.
Contributed Surplus
March 31, 2005 | December 31, 2004 | |||||||
Balance, beginning of period |
$ | 1,923 | $ | 189 | ||||
Trust unit rights incentive plan (non-cash expensed) |
695 | 2,264 | ||||||
Phantom trust units (non-cash expensed) |
122 | | ||||||
Trust unit rights incentive plan (non-cash exercised) |
(212 | ) | (530 | ) | ||||
Balance, end of period |
$ | 2,528 | $ | 1,923 | ||||
Trust Unit Option Plan
As at March 31, 2005, options to purchase 658,732 Class B trust units were outstanding (December 31, 2004 845,374) that expire at various dates to June 28, 2009.
March 31, 2005 | December 31, 2004 | |||||||||||||||
Weighted | Weighted | |||||||||||||||
Trust Unit Options | Number | Average | Number | Average | ||||||||||||
Of options | Exercise price | of options | Exercise price | |||||||||||||
Outstanding at beginning of period |
845,374 | $ | 16.97 | 2,014,903 | $ | 17.47 | ||||||||||
Exercised |
(184,242 | ) | $ | 14.31 | (838,789 | ) | $ | 16.82 | ||||||||
Expired |
(2,400 | ) | $ | 15.25 | (325,200 | ) | $ | 20.44 | ||||||||
Cancelled |
| $ | | (5,540 | ) | $ | 16.53 | |||||||||
Outstanding and exercisable at period-end |
658,732 | $ | 17.71 | 845,374 | $ | 16.97 | ||||||||||
PENGROWTH ENERGY TRUST - 23 -
Rights Incentive Plan
As at March 31, 2005, rights to purchase 2,209,153 Class B trust units were outstanding (December 31, 2004 2,011,451) that expire at various dates to March 3, 2010.
March 31, 2005 | December 31, 2004 | |||||||||||||||
Weighted | Weighted | |||||||||||||||
Number | Average | Number | Average | |||||||||||||
Rights Incentive Options | of rights | Exercise price | of rights | Exercise price | ||||||||||||
Outstanding at beginning of period |
2,011,451 | $ | 14.23 | 1,112,140 | $ | 12.20 | ||||||||||
Granted (*) |
482,945 | $ | 18.14 | 1,409,856 | $ | 17.35 | ||||||||||
Exercised |
(225,403 | ) | $ | 13.18 | (456,049 | ) | $ | 13.47 | ||||||||
Cancelled |
(59,840 | ) | $ | 16.14 | (54,496 | ) | $ | 14.19 | ||||||||
Outstanding at period-end |
2,209,153 | $ | 14.86 | 2,011,451 | $ | 14.23 | ||||||||||
Exercisable at period-end |
1,317,437 | $ | 13.57 | 1,037,078 | $ | 12.48 | ||||||||||
(*) Weighted average exercise price of rights granted is based on the exercise price at the date of grant |
The fair value of rights incentive options granted during the three months ended March 31, 2005 was estimated at 15 percent of the exercise price at the date of grant using a modified Black-Scholes option pricing model with the following assumptions: risk-free rate of 3.9 percent, volatility of 22 percent, expected life of five years and adjustments for the estimated distributions and reductions in the exercise price over the life of the right incentive option.
Long Term Incentive Program
Effective January 1, 2005, the Board of Directors approved a Long Term Incentive Plan. Under the Long Term Incentive Plan, Phantom trust units are granted to employees, officers, directors and certain consultants of the Corporation and the Manager. The number of Phantom trust units granted is based on a grant value as a percentage of an individuals base salary and an established weighting of Phantom trust units and/or rights incentive options that is dependent on an individuals position. The Phantom trust units fully vest on the third anniversary year from the date of grant. The Phantom trust units will receive distributions in the form of additional Phantom trust units. The number of Phantom trust units, including any additional units from re-invested distributions at the end of the three year vesting period will be subject to a relative performance test which compares Pengrowths three year average total return to the three year average total return of a peer group of other energy trusts. Upon vesting, the number of Class B trust units issued from treasury may range from zero to one and one-half times the number of Phantom trust units granted.
As at March 31, 2005, 159,644 Phantom trust units were outstanding. The Phantom trust units vest on March 2, 2008.
Number of Phantom | ||||
trust units | ||||
Outstanding, beginning of period |
| |||
Granted |
160,888 | |||
Cancelled
|
(1,244 | ) | ||
Outstanding, end of period |
159,644 | |||
Compensation expense associated with the Phantom trust units was based on the estimated fair value of $18.14 per Phantom trust unit and managements estimate of the number of Phantom trust units to be issued on maturity.
- 24 - PENGROWTH ENERGY TRUST
4. | ASSET RETIREMENT OBLIGATIONS |
For the three | ||||||||
months ended | For the year | |||||||
March 31, | ended December | |||||||
2005 | 31, 2004 | |||||||
Asset retirement obligations, beginning of period |
$ | 171,866 | $ | 102,528 | ||||
Increase in liabilities related to: |
||||||||
Acquisitions |
2,309 | 44,368 | ||||||
Additions |
993 | 2,681 | ||||||
Revisions |
| 16,087 | ||||||
Accretion expense |
3,403 | 10,642 | ||||||
Liabilities settled during the period |
(1,118 | ) | (4,440 | ) | ||||
Asset retirement obligations, end of period |
$ | 177,453 | $ | 171,866 | ||||
5. | DEFERRED CHARGES |
As at | As at | |||||||
March 31 | December 31, | |||||||
2005 | 2004 | |||||||
Imputed interest on note payable (net of
accumulated amortization of $1,905) |
$ | 1,702 | $ | 2,020 | ||||
U.S. debt issue costs (net of accumulated
amortization of $587) |
1,554 | 1,631 | ||||||
$ | 3,256 | $ | 3,651 | |||||
6. | FOREIGN EXCHANGE LOSS (GAIN) |
Three months ended | ||||||||
March 31, 2005 | March 31, 2004 | |||||||
Unrealized foreign exchange loss on
translation of U.S. dollar denominated debt |
$ | 1,520 | $ | 2,960 | ||||
Realized foreign exchange gains |
(160 | ) | (589 | ) | ||||
$ | 1,360 | $ | 2,371 | |||||
The U.S. dollar denominated debt is translated into Canadian dollars at the exchange rate in effect at the balance sheet date. Foreign exchange gains and losses are included in income. | ||||
7. | OTHER CASH FLOW DISCLOSURES | |||
Change in Non-Cash Operating Working Capital |
March 31, 2005 | March 31, 2004 | |||||||
Accounts receivable |
$ | (1,092 | ) | $ | 201 | |||
Inventory |
439 | (358 | ) | |||||
Accounts payable and accrued liabilities |
12,565 | (4,852 | ) | |||||
Due to Pengrowth Management Limited |
(1,899 | ) | 133 | |||||
$ | 10,013 | $ | (4,876 | ) | ||||
Change in Non-Cash Investing Working Capital |
March 31, 2005 | March 31, 2004 | |||||||
Accounts payable for capital accruals |
$ | (3,192 | ) | $ | 4,728 | |||
PENGROWTH ENERGY TRUST - 25 -
Cash Payments |
March 31, 2005 | March 31, 2004 | |||||||
Cash payments made for taxes |
$ | 1,247 | $ | 523 | ||||
Cash payments made for interest |
$ | 1,875 | $ | 343 | ||||
8. | FINANCIAL INSTRUMENTS | |||
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. | ||||
As at March 31, 2005, Pengrowth had fixed the price applicable to future production as follows: | ||||
Crude Oil: |
Volume | Reference | Price | ||||||||||
Remaining Term | (bbl/d) | Point | per bbl | |||||||||
2005 |
||||||||||||
Financial: |
||||||||||||
April 1, 2005 Dec 31, 2005 |
10,000 | WTI(*) | $54.39 Cdn | |||||||||
2006 |
||||||||||||
Financial: |
||||||||||||
Jan 1, 2006 Dec 31, 2006 |
2,000 | WTI (*) | $63.01 Cdn | |||||||||
Natural Gas:
Volume | Reference | Price | ||||||||||
Remaining Term | (mmbtu/d) | Point | per mmbtu | |||||||||
2005 |
||||||||||||
Financial: |
||||||||||||
April 1, 2005 Dec 31, 2005 |
11,000 | Tetco M3(*) | $9.27 Cdn | |||||||||
April 1, 2005 Dec 31, 2005 |
2,500 | Transco Z6(*) | $10.01 Cdn | |||||||||
April 1, 2005 Dec 31, 2005 |
2,500 | NGI Chicago(*) | $9.41 Cdn | |||||||||
May 1, 2005 Dec 31, 2005 |
2,500 | Transco Z6(*) | $10.21 Cdn | |||||||||
May 1, 2005 Dec 31, 2005 |
2,370 | AECO | $8.35 Cdn | |||||||||
2006 |
||||||||||||
Financial: |
||||||||||||
Jan 1, 2006 Dec 31, 2006 |
2,500 | Transco Z6(*) | $10.63 Cdn | |||||||||
Jan 1, 2006 Dec 31, 2006 |
2,370 | AECO | $8.03 Cdn | |||||||||
(*) | Associated Cdn$ / U.S.$ foreign exchange rate has been fixed. |
The estimated fair value of the financial crude oil and natural gas contracts have been determined based on the amounts Pengrowth would receive or pay to terminate the contracts at period-end. At March 31, 2005, the amount Pengrowth would pay to terminate the financial crude oil and natural gas contracts would be $36,407,000 and $4,647,000, respectively. |
- 26 - PENGROWTH ENERGY TRUST
Natural Gas Fixed Price Sales Contract: |
Pengrowth also has a natural gas fixed price physical sales contract outstanding, the details of which are provided below: |
Volume | Price | |||||||
Remaining Term | (mmbtu/d) | per mmbtu (**) | ||||||
2005 to 2009 |
||||||||
April 1, 2005 Oct 31, 2005 |
3,886 | $2.18 Cdn | ||||||
Nov 1, 2005 Oct 31, 2006 |
3,886 | $2.23 Cdn | ||||||
Nov 1, 2006 Oct 31, 2007 |
3,886 | $2.29 Cdn | ||||||
Nov 1, 2007 Oct 31, 2008 |
3,886 | $2.34 Cdn | ||||||
Nov 1, 2008 April 30, 2009 |
3,886 | $2.40 Cdn | ||||||
(**) | Reference price based on AECO |
As at March 31, 2005, the fair value amount Pengrowth would pay to terminate the natural gas fixed price sales contract would be $28,863,000 (December 31, 2004 - $22,282,000). | ||||
Fair Value of Financial Instruments | ||||
The carrying value of financial instruments included in the balance sheet, other than long term debt, the note payable and remediation trust funds, approximate their fair value due to their short maturity. The fair value of the remediation trust funds at March 31, 2005 was approximately $8,647,000 (December 31, 2004 $8,366,000). The fair value of the U.S. dollar denominated debt at March 31, 2005 was approximately $234,904,000 (December 31, 2004 - $238,726,000) based on the changes in the fair value of the underlying U.S. Treasury Bill that was originally used as the basis for determining the coupon rate for each of Pengrowth Corporations notes. The fair value of the note payable at March 31, 2005, approximates its carrying value net of the imputed interest included in deferred charges. | ||||
9. | SUBSEQUENT EVENT | |||
On April 29, 2005, Pengrowth closed an Arrangement Agreement (the Arrangement) with Crispin Energy Inc. (Crispin) whereby Corporation acquired all of the issued and outstanding shares of Crispin on the basis of 0.0725 Class B trust units of EnergyTrust for each share held by Canadian resident shareholders of Crispin and 0.0512 Class A trust units for each share held by non-Canadian resident shareholders of Crispin. Pengrowth anticipates issuing approximately 3.5 million Class B trust units and 0.7 million Class A trust units. |
PENGROWTH ENERGY TRUST - 27 -
Corporate Information
DIRECTORS OF PENGROWTH CORPORATION
Kirby L Hedrick (elected
April 26, 2005) Business Consultant
James S. Kinnear; Chairman
President, Pengrowth
Management Limited
Michael S. Parrett
Business Consultant
A. Terrence Poole (elected April 26, 2005)
Executive Vice-President, Corporate
Strategy and Development,
Nova Chemicals Corporation
William R. Stedman
Chairman and Chief Executive
Officer,
ENTx Capital Corporation
Stanley H. Wong
President, Carbine Resources Ltd.
John B. Zaozirny; Lead
Director Counsel,
McCarthy Tetrault
Director Emeritus
Thomas S. Dobson
President, T.S. Dobson Consultant Ltd.
Francis G. Vetsch
President, Vetsch Resource
Management Ltd.
OFFICERS OF PENGROWTH
CORPORATION
James S. Kinnear
Chairman, President and Chief
Executive Officer
Christopher Webster
Chief Financial
Officer
James J. Emme (subject to
Canadian immigration
approval)
Executive Vice
President
Gordon M. Anderson
Vice President
Henry D. McKinnon
Vice President,
Operations
Lynn Kis
Vice President, Engineering
Charles V. Selby
Vice President and Corporate Secretary
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.
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 equivalent |
|
mmboe*
|
million barrels of oil
equivalent |
|
mmbtu
|
million British thermal units |
|
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 (Energy Trust) Pengrowth Corporation (Corporation) *6 mcf of gas = 1 barrel of oil
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.A / PGF.B
The New York Stock
Exchange:
Symbol: PGH
PENGROWTH ENERGY TRUST
Head Office
Suite 2900, 111 5 Avenue S.W.
Calgary, Alberta T2P 3Y6 Canada
Telephone: (403) 233-0224
Toll-Free: 1 800 223-4122
Facsimile: (403) 265-6251
Email: investorrelations@pengrowth.com
Website: http://www.pengrowth.com
Toronto Office
2315, 200 Bay
Street
Toronto, Ontario M5J 2J2
Canada
Telephone: (416)
362-1748
Toll-Free: 1 888 744-1111
Facsimile: (416) 362-8191
Halifax Office
Purdys Tower 1 Suite 1700
1959 Upper Water Street
Halifax, Nova Scotia B3J 2N2
Canada
Telephone: (902) 425-8778
Facsimile: (902) 425-7887
Contact: Jim MacDonald, General Manager,
East Coast Operations
INVESTOR RELATIONS
For investor relations
enquiries, please contact:
Investor Relations, Calgary
Telephone: (403) 233-0224
Toll-Free: 1 800 223-4122
Facsimile: (403) 294-0051
Email: investorrelations@pengrowth.com
or
Investor Relations, Toronto
Telephone: (416) 362-1748
Toll-Free: 1 888 744-1111
Facsimile: (416) 362-8191
FORM 52-109FT2
CERTIFICATION OF INTERIM FILINGS DURING TRANSITION PERIOD
I, JAMES S. KINNEAR, Chairman, President and Chief Executive Officer of Pengrowth Corporation, certify that:
1. | I have reviewed the interim filings (as this term is defined in Multilateral Instrument 52-109 Certification of Disclosure in Issuers Annual and Interim Filings) of Pengrowth Energy Trust, (the issuer) for the interim period ending March 31, 2005; |
2. | Based on my knowledge, the interim filings do not contain any untrue statement of a material fact or omit to state a material fact required to be stated or that is necessary to make a statement not misleading in light of the circumstances under which it was made, with respect to the period covered by the interim filings; and |
3. | Based on my knowledge, the interim financial statements together with the other financial information included in the interim filings fairly present in all material respects the financial condition, results of operations and cash flows of the issuer, as of the date and for the periods presented in the interim filings. |
DATED April 27, 2005.
James S. Kinnear | ||
Signature | ||
Chairman, President and | ||
Chief Executive Officer | ||
Title |
FORM 52-109FT2
CERTIFICATION OF INTERIM FILINGS DURING TRANSITION PERIOD
I, CHRISTOPHER G. WEBSTER, Chief Financial Officer of Pengrowth Corporation, certify that:
1. | I have reviewed the interim filings (as this term is defined in Multilateral Instrument 52-109 Certification of Disclosure in Issuers Annual and Interim Filings) of Pengrowth Energy Trust, (the issuer) for the interim period ending March 31, 2005; |
2. | Based on my knowledge, the interim filings do not contain any untrue statement of a material fact or omit to state a material fact required to be stated or that is necessary to make a statement not misleading in light of the circumstances under which it was made, with respect to the period covered by the interim filings; and |
3. | Based on my knowledge, the interim financial statements together with the other financial information included in the interim filings fairly present in all material respects the financial condition, results of operations and cash flows of the issuer, as of the date and for the periods presented in the interim filings. |
DATED April 27, 2005.
Christopher G. Webster | ||
Signature | ||
Chief Financial Officer | ||
Title |