1. | Press Release announcing third quarter 2005 results. |
PENGROWTH ENERGY TRUST by its administrator PENGROWTH CORPORATION |
||||
November 4, 2005 | By: | /s/ Gordon M. Anderson | ||
Name: | Gordon M. Anderson | |||
Title: | Vice President |
Attention: | Financial Editors | Stock Symbol: (PGF.A / PGF.B)TSX; | ||
(PGH) NYSE |
Three Months ended | Nine Months ended | |||||||||||||||||||||||
September 30 | % | September 30 | % | |||||||||||||||||||||
($thousands, except per unit amounts) | 2005 | 2004 | Change | 2005 | 2004 | Change | ||||||||||||||||||
INCOME STATEMENT |
||||||||||||||||||||||||
Oil and gas sales |
$ | 304,484 | $ | 226,514 | 34 | % | $ | 797,587 | $ | 592,569 | 35 | % | ||||||||||||
Net income |
$ | 100,243 | $ | 51,271 | 96 | % | $ | 209,663 | 122,607 | 71 | % | |||||||||||||
Net income per unit |
$ | 0.63 | $ | 0.38 | 66 | % | $ | 1.34 | $ | 0.93 | 44 | % | ||||||||||||
Cash generated from operations |
$ | 158,976 | $ | 116,258 | 37 | % | $ | 421,482 | $ | 310,880 | 36 | % | ||||||||||||
Cash generated from operations per unit |
$ | 1.00 | $ | 0.86 | 16 | % | $ | 2.70 | $ | 2.35 | 15 | % | ||||||||||||
Distributable cash* |
$ | 162,009 | $ | 104,304 | 55 | % | $ | 423,860 | $ | 296,220 | 43 | % | ||||||||||||
Distributable cash per unit* |
$ | 1.02 | $ | 0.77 | 32 | % | $ | 2.71 | $ | 2.24 | 21 | % | ||||||||||||
Distributions |
$ | 109,853 | $ | 93,870 | 17 | % | $ | 326,119 | $ | 266,595 | 22 | % | ||||||||||||
Distributions paid or declared per unit |
$ | 0.69 | $ | 0.67 | 3 | % | $ | 2.07 | $ | 1.94 | 7 | % | ||||||||||||
Weighted average number of units outstanding |
158,789 | 135,906 | 17 | % | 156,318 | 132,213 | 18 | % | ||||||||||||||||
BALANCE SHEET |
||||||||||||||||||||||||
Working capital |
$ | (77,528 | ) | $ | (311,352 | ) | (75 | )% | $ | (77,528 | ) | $ | (311,352 | ) | (75 | )% | ||||||||
Property, plant and equipment and other assets |
$ | 2,090,399 | $ | 1,985,737 | 5 | % | $ | 2,090,399 | $ | 1,985,737 | 5 | % | ||||||||||||
Long-term debt |
$ | 422,220 | $ | 355,320 | 19 | % | $ | 422,220 | $ | 355,320 | 19 | % | ||||||||||||
Unitholders equity |
$ | 1,467,859 | $ | 1,235,575 | 19 | % | $ | 1,467,859 | $ | 1,235,575 | 19 | % | ||||||||||||
Unitholders equity per unit |
$ | 9.22 | $ | 9.06 | 2 | % | $ | 9.22 | $ | 9.06 | 2 | % | ||||||||||||
Number of units outstanding at period end |
159,263 | 136,449 | 17 | % | 159,263 | 136,449 | 17 | % | ||||||||||||||||
DAILY PRODUCTION |
||||||||||||||||||||||||
Crude oil (barrels) |
20,660 | 20,735 | 0 | % | 20,670 | 21,051 | (2 | )% | ||||||||||||||||
Heavy oil (barrels) |
5,405 | 6,507 | (17 | )% | 5,695 | 2,799 | 103 | % | ||||||||||||||||
Natural gas (thousands of cubic feet) |
164,288 | 166,618 | (1 | )% | 158,426 | 140,133 | 13 | % | ||||||||||||||||
Natural gas liquids (barrels) |
5,448 | 5,139 | 6 | % | 5,885 | 5,246 | 12 | % | ||||||||||||||||
Total production (boe) |
58,894 | 60,151 | (2 | )% | 58,654 | 52,452 | 12 | % | ||||||||||||||||
TOTAL PRODUCTION (mboe) |
5,418 | 5,534 | (2 | )% | 16,013 | 14,372 | 11 | % | ||||||||||||||||
PRODUCTION PROFILE |
||||||||||||||||||||||||
Crude oil |
35 | % | 34 | % | 35 | % | 40 | % | ||||||||||||||||
Heavy oil |
9 | % | 11 | % | 10 | % | 5 | % | ||||||||||||||||
Natural gas |
47 | % | 46 | % | 45 | % | 45 | % | ||||||||||||||||
Natural gas liquids |
9 | % | 9 | % | 10 | % | 10 | % | ||||||||||||||||
AVERAGE REALIZED PRICES |
||||||||||||||||||||||||
Crude oil (per barrel) |
$ | 63.95 | $ | 45.15 | 42 | % | $ | 58.31 | $ | 42.71 | 37 | % | ||||||||||||
Heavy oil (per barrel) |
$ | 47.74 | $ | 37.96 | 26 | % | $ | 33.82 | $ | 36.25 | (7 | )% | ||||||||||||
Natural gas (per mcf) |
$ | 8.57 | $ | 6.36 | 35 | % | $ | 7.61 | $ | 6.72 | 13 | % | ||||||||||||
Natural gas liquids (per barrel) |
$ | 57.75 | $ | 42.33 | 36 | % | $ | 52.59 | $ | 40.21 | 31 | % | ||||||||||||
Average realized price per boe |
$ | 56.07 | $ | 40.90 | 37 | % | $ | 49.66 | $ | 41.05 | 21 | % |
* | See the section entitled Non-GAAP Financial Measures |
Three Months ended | Nine Months ended | |||||||||||||||
September 30 | September 30 | |||||||||||||||
(thousands, except per unit amounts) | 2005 | 2004 | 2005 | 2004 | ||||||||||||
TRUST UNIT TRADING (Class A) |
||||||||||||||||
PGH (NYSE) after unit re-class* |
||||||||||||||||
High |
$ | 25.75 | U.S. | $ | 18.94 | U.S. | $ | 25.75 | U.S. | $ | 18.94 | U.S. | ||||
Low |
$ | 21.55 | U.S. | $ | 14.40 | U.S. | $ | 18.11 | U.S. | $ | 14.40 | U.S. | ||||
Close |
$ | 25.42 | U.S. | $ | 17.93 | U.S. | $ | 25.42 | U.S. | $ | 17.93 | U.S. | ||||
Value |
$ | 340,318 | U.S. | $ | 350,374 | U.S. | $ | 1,190,435 | U.S. | $ | 350,374 | U.S. | ||||
Volume (thousands of units) |
14,502 | 21,200 | 55,276 | 21,200 | ||||||||||||
PGF.A (TSX)* |
||||||||||||||||
High |
$ | 30.10 | $ | 24.19 | $ | 30.10 | $ | 24.19 | ||||||||
Low |
$ | 26.30 | $ | 19.10 | $ | 22.15 | $ | 19.10 | ||||||||
Close |
$ | 29.50 | $ | 22.67 | $ | 29.50 | $ | 22.67 | ||||||||
Value |
$ | 58,000 | $ | 35,524 | $ | 157,672 | $ | 35,524 | ||||||||
Volume (thousands of units) |
2,047 | 1,672 | 5,894 | 1,672 | ||||||||||||
TRUST UNIT TRADING (Class B) |
||||||||||||||||
PGF.B (TSX)* |
||||||||||||||||
High |
$ | 21.26 | $ | 20.00 | $ | 21.26 | $ | 20.00 | ||||||||
Low |
$ | 18.25 | $ | 18.03 | $ | 16.10 | $ | 18.03 | ||||||||
Close |
$ | 20.58 | $ | 18.87 | $ | 20.58 | $ | 18.87 | ||||||||
Value |
$ | 441,039 | $ | 105,650 | $ | 1,327,210 | $ | 105,650 | ||||||||
Volume (thousands of units) |
22,738 | 5,588 | 71,326 | 5,588 | ||||||||||||
TRUST UNIT TRADING (before unit re-class) |
||||||||||||||||
PGH (NYSE) before unit re-class* |
||||||||||||||||
High |
$ | 14.95 | U.S. | $ | 14.95 | U.S. | ||||||||||
Low |
$ | 13.84 | U.S. | $ | 11.62 | U.S. | ||||||||||
Close |
$ | 14.64 | U.S. | $ | 14.64 | U.S. | ||||||||||
Value |
$ | 84,506 | U.S. | $ | 905,950 | U.S. | ||||||||||
Volume (thousands of units) |
5,797 | 64,890 | ||||||||||||||
PGF. UN (TSX)* |
||||||||||||||||
High |
$ | 19.75 | $ | 21.25 | ||||||||||||
Low |
$ | 18.52 | $ | 15.55 | ||||||||||||
Close |
$ | 19.42 | $ | 19.42 | ||||||||||||
Value |
$ | 68,531 | $ | 964,766 | ||||||||||||
Volume (thousands of units) |
3,554 | 52,319 |
* | 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. |
Daily Production | Three months ended | Nine months ended | ||||||||||||||||||
Sept 30, 2005 | Jun 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | ||||||||||||||||
Light crude oil (bbls) |
20,660 | 20,906 | 20,735 | 20,670 | 21,051 | |||||||||||||||
Heavy oil (bbls) |
5,405 | 5,641 | 6,507 | 5,695 | 2,799 | |||||||||||||||
Natural gas (mcf) |
164,288 | 153,423 | 166,618 | 158,426 | 140,133 | |||||||||||||||
Natural gas liquids (bbls) |
5,448 | 5,870 | 5,139 | 5,885 | 5,246 | |||||||||||||||
Total boe per day |
58,894 | 57,988 | 60,151 | 58,654 | 52,452 | |||||||||||||||
Average realized prices Cdn$ | Three months ended | Nine months ended | ||||||||||||||||||
(after the impact of hedging) | Sept 30, 2005 | Jun 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | |||||||||||||||
Light crude oil (per bbl) |
$ | 63.95 | $ | 56.44 | $ | 45.15 | $ | 58.31 | $ | 42.71 | ||||||||||
Heavy oil (per bbl) |
47.74 | 30.32 | 37.96 | 33.82 | 36.25 | |||||||||||||||
Natural gas (per mcf) |
8.57 | 7.34 | 6.36 | 7.61 | 6.72 | |||||||||||||||
Natural gas liquids (per bbl) |
57.75 | 50.03 | 42.33 | 52.59 | 40.21 | |||||||||||||||
Total per boe |
$ | 56.07 | $ | 47.79 | $ | 40.90 | $ | 49.66 | $ | 41.05 | ||||||||||
Volume | Price | |||||||||||
Remaining Term | (bbl per day) | Reference Point | per bbl | |||||||||
2005 Financial |
||||||||||||
Oct 1, 2005
Dec 31, 2005 |
10,000 | WTI (1) | $54.39 Cdn | |||||||||
2006 Financial |
||||||||||||
Jan 1, 2006
Dec 31, 2006 |
4,000 | WTI (1) | $64.08 Cdn |
Volume | Price | |||||||||
Remaining Term | (mmbtu per day) | Reference Point | per mmbtu | |||||||
2005 Financial |
||||||||||
Oct 1, 2005
Dec 31, 2005 |
11,000 | Tetco M3 (1) | $ | 9.27 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
5,000 | Transco Z6 (1) | $ | 10.11 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
2,500 | NGI Chicago(1) | $ | 9.41 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
2,500 | Nymex (1) | $ | 14.07 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
2,370 | AECO | $ | 8.35 Cdn | ||||||
2006 Financial |
||||||||||
Jan 1, 2006
Dec 31,2006 |
2,500 | Transco Z6 (1) | $ | 10.63 Cdn | ||||||
Jan 1, 2006
Dec 31, 2006 |
2,370 | AECO | $ | 8.03 Cdn | ||||||
Jan 1, 2006
Mar 31, 2006 |
2,500 | Nymex (1) | $ | 14.56 Cdn |
(1) | Associated Cdn$/US$ foreign exchange rate has been fixed. |
Combined Netbacks ($ per boe) | Three months ended | Nine months ended | ||||||||||||||
Sept 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | |||||||||||||
Sales price |
$ | 56.07 | $ | 40.90 | $ | 49.66 | $ | 41.05 | ||||||||
Other production income |
0.13 | 0.02 | 0.15 | 0.18 | ||||||||||||
56.20 | 40.92 | 49.81 | 41.23 | |||||||||||||
Processing and other income |
0.39 | 0.53 | 0.86 | 0.70 | ||||||||||||
Royalties |
(10.60 | ) | (8.88 | ) | (9.11 | ) | (7.73 | ) | ||||||||
Operating costs |
(10.59 | ) | (8.51 | ) | (9.80 | ) | (8.18 | ) | ||||||||
Transportation costs |
(0.36 | ) | (0.44 | ) | (0.35 | ) | (0.40 | ) | ||||||||
Amortization of injectants |
(1.10 | ) | (0.85 | ) | (1.08 | ) | (1.02 | ) | ||||||||
Operating netback |
$ | 33.94 | $ | 22.77 | $ | 30.33 | $ | 24.60 | ||||||||
Light Crude Netbacks ($ per bbl) | Three months ended | Nine months ended | ||||||||||||||
Sept 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | |||||||||||||
Sales price |
$ | 63.95 | $ | 45.15 | $ | 58.31 | $ | 42.71 | ||||||||
Other production income |
0.37 | 0.06 | 0.44 | 0.44 | ||||||||||||
64.32 | 45.21 | 58.75 | 43.15 | |||||||||||||
Processing and other income |
0.64 | 0.25 | 0.51 | 0.45 | ||||||||||||
Royalties |
(11.03 | ) | (10.29 | ) | (9.39 | ) | (6.96 | ) | ||||||||
Operating costs |
(12.85 | ) | (9.38 | ) | (11.58 | ) | (9.34 | ) | ||||||||
Transportation costs |
(0.29 | ) | (0.23 | ) | (0.30 | ) | (0.23 | ) | ||||||||
Amortization of injectants |
(3.14 | ) | (2.46 | ) | (3.07 | ) | (2.55 | ) | ||||||||
Operating netback |
$ | 37.65 | $ | 23.10 | $ | 34.92 | $ | 24.52 | ||||||||
Heavy Oil Netbacks ($ per bbl) | Three months ended | Nine months ended | ||||||||||||||
Sept 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | |||||||||||||
Sales price |
$ | 47.74 | $ | 37.96 | $ | 33.82 | $ | 36.25 | ||||||||
Processing and other income |
(0.83 | ) | | 0.24 | | |||||||||||
Royalties |
(8.00 | ) | (5.55 | ) | (5.03 | ) | (5.35 | ) | ||||||||
Operating costs |
(16.30 | ) | (11.20 | ) | (16.95 | ) | (10.14 | ) | ||||||||
Operating netback |
$ | 22.61 | $ | 21.21 | $ | 12.08 | $ | 20.76 | ||||||||
Natural Gas Netbacks ($ per mcf) | Three months ended | Nine months ended | ||||||||||||||
Sept 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | |||||||||||||
Sales price |
$ | 8.57 | $ | 6.36 | $ | 7.61 | $ | 6.72 | ||||||||
Processing and other income |
0.09 | 0.16 | 0.24 | 0.19 | ||||||||||||
Royalties |
(1.47 | ) | (1.27 | ) | (1.36 | ) | (1.22 | ) | ||||||||
Operating costs |
(1.31 | ) | (1.22 | ) | (1.19 | ) | (1.15 | ) | ||||||||
Transportation costs |
(0.09 | ) | (0.13 | ) | (0.09 | ) | (0.11 | ) | ||||||||
Operating netback |
$ | 5.79 | $ | 3.90 | $ | 5.21 | $ | 4.43 | ||||||||
NGL Netbacks ($ per bbl) | Three months ended | Nine months ended | ||||||||||||||
Sept 30, 2005 | Sept 30, 2004 | Sept 30, 2005 | Sept 30, 2004 | |||||||||||||
Sales price |
$ | 57.75 | $ | 42.33 | $ | 52.59 | $ | 40.21 | ||||||||
Royalties |
(20.57 | ) | (14.19 | ) | (16.27 | ) | (14.07 | ) | ||||||||
Operating costs |
(10.13 | ) | (8.07 | ) | (8.65 | ) | (7.95 | ) | ||||||||
Transportation costs |
| (0.10 | ) | | (0.10 | ) | ||||||||||
Operating netback |
$ | 27.05 | $ | 19.97 | $ | 27.67 | $ | 18.09 | ||||||||
($thousands, except per unit amounts) | Three months ended Sept 30 | Nine months ended Sept 30 | ||||||||||||||
2005 | 2004 | 2005 | 2004 | |||||||||||||
Cash generated from operations |
158,976 | 116,258 | 421,482 | 310,880 | ||||||||||||
Change in non-cash operating working capital |
(789 | ) | (9,857 | ) | (1,840 | ) | (9,749 | ) | ||||||||
Change in deferred injectants |
892 | (1,663 | ) | 2,854 | (2,482 | ) | ||||||||||
Change in remediation trust funds |
(272 | ) | (276 | ) | (803 | ) | (949 | ) | ||||||||
Change in deferred charges |
2,818 | (473 | ) | 2,028 | (1,420 | ) | ||||||||||
Other |
384 | 315 | 139 | (60 | ) | |||||||||||
Distributable cash |
162,009 | 104,304 | 423,860 | 296,220 | ||||||||||||
Allocation of Distributable Cash |
||||||||||||||||
Cash withheld |
52,156 | 10,434 | 97,741 | 29,625 | ||||||||||||
Distributions paid or declared |
109,853 | 93,870 | 326,119 | 266,595 | ||||||||||||
Distributable cash |
162,009 | 104,304 | 423,860 | 296,220 | ||||||||||||
Distributable cash per unit |
1.02 | 0.77 | 2.71 | 2.24 | ||||||||||||
Distributions paid or declared per unit |
0.69 | 0.67 | 2.07 | 1.94 | ||||||||||||
Payout ratio |
69 | % | 81 | % | 77 | % | 86 | % | ||||||||
(000s) | ||||
Class A trust units |
77,524 | |||
Class B trust units |
81,817 | |||
Undeclared trust units |
43 | |||
Total |
159,384 | |||
(000s) | ||||
Trust unit options |
357 | |||
Rights incentive options. |
1,554 | |||
Deferred entitlement trust units |
150 | |||
2005 | ||||||||||||
Q1 | Q2 | Q3 | ||||||||||
Oil and gas sales ($ 000s) |
239,913 | 253,189 | 304,484 | |||||||||
Net income ($ 000s) |
56,314 | 53,106 | 100,243 | |||||||||
Net income per unit ($) |
0.37 | 0.34 | 0.63 | |||||||||
Net income per unit diluted ($) |
0.37 | 0.34 | 0.63 | |||||||||
Distributable cash ($ 000s) |
127,804 | 134,047 | 162,009 | |||||||||
Actual distributions paid or declared per unit ($) |
0.69 | 0.69 | 0.69 | |||||||||
Daily production (boe) |
59,082 | 57,988 | 58,894 | |||||||||
Total production (mboe) |
5,317 | 5,277 | 5,418 | |||||||||
Average realized price per boe ($ per boe) |
44.97 | 47.79 | 56.07 | |||||||||
Operating netback per boe ($ per boe) |
27.70 | 29.26 | 33.94 |
2004 | ||||||||||||||||
Q1 | Q2 | Q3 | Q4 | |||||||||||||
Oil and gas sales ($000s) |
168,771 | 197,284 | 226,514 | 223,183 | ||||||||||||
Net income ($000s) |
38,652 | 32,684 | 51,271 | 31,138 | ||||||||||||
Net income per unit ($) |
0.31 | 0.24 | 0.38 | 0.23 | ||||||||||||
Net income per unit diluted ($) |
0.31 | 0.24 | 0.38 | 0.23 | ||||||||||||
Distributable cash ($000s) |
92,895 | 99,021 | 104,304 | 104,598 | ||||||||||||
Actual distributions paid or declared per unit ($) |
0.63 | 0.64 | 0.67 | 0.69 | ||||||||||||
Daily production (boe) |
45,668 | 51,451 | 60,151 | 57,425 | ||||||||||||
Total production (mboe) |
4,156 | 4,682 | 5,534 | 5,283 | ||||||||||||
Average realized price per boe ($ per boe) |
40.37 | 41.83 | 40.90 | 42.08 | ||||||||||||
Operating netback per boe ($ per boe) |
25.71 | 25.71 | 22.77 | 24.31 |
2003 | ||||||||||||||||
Q1 | Q2 | Q3 | Q4 | |||||||||||||
Oil and gas sales ($ 000s) |
207,891 | 171,836 | 165,601 | 157,404 | ||||||||||||
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) |
108,025 | 79,695 | 81,057 | 77,122 | ||||||||||||
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) |
45.21 | 38.60 | 36.65 | 35.78 | ||||||||||||
Operating netback per boe ($ per boe) |
26.50 | 21.11 | 20.54 | 20.43 |
| Mr. Larry B. Strong has been appointed Vice President, Geosciences and an Officer of Pengrowth Corporation. He will focus on exploitation and exploration opportunities on Pengrowths existing land base and will add value in conjunction with new acquisitions. Mr. Strong is a highly qualified geologist with both solid management and business experience. Mr. Strong brings over 20 years experience in Earth Sciences beginning his career as a Petroleum Geologist/Geophysicist with Chevron Canada Resources. Prior to joining Pengrowth Mr. Strong served in senior geosciences roles at NCE Resources Group and Waterous & Co. and most recently served as an Officer and Vice President of Geosciences at Petrofund Corporation. Mr. Strong holds a Bachelor of Science (Specialist) in Geology and a Minor in Computer Science from Brandon University. | ||
| Mr. William Christensen who is presently consulting to Pengrowth will become Vice President, Strategic Planning and Reservoir Exploitation an Officer of Pengrowth Corporation upon Canadian immigration approval. Mr. Christensens responsibilities will include a comprehensive review of past acquisitions and the effectiveness of Pengrowths exploitation and development programs as a basis for planning effective future initiatives to enhance unitholder value. Mr. Christensen has over 25 years in the energy sector including broad international experience, both in operations and the completion of transactions. Prior to a recent relocation to Houston, Mr. Christensen served as Vice President Planning with Northrock Resources. Before joining Northrock, Mr. Christensen served in several capacities during a long and varied career with Unocal Corporation. Mr. Christensen holds a Masters in Business Administration from UCLA and a Bachelor of Science in Mechanical Engineering from Oregon State University. | ||
| Mr. James Causgrove has been appointed Vice President, Production and Operations and an Officer of Pengrowth Corporation. He will have broad responsibilities for the operating activities of Pengrowth Corporation and Pengrowths ongoing development and growth. Mr. Causgrove has over 25 years of experience with Chevron, where he most recently held the position of Manager, New Growth Opportunities Group and Senior Vice President and Chief Operating Officer of Central Alberta Midstream. Mr. Causgrove has a broad operational background in drilling, production engineering and midstream areas across the Western Canadian Sedimentary Basin as well as significant experience in the property divestiture market and the analysis of potential corporate and acquisitions and divestitures, including the recent sale of Central Alberta Midstream. Mr. Causgrove holds a Bachelor of Science in Chemical Engineering and is a registered professional engineer. |
| Does the tax advantage of FTEs relative to public corporations have a significant impact on how businesses are organized in Canada? | ||
| Have FTEs had a significant impact on tax revenues? Is there potential for revenue losses to grow in the years to come? | ||
| What impacts are FTEs having on investment decision and the allocation of capital in Canada? Is the overall impact on the economy positive or negative? | ||
| Given the important role that tax-exempt investors play in Canadian capital markets, and could play in the FTE market, what impact could this have on government revenues and economic efficiency? | ||
| Overall, are there public policy concerns about FTEs and how the tax system influences their existence and, if so, what actions would be considered to address these concerns? |
| Successfully drilled one oil well at Oak Baldonnel (100 percent working interest) and testing is currently underway. | ||
| Completed Reservoir Simulation on Oak Cecil C Pool. Identified an infill drilling opportunity for the fourth quarter. | ||
| Delineated Notikewin play over Bulrush area for first quarter 2006 activity. | ||
| Sirius/Prespatou Gas Facility was brought online in July (90 percent working interest) with 4.0 mmcf per day gross throughput. | ||
| Two non-operated recompletions (33.33 percent working interest) yielded 1.0 mmcf per day at Bonanza and will be tied-in during the fourth quarter. | ||
| Two parcels were purchased at Crown land sales for prospects to be drilled in 2006. |
| A 100 percent working interest well in the West Pembina area came on production at 1.0 mmcf per day. | ||
| A non-operated gas well (20 percent working interest) was tested in the Notikewin formation at 320 mcf per day. | ||
| Pengrowth increased its undeveloped land position at West Pembina during the quarter. | ||
| During the third quarter, 44 wells of a 52 well program for the Milk River and Medicine Hat formations at Princess, Alberta were drilled, completed, fracture stimulated and tied-in (mainly in the third quarter). These wells should come on production November 1, 2005. The drilling of the remaining eight wells was deferred to 2006. | ||
| Wells which came on during the third quarter include two Belly River (284 mcf and 250 mcf per day), one Ellerslie (460 mcf per day) and one additional well was drilled and is awaiting completion. | ||
| Imperial Oil Resources served notice of their intent to commence the drilling of a gas well at Quirk Creek. Pengrowth is participating in this well with a working interest of 68 percent. |
| A new miscible pattern is beginning to see response with incremental oil production of 283 barrels of oil per day. | ||
| One producer reactivation added 25 barrels of oil per day. | ||
| Pengrowth acquired 4,000 acres at Crown land sales on parcels directly offsetting the Judy Creek A & B pools. | ||
| Two farm-in wells were drilled by industry partners. | ||
| The Judy Creek Plant Acid Gas Injection project is underway with the testing of a prospective injection well. The acid gas compressor is on order and Alberta Environment has granted an extension to the current plant license to July, 2006 to allow time for the implementation of this project. |
| One well drilled at a Gething location was dry and abandoned. |
| Fourteen oil wells were drilled in the third quarter. These were a combination of horizontals and vertical re-entries for horizontal production. Production response to the drilling and CO2 injection programs has been favourable. |
| At the Hanlan Unit and Hanlan Robb Gas Plant one gas well was drilled and expected onstream in September, 2005. The initial in-line flow test (3.3 mmcf per day gross) is now being analyzed by the operator and is slated to come onstream in February 2006. |
| Two wells were rig released from drilling in the third quarter. Plans are in place to test these multi-legged horizontal oil wells in the east platform area. The operator has not yet reported results. |
| The final three oil producers in a seven well drilling program came onstream in the third quarter. The last two of a four oil well reactivation program came onstream in July. |
| Three development wells were drilled in East Bodo, one of which is a horizontal well. These wells were drilled to change the waterflood pattern from an inverted nine spot to a line drive. Pengrowth expects initial primary production for up to a year before conversion to a line drive. | ||
| A non-operated development well was drilled and cased at South Bodo (35 percent working interest). | ||
| One development well in Cosine and one development well in Plover are expected to be completed as gas wells with the potential for up to four development infill opportunities. All are expected to be tied-in in the fourth quarter of 2005. | ||
| The polymer skid for the East Bodo polymer pilot has been ordered. It is now under construction with delivery, installation and polymer injection to start in 2006. | ||
| A large 3-D seismic program in the East Bodo area has been initiated for development potential and possible surveillance of the East Bodo waterflood and polymer pilot. |
| Third quarter gross raw gas production from the five SOEP fields, Thebaud, Venture, North Triumph, Alma and South Venture averaged 432 mmcf per day gross (36.3 mmcf per day net). | ||
| Monthly raw production for July, August, and September was 414 mmcf per day gross (36.3 mmcf per day net), 446 mmcf per day gross (37.5 mmcf per day net) and 435 mmcf per day gross (36.5 mmcf per day net), respectively. | ||
| Pengrowth also had a 65,000 bbl condensate sale in August. | ||
| The Venture 7 (V7) development well was spudded on August 5, 2005. As of September 30, 2005 the V7 well was at a drilled depth of 5,666 meters with a projected total depth of 6,444 meters. The V7 well is expected to start production by year-end. |
| Fabrication of the compression topsides, jacket and piles is approximately 40 percent complete. | ||
| Cut-in work in preparation for the compressor installation is in progress at the Thebaud facilities. | ||
| In-service date for the compressor is scheduled for late 2006. |
As at | As at | |||||||
September 30 | December 31 | |||||||
(Stated in thousands of dollars) | 2005 | 2004 | ||||||
(unaudited) | ||||||||
ASSETS |
||||||||
CURRENT ASSETS |
||||||||
Cash |
$ | 997 | $ | | ||||
Accounts receivable |
127,392 | 104,228 | ||||||
Inventory |
| 439 | ||||||
128,389 | 104,667 | |||||||
REMEDIATION TRUST FUND |
9,113 | 8,309 | ||||||
DEFERRED
CHARGES (Note 6) |
5,679 | 3,651 | ||||||
GOODWILL (Note 3) |
183,385 | 170,619 | ||||||
PROPERTY, PLANT AND EQUIPMENT
AND OTHER ASSETS |
2,090,399 | 1,989,288 | ||||||
$ | 2,416,965 | $ | 2,276,534 | |||||
LIABILITIES AND UNITHOLDERS EQUITY |
||||||||
CURRENT LIABILITIES |
||||||||
Bank indebtedness |
$ | | $ | 4,214 | ||||
Accounts payable and accrued liabilities |
107,089 | 80,423 | ||||||
Distributions payable to unitholders |
73,323 | 70,456 | ||||||
Due to Pengrowth Management Limited |
5,096 | 7,325 | ||||||
Note payable |
15,000 | 15,000 | ||||||
Current portion of contract liabilities |
5,409 | 5,795 | ||||||
205,917 | 183,213 | |||||||
NOTE PAYABLE |
20,000 | 20,000 | ||||||
CONTRACT LIABILITIES |
14,256 | 18,216 | ||||||
LONG-TERM DEBT (Note 2) |
422,220 | 345,400 | ||||||
ASSET RETIREMENT OBLIGATIONS (Note 5) |
183,452 | 171,866 | ||||||
FUTURE INCOME TAXES |
103,261 | 75,628 | ||||||
TRUST
UNITHOLDERS EQUITY |
||||||||
Trust Unitholders capital (Note 4) |
2,504,125 | 2,383,284 | ||||||
Contributed surplus (Note 4) |
3,186 | 1,923 | ||||||
Accumulated earnings |
936,720 | 727,057 | ||||||
Accumulated distributions paid or declared |
(1,976,172 | ) | (1,650,053 | ) | ||||
1,467,859 | 1,462,211 | |||||||
SUBSEQUENT EVENT (Note 10) |
||||||||
$ | 2,416,965 | $ | 2,276,534 | |||||
Three months ended | Nine months ended | |||||||||||||||||||
(Stated in thousands of dollars) | September 30 | September 30 | ||||||||||||||||||
(Unaudited) | 2005 | 2004 | 2005 | 2004 | ||||||||||||||||
REVENUES |
||||||||||||||||||||
Oil and gas sales |
$ | 304,484 | $ | 226,514 | $ | 797,587 | $ | 592,569 | ||||||||||||
Processing and other income |
2,039 | 2,871 | 11,771 | 8,495 | ||||||||||||||||
Royalties, net of incentives |
(57,414 | ) | (49,207 | ) | (145,879 | ) | (111,274 | ) | ||||||||||||
249,109 | 180,178 | 663,479 | 489,790 | |||||||||||||||||
Interest and other income |
74 | 78 | 1,916 | 1,204 | ||||||||||||||||
NET REVENUE |
249,183 | 180,256 | 665,395 | 490,994 | ||||||||||||||||
EXPENSES |
||||||||||||||||||||
Operating |
57,371 | 47,163 | 156,885 | 117,149 | ||||||||||||||||
Transportation |
1,969 | 2,423 | 5,584 | 5,797 | ||||||||||||||||
Amortization of injectants for miscible floods |
5,969 | 4,694 | 17,322 | 14,721 | ||||||||||||||||
Interest |
5,644 | 8,650 | 16,786 | 20,582 | ||||||||||||||||
General and administrative |
7,559 | 6,142 | 21,765 | 17,538 | ||||||||||||||||
Management fee |
3,537 | 2,493 | 11,588 | 10,317 | ||||||||||||||||
Foreign exchange gain (Note 7) |
(12,255 | ) | (13,688 | ) | (8,470 | ) | (6,651 | ) | ||||||||||||
Depletion and depreciation |
73,541 | 69,323 | 213,594 | 177,923 | ||||||||||||||||
Accretion (Note 5) |
3,578 | 3,093 | 10,531 | 7,465 | ||||||||||||||||
146,913 | 130,293 | 445,585 | 364,841 | |||||||||||||||||
NET INCOME BEFORE TAXES |
102,270 | 49,963 | 219,810 | 126,153 | ||||||||||||||||
INCOME TAX EXPENSE (RECOVERY) |
||||||||||||||||||||
Capital |
2,116 | 1,474 | 4,722 | 2,849 | ||||||||||||||||
Future |
(89 | ) | (2,782 | ) | 5,425 | 697 | ||||||||||||||
2,027 | (1,308 | ) | 10,147 | 3,546 | ||||||||||||||||
NET INCOME |
$ | 100,243 | $ | 51,271 | $ | 209,663 | $ | 122,607 | ||||||||||||
Accumulated earnings, beginning of period |
836,477 | 644,648 | 727,057 | 573,312 | ||||||||||||||||
ACCUMULATED EARNINGS, END OF PERIOD |
$ | 936,720 | $ | 695,919 | $ | 936,720 | $ | 695,919 | ||||||||||||
NET INCOME PER UNIT (Note 4) |
Basic | $ | 0.631 | $ | 0.377 | $ | 1.341 | $ | 0.927 | |||||||||||
Diluted | $ | 0.629 | $ | 0.376 | $ | 1.337 | $ | 0.923 | ||||||||||||
Three months ended | Nine months ended | |||||||||||||||
(Stated in thousands of dollars) | September 30 | September 30 | ||||||||||||||
(Unaudited) | 2005 | 2004 | 2005 | 2004 | ||||||||||||
CASH PROVIDED BY (USED FOR): |
||||||||||||||||
OPERATING |
||||||||||||||||
Net income |
$ | 100,243 | $ | 51,271 | $ | 209,663 | $ | 122,607 | ||||||||
Depletion, depreciation and accretion |
77,119 | 72,416 | 224,125 | 185,388 | ||||||||||||
Future income taxes |
(89 | ) | (2,782 | ) | 5,425 | 697 | ||||||||||
Contract liability amortization |
(1,448 | ) | (1,555 | ) | (4,346 | ) | (2,379 | ) | ||||||||
Amortization of injectants |
5,969 | 4,694 | 17,322 | 14,721 | ||||||||||||
Purchase of injectants |
(6,861 | ) | (3,031 | ) | (20,176 | ) | (12,239 | ) | ||||||||
Expenditures on remediation |
(1,676 | ) | (1,199 | ) | (4,300 | ) | (4,029 | ) | ||||||||
Unrealized foreign exchange gain (Note 7) |
(12,860 | ) | (14,440 | ) | (8,180 | ) | (6,980 | ) | ||||||||
Trust unit based compensation |
608 | 554 | 2,137 | 1,925 | ||||||||||||
Deferred charges |
(4,283 | ) | | (4,283 | ) | | ||||||||||
Amortization of deferred charges |
1,465 | 473 | 2,255 | 1,420 | ||||||||||||
Changes in non-cash operating working capital (Note 8) |
789 | 9,857 | 1,840 | 9,749 | ||||||||||||
158,976 | 116,258 | 421,482 | 310,880 | |||||||||||||
FINANCING |
||||||||||||||||
Distributions |
(109,455 | ) | (88,293 | ) | (323,252 | ) | (251,822 | ) | ||||||||
Change in long-term debt, net |
(26,428 | ) | 14,680 | 64,541 | 339,680 | |||||||||||
Proceeds from issue of trust units |
15,477 | 13,036 | 32,007 | 218,205 | ||||||||||||
(120,406 | ) | (60,577 | ) | (226,704 | ) | 306,063 | ||||||||||
INVESTING |
||||||||||||||||
Expenditures on property acquisitions |
(2,861 | ) | (20,852 | ) | (94,427 | ) | (574,045 | ) | ||||||||
Expenditures on property, plant and equipment |
(40,050 | ) | (43,455 | ) | (114,486 | ) | (107,020 | ) | ||||||||
Proceeds on property dispositions |
18,623 | | 18,623 | | ||||||||||||
Change in remediation trust fund |
(272 | ) | (276 | ) | (804 | ) | (949 | ) | ||||||||
Purchase of marketable securities |
| (2,680 | ) | | (2,680 | ) | ||||||||||
Change in non-cash investing working capital (Note 8) |
1,527 | 1,385 | 1,527 | (959 | ) | |||||||||||
(23,033 | ) | (65,878 | ) | (189,567 | ) | (685,653 | ) | |||||||||
CHANGE IN CASH AND TERM DEPOSITS |
15,537 | (10,197 | ) | 5,211 | (68,710 | ) | ||||||||||
CASH AND TERM DEPOSITS (BANK INDEBTEDNESS) AT BEGINNING OF PERIOD |
(14,540 | ) | 5,641 | (4,214 | ) | 64,154 | ||||||||||
CASH AND TERM DEPOSITS (BANK INDEBTEDNESS) AT END OF PERIOD |
$ | 997 | $ | (4,556 | ) | $ | 997 | $ | (4,556 | ) | ||||||
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 do not contain the accounts of Pengrowth Management Limited (the Manager). 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. | ||
TRUST UNIT AWARD PLAN | ||
Effective July 13, 2005, Pengrowth established a new incentive plan to reward and retain employees whereby Class B trust units and cash to offset the estimated taxable benefit will be awarded to eligible employees. Employees will receive one half of the trust units and cash on January 1, 2006 and one half of the trust units and cash on July 1, 2006. Any appreciation or depreciation in the Class B trust units over the vesting period accrues to the eligible employees. | ||
Pengrowth acquired the Class B trust units to be awarded under the plan on the open market for $4.3 million and placed them in a trust account established for the benefit of the eligible employees. The cost to acquire the trust units has been recorded as deferred compensation expense and is being charged to net income on a straight line basis over one year. In addition, the cash portion of the incentive plan of approximately $1.5 million is being accrued on a straight line basis over one year. Any unvested trust units will be sold on the open market. During the three months ended September 30, 2005 $1.4 million has been charged to net income. | ||
TRUST UNIT BASED COMPENSATION PLANS | ||
Pengrowth has trust unit based compensation plans under which directors, officers, employees and special consultants of Pengrowth and the Manager are eligible to receive trust unit options and rights. Pengrowth records compensation expense and a corresponding decrease to contributed surplus in respect of rights incentive options granted on or after January 1, 2003. The amount of compensation expense is reduced and a corresponding increase to contributed surplus recorded for rights incentive options which are subsequently cancelled prior to vesting. | ||
Compensation expense is based on a fair value method. The fair value of rights incentive options granted during the nine months ended September 30, 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. For the three months ended September 30, 2005, compensation expense of $250,000 (September 30, 2004 $312,000) and for the nine months ended September 30, 2005 compensation expense of $1,308,000 (September 30, 2004 $938,000) related to the rights incentive options was recorded. | ||
LONG TERM INCENTIVE PLAN | ||
Effective January 1, 2005, the Board of Directors approved a Long Term Incentive Plan. Under the Long Term Incentive Plan for permanent employees of Pengrowth and other designated participants, deferred entitlement trust units are granted based on a grant value as a percentage of an individuals base salary and an established weighting of deferred entitlement trust units and/or rights incentive options that is dependent on an individuals position within the organization. The deferred |
entitlement trust units fully vest and are converted to Pengrowth Energy Trust Class B trust units (Class B trust units) on the third anniversary year from the date of grant and will receive distributions prior to the vesting date in the form of additional deferred entitlement trust units. However, the number of deferred entitlement trust units actually issued to each participant 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 such that 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 deferred entitlement trust units granted plus accrued deferred entitlement trust units through the deemed re-investment of distributions. | ||
Compensation expense related to deferred entitlement trust units is based on the fair value of the deferred entitlement 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 deferred entitlement trust units at the date of grant 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 unit holders capital is increased and contributed surplus is reduced. For the three months ended and nine months ended September 30, 2005, Pengrowth recorded compensation expense of $358,000 and $795,000, respectively associated with the deferred entitlement trust units. Compensation expense associated with the deferred entitlement trust units was based on the weighted average estimated fair value of $18.69 per deferred entitlement trust unit. | ||
2. | LONG TERM DEBT |
As at | As at | |||||||
September 30, | December 31, | |||||||
2005 | 2004 | |||||||
U.S. dollar denominated debt: |
||||||||
U.S. $150 million senior unsecured notes at 4.93% due April 2010 |
$ | 174,165 | $ | 180,300 | ||||
U.S. $50 million senior unsecured notes at 5.47% due April 2013 |
58,055 | 60,100 | ||||||
232,220 | 240,400 | |||||||
Canadian dollar revolving credit borrowings |
190,000 | 105,000 | ||||||
$ | 422,220 | $ | 345,400 | |||||
On September 30, 2005 Pengrowth had a $470 million revolving unsecured credit facility syndicated among eight financial institutions of which approximately $295 million remained unutilized. The facilities are currently reduced by outstanding letters of credit in the amount of approximately $21 million. The credit facility is an extendible 364 day revolving facility with a three year amortization period. The credit facility will revolve until June 16, 2006 and is extendible at that time at the lenders option. In the event the facility is not renewed, any amount outstanding would be repaid in equal quarterly instalments over the three year period. Pengrowth 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 the one year following the date of non-renewal. Pengrowth also 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 Pengrowth. The margin and stamping fees vary from 0.25 percent to 1.40 percent on the new revolving credit facility depending on financial statement ratios and the form of borrowing. | ||
3. | CORPORATE ACQUISITION | |
On April 29, 2005, Pengrowth acquired all of the issued and outstanding shares of Crispin Energy Inc. (Crispin) which held interests in oil and natural gas assets mainly in Alberta. The shares were acquired on the basis of exchanging 0.0725 Class B trust units of Pengrowth Energy Trust for each share held by Canadian resident shareholders of Crispin and 0.0512 Class A trust units of Pengrowth Energy Trust for each share held by non-Canadian resident shareholders of Crispin. The average value assigned to each trust unit issued was $20.80 based on the weighted average trading price of the Class A and Class B trust units for a period before and after the acquisition was announced. Pengrowth Energy Trust issued 3,538,581 Class B trust units and 686,732 Class A trust units valued at $88 million. The transaction was accounted for using the purchase method of accounting with the allocation of the purchase price and consideration as follows: |
Allocation of purchase price: |
||||
Working capital |
$ | 1,655 | ||
Property, plant, and equipment |
121,729 | |||
Goodwill |
12,766 | |||
Long-term debt |
(20,459 | ) | ||
Asset retirement obligations |
(4,038 | ) | ||
Future income taxes |
(22,208 | ) | ||
$ | 89,445 | |||
Cost of acquisition: |
||||
Trust units issued |
$ | 87,960 | ||
Acquisition costs |
1,485 | |||
$ | 89,445 | |||
Property, plant and equipment of $122 million represents the estimated fair value of the assets acquired determined in part by an independent reserve evaluation. Goodwill of $13 million, which is not deductible for tax purposes, was determined based on the excess of the total cost of the acquisition less the value assigned to the identifiable assets and liabilities including the future income tax liability. | ||
The future income tax liability was determined based on an enacted income tax rate of approximately 34 percent as at April 29, 2005. Results from operations of the acquired assets of Crispin subsequent to April 29, 2005 are included in the consolidated financial statements. Final determination of the cost of the acquisition and the allocation thereof to the fair values of Crispins net assets is still pending. | ||
4. | TRUST UNITS | |
The total authorized capital of Pengrowth is 500,000,000 trust units. | ||
Undeclared Trust Units: |
9 Months Ended | 12 Months Ended | |||||||||||||||
September 30, 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 |
(25,556 | ) | (392 | ) | (135,792,888 | ) | (2,080,281 | ) | ||||||||
Balance, end of period |
47,769 | $ | 731 | 73,325 | $ | 1,123 | ||||||||||
Class A Trust Units: |
9 Months Ended | For the period from | |||||||||||||||
September 30, 2005 | July 27, 2004 to Dec 31,2004 | |||||||||||||||
Number | Number of | |||||||||||||||
Trust units issued | Of units | Amount | units | Amount | ||||||||||||
Balance, beginning of period |
76,792,759 | $ | 1,176,427 | | $ | | ||||||||||
Issued for the Crispin acquisition (non-cash)
(Note 3) |
686,732 | 19,002 | | | ||||||||||||
Trust units converted |
45,082 | 691 | 76,792,759 | 1,176,427 | ||||||||||||
Balance, end of period |
77,524,573 | $ | 1,196,120 | 76,792,759 | $ | 1,176,427 | ||||||||||
Class B Trust Units: |
9 Months Ended | For the period from | |||||||||||||||
September 30, 2005 | July 27, 2004 to Dec 31, 2004 | |||||||||||||||
Number | Number of | |||||||||||||||
Trust units issued | Of units | Amount | units | Amount | ||||||||||||
Balance, beginning of period |
76,106,471 | $ | 1,205,734 | | $ | | ||||||||||
Trust units converted |
(19,526 | ) | (299 | ) | 59,000,129 | 903,854 | ||||||||||
Issued for cash |
| | 15,985,000 | 298,920 | ||||||||||||
Less: issue expenses |
| | | (15,577 | ) | |||||||||||
Issued for the Crispin acquisition (non-cash)
(Note 3) |
3,538,581 | 68,958 | | | ||||||||||||
Issued for cash on exercise of trust units
options and rights |
1,235,557 | 17,449 | 746,864 | 11,516 | ||||||||||||
Issued for cash under Distribution
Reinvestment Plan (DRIP) |
829,918 | 14,558 | 374,478 | 6,750 | ||||||||||||
Trust unit rights incentive plan (non-cash
exercised) |
| 874 | | 271 | ||||||||||||
Balance, end of period |
81,691,001 | $ | 1,307,274 | 76,106,471 | $ | 1,205,734 | ||||||||||
As at September 30, 2005 Pengrowth had 159,263,343 trust units (December 31, 2004 152,972,555 trust units) outstanding. | ||
Per Trust Unit Amounts | ||
The per trust unit amounts of net income are based on the following weighted average trust units outstanding for the period. The weighted average trust units outstanding for the three months ended September 30, 2005 were 158,789,481 trust units (September 30, 2004 135,906,487 trust units) and for the nine months ended September 30, 2005 were 156,318,245 trust units (September 30, 2004 132,213,280 trust units). In computing diluted net income per trust unit, 507,494 trust units were added to the weighted average number of trust units outstanding during the three months ended September 30, 2005 (September 30, 2004633,751 trust units) and 502,233 trust units were added for the nine months ended September 30, 2005 (September 30, 2004 623,464 trust units) for the dilutive effect of trust unit options, rights and deferred entitlement trust units. For the three months ended September 30, 2005,10,140 options and rights (September 30,2004958,292 options and rights) and for the nine months ended September 30, 2005, 549,284 options and rights (September 30, 2004781,161 options and rights) were excluded from the diluted net income per trust unit calculation as their effect is anti-dilutive. | ||
Contributed Surplus |
9 Months Ended | 12 Months Ended | |||||||
September 30, 2005 | December 31, 2004 | |||||||
Balance, beginning of period |
$ | 1,923 | $ | 189 | ||||
Trust unit rights incentive plan (non-cash expensed) |
1,308 | 2,264 | ||||||
Deferred entitlement trust units (non-cash expensed) |
829 | | ||||||
Trust unit rights incentive plan (non-cash exercised) |
(874 | ) | (530 | ) | ||||
Balance, end of period |
$ | 3,186 | $ | 1,923 | ||||
Trust Unit Option Plan | ||
As at September 30, 2005, options to purchase 365,200 Class B trust units were outstanding (December 31, 2004options to purchase 845,374 Class B trust units) that expire at various dates to June 28, 2009. |
9 Months Ended | 12 Months Ended | |||||||||||||||
September 30, 2005 | December 31, 2004 | |||||||||||||||
Weighted | Weighted | |||||||||||||||
Number | Average Exercise | Number | Average Exercise | |||||||||||||
Trust unit options | Of options | price | of options | price | ||||||||||||
Outstanding at beginning of period |
845,374 | $ | 16.97 | 2,014,903 | $ | 17.47 | ||||||||||
Exercised |
(452,424 | ) | $ | 16.37 | (838,789 | ) | $ | 16.82 | ||||||||
Expired |
(2,400 | ) | $ | 15.25 | (325,200 | ) | $ | 20.44 | ||||||||
Cancelled |
(25,350 | ) | $ | 18.98 | (5,540 | ) | $ | 16.53 | ||||||||
Outstanding and exercisable at period-end |
365,200 | $ | 17.57 | 845,374 | $ | 16.97 | ||||||||||
Rights Incentive Plan | ||
As at September 30, 2005, rights to purchase 1,553,576 Class B trust units were outstanding (December 31, 2004rights to purchase 2,011,451 Class B trust units) that expire at various dates to July 7, 2010. |
9 Months Ended | 12 Months Ended | |||||||||||||||
September 30, 2005 | December 31, 2004 | |||||||||||||||
Weighted | Weighted | |||||||||||||||
Number of | Average Exercise | Number of | Average Exercise | |||||||||||||
Rights incentive options | rights | price | rights | price | ||||||||||||
Outstanding at beginning of period |
2,011,451 | $ | 14.23 | 1,112,140 | $ | 12.20 | ||||||||||
Granted(1) |
521,312 | $ | 18.18 | 1,409,856 | $ | 17.35 | ||||||||||
Exercised |
(783,133 | ) | $ | 12.82 | (456,049 | ) | $ | 13.47 | ||||||||
Cancelled |
(196,054 | ) | $ | 17.12 | (54,496 | ) | $ | 14.19 | ||||||||
Outstanding at period-end |
1,553,576 | $ | 14.88 | 2,011,451 | $ | 14.23 | ||||||||||
Exercisable at period-end |
720,191 | $ | 13.13 | 1,037,078 | $ | 12.48 | ||||||||||
(1) | Weighted average exercise price of rights granted are based on the exercise price at the date of grant |
Long Term Incentive Program | ||
As at September 30, 2005,150,529 deferred entitlement trust units were outstanding, including accrued distributions re-invested to September 15, 2005. The deferred entitlement trust units vest on various dates to July, 2008. |
Number of deferred | ||||
entitlement trust | ||||
units | ||||
Outstanding, beginning of period |
| |||
Granted |
170,983 | |||
Cancelled |
(20,454 | ) | ||
Outstanding, end of period |
150,529 | |||
Compensation expense associated with the deferred entitlement trust units was based on the weighted average estimated fair value of $18.69 per deferred entitlement trust unit. |
5. | ASSET RETIREMENT OBLIGATIONS |
For the nine months ended | For the year ended | |||||||
September 30, | December 31, | |||||||
2005 | 2004 | |||||||
Asset retirement obligations, beginning of period |
$ | 171,866 | $ | 102,528 | ||||
Increase (decrease) in liabilities related to: |
||||||||
Acquisitions |
6,347 | 44,368 | ||||||
Additions |
1,302 | 2,681 | ||||||
Disposals |
(2,294 | ) | | |||||
Revisions |
| 16,087 | ||||||
Accretion expense |
10,531 | 10,642 | ||||||
Liabilities settled during the period |
(4,300 | ) | (4,440 | ) | ||||
Asset retirement obligations, end of period |
$ | 183,452 | $ | 171,866 | ||||
6. | DEFERRED CHARGES |
As at | As at | |||||||
September 30, | December 31, | |||||||
2005 | 2004 | |||||||
Imputed
interest on note
payable (net of
accumulated
amortization of
$2,543) |
$ | 1,065 | $ | 2,020 | ||||
U.S. debt issue
costs (net of
accumulated
amortization of
$739) |
1,402 | 1,631 | ||||||
Deferred
compensation
expense (net of
accumulated
amortization of
$1,071) |
3,212 | | ||||||
$ | 5,679 | $ | 3,651 | |||||
7. | FOREIGN EXCHANGE |
Three months ended | Nine months ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2005 | 2004 | 2005 | 2004 | |||||||||||||
Unrealized foreign exchange gain
on translation of U.S. dollar denominated
debt |
$ | 12,860 | $ | 14,440 | $ | 8,180 | $ | 6,980 | ||||||||
Realized foreign exchange gain (loss) |
(605 | ) | (752 | ) | 290 | (329 | ) | |||||||||
$ | 12,255 | $ | 13,688 | $ | 8,470 | $ | 6,651 | |||||||||
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. |
8. | OTHER CASH FLOW DISCLOSURES | |
Change in Non-Cash Operating Working Capital | ||
Cash provided by (used for): |
Three months ended | Nine months ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2005 | 2004 | 2005 | 2004 | |||||||||||||
Accounts receivable |
$ | (24,052 | ) | $ | (11,157 | ) | $ | (21,508 | ) | $ | (34,713 | ) | ||||
Inventory |
| (113 | ) | 439 | 170 | |||||||||||
Accounts payable and accrued liabilities |
23,884 | 19,701 | 25,138 | 39,128 | ||||||||||||
Due to Pengrowth Management Limited |
957 | 1,426 | (2,229 | ) | 5,164 | |||||||||||
$ | 789 | $ | 9,857 | $ | 1,840 | $ | 9,749 | |||||||||
Change in Non-Cash Investing Working Capital | ||
Cash provided by (used for): |
Three months ended | Nine months ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2005 | 2004 | 2005 | 2004 | |||||||||||||
Accounts payable for capital accruals |
$ | 1,527 | $ | 1,385 | $ | 1,527 | $ | (959 | ) | |||||||
Three months ended | Nine months ended | |||||||||||||||
September 30, | September 30, | |||||||||||||||
2005 | 2004 | 2005 | 2004 | |||||||||||||
Cash payments made for taxes |
$ | 1,787 | $ | 1,730 | $ | 4,363 | $ | 2,885 | ||||||||
Cash payments made for interest |
$ | 2,763 | $ | 5,145 | $ | 12,952 | $ | 15,733 | ||||||||
9. | FINANCIAL INSTRUMENTS | |
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 September 30, 2005, Pengrowth had fixed the price applicable to future production as follows: | ||
Crude Oil: |
Volume | Reference | Price | ||||||||||
Remaining Term | (bbl/day) | Point | per bbl | |||||||||
2005 |
||||||||||||
Financial: |
||||||||||||
Oct 1, 2005
Dec 31, 2005 |
10,000 | WTI (1) | $54.39 Cdn | |||||||||
2006 |
||||||||||||
Financial: |
||||||||||||
Jan 1, 2006
Dec 31, 2006 |
4,000 | WTI (1) | $64.08 Cdn | |||||||||
Volume | Reference | Price | ||||||||
Remaining Term | (mmbtu/day) | Point | per mmbtu | |||||||
2005 |
||||||||||
Financial: |
||||||||||
Oct 1, 2005
Dec 31, 2005 |
11,000 | Tetco M3 (1) | $ | 9.27 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
5,000 | Transco Z6 (1) | $ | 10.11 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
2,500 | NGI Chicago (1) | $ | 9.41 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
2,500 | NYMEX(1) | $ | 14.07 Cdn | ||||||
Oct 1, 2005
Dec 31, 2005 |
2,370 | AECO | $ | 8.35 Cdn | ||||||
2006 |
||||||||||
Financial: |
||||||||||
Jan 1, 2006
Dec 31, 2006 |
2,500 | Transco Z6 (1) | $ | 10. 63 Cdn | ||||||
Jan 1, 2006
Dec 31, 2006 |
2,370 | AECO | $ | 8.03 Cdn | ||||||
Jan 1, 2006
Mar 31, 2006 |
2,500 | NYMEX(1) | $ | 14.56 Cdn | ||||||
(1) | Associated Cdn$ / U.S. $ foreign exchange rate has been fixed. |
The estimated fair value of the financial crude oil and natural gas contracts has been determined based on the amounts Pengrowth would receive or pay to terminate the contracts at period-end. At September 30, 2005, the amount Pengrowth would pay to terminate the financial crude oil and natural gas contracts would be $39,198,000 and $25,036,000, respectively. | ||
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/day) | per mmbtu(2) | ||||||
2005 to 2009 |
||||||||
July 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
Apr 30, 2009 |
3,886 | $ | 2.40 Cdn | |||||
(2) | Reference price based on AECO |
As at September 30, 2005, the fair value amount Pengrowth would pay to terminate the natural gas fixed price sales contract would be $37,822,000 (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 September 30, 2005 was approximately $9,207,000 (December 31, 2004 $8,366,000). The fair value of the U.S. dollar denominated debt at September 30, 2005 was approximately $225,850,000 (December 31, 2004 $238,726,000) based on the changes in the fair value of the underlying seven and ten year 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 September 30, 2005, approximates its carrying value net of the imputed interest included in deferred charges. | ||
10. | SUBSEQUENT EVENT | |
Purchase and sale agreements have been executed with several parties to acquire from Pengrowth non-core properties with associated production of approximately 400 boe per day for gross proceeds of approximately $20 million. These divestments were previously disclosed in the second quarter of 2005 and are now expected to close in the fourth quarter. |