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Pengrowth Energy Trust Announces Second Quarter 2007 Results CALGARY, ALBERTA--(MARKET WIRE)--Aug 2, 2007 -- Pengrowth Corporation, administrator of Pengrowth Energy
Trust (Toronto:PGF-UN.TO - News)(NYSE:PGH - News) (collectively "Pengrowth"),
is pleased to announce the interim unaudited operating and
financial results for the three month and six month periods
ended June 30, 2007.
Pengrowth reported net income of $271.7 million ($1.11 per trust unit) in the second quarter of 2007 compared to a net loss of $69.8 million ($0.29 per trust unit) in the first quarter of 2007 and net income of $110.1 million ($0.69 per trust unit) in the same period last year. Net income in the quarter included a $147.7 million increase in earnings due to a future tax recovery. The future tax recovery was recorded as a result of the enactment of the previously announced tax on income trusts, asset dispositions in the quarter and a reduction in the federal income tax rate. During the second quarter of 2007, Pengrowth generated distributable cash of $196.9 million versus $199.4 million in the first quarter of 2007 and $152.3 million in the second quarter of 2006. Distributions paid or declared to unitholders in the second quarter of 2007 totaled $184.3 million or $0.75 per trust unit reflecting a payout ratio of 94 percent. Pengrowth's distributions remain unchanged at $0.25 per trust unit per month, up to and including our most recently announced August 15, 2007 distribution. Daily production remained relatively stable in the second quarter of 2007 at 89,633 boe per day when compared to the first quarter of 2007 and increased approximately 59 percent when compared to the second quarter of 2006. The increase is primarily due to the Carson Creek, Esprit Trust and the CP properties acquisitions, SOEP compression and contributions from our ongoing development activities. Pengrowth anticipates full year average daily production in the range of 85,000 boe per day to 87,500 boe per day including the expected divestiture of 8,900 boe per day of production at the time of sale. Development capital for the second quarter of 2007 totaled $44.4 million with approximately 82 percent spent on drilling and completions. Pengrowth participated in drilling 34 gross (15.3 net) wells with a success rate of 94 percent. In addition, Pengrowth participated in the drilling of three injection and one water disposal well (0.9 net). During 2007, Pengrowth intends to dispose of approximately $450 million of non-core properties. In the first half of this year, Pengrowth completed asset sales for proceeds of approximately $282 million. The proceeds were used to partially repay the $600 million bridge facility. Subsequent to the end of second quarter, Pengrowth closed a U.S. $400 million offering of notes issued on a private placement basis on July 26, 2007 in the United States. The private placement consists of 6.35 percent notes due in 2017. The notes are unsecured and rank equally with Pengrowth's bank facilities and existing term notes. Note regarding currency: all figures contained within this report are quoted in Canadian dollars unless otherwise indicated. President's Message To our valued unitholders, The second quarter of 2007 marked further progress in Pengrowth's continued transformation and I am pleased to present the unaudited quarterly results for the three months and six months ended June 30, 2007. Pengrowth performed well during the second quarter. We continued to see positive results from our operations and remain well positioned for a generally favourable second half of 2007. In my annual letter dated February 26, 2007, we set out a number of goals and objectives for the trust in 2007 and I would like to take this opportunity to update our progress on each of these key targets at this pivotal mid-year mark. 2007 key targets include: 1) Execution of a $275 million capital development program that is focused on asset optimization and organic growth. 2) Full integration of the assets and people associated with the Carson Creek, Esprit Trust and CP properties acquisitions in order to fully exploit those opportunities identified by our operations teams. 3) Completion of our property disposition program. 4) Continuing to make distributions to unitholders while executing a prudent business model. Pengrowth remained focused on development opportunities during the quarter and continued to achieve encouraging results. Pengrowth's capital development program totaled approximately $44.4 million in the second quarter with approximately 82 percent directed towards drilling and completions. Pengrowth participated in drilling 34 gross wells (15.3 net) with a success rate of 94 percent. In addition, we participated in the drilling of three injectors and one water disposal well (0.9 net). Production for the second quarter of 2007 remained relatively stable with average daily production of 89,633 barrels of oil equivalent (boe) per day when compared to the first quarter of 2007 and increased approximately 59 percent when compared to the second quarter of 2006. The increase is mainly attributable to production additions associated with the Carson Creek, Esprit Trust and CP properties acquisitions which closed in the second half of 2006 and early 2007 and were augmented by our capital development program. These additions served to nearly offset natural production declines and the impact of our divestiture program. Based on these results, Pengrowth has increased its forecast for average 2007 production to the range of 85,000 to 87,500 boe per day. Integration activities associated with the Carson Creek, Esprit Trust and CP properties acquisitions continued into the second quarter. The Carson Creek and Esprit properties have been completely integrated into our asset teams. Work is being done to reroute some gas from Carson Creek to Judy Creek and evaluation is underway for potentially moving all the gas from this area to Judy Creek. These optimizations are expected to result in significant operating cost savings. Optimization of gas processing has been identified for the Harmattan and Olds properties which will significantly reduce costs incurred due to third party arrangements. Pengrowth has been successful in the hiring of a significant number of experienced technical staff to work on these opportunities. Pengrowth took over full management of the CP properties in June after completion of the transition services contract from ConocoPhillips. Upside in the Deer Mountain, Goose River & Red Earth properties has been identified with projects underway for the third and fourth quarters. Pengrowth has one of the strongest property portfolios in the energy trust sector. In conjunction with the integration of the new assets into our operations, we have realized the opportunity to high-grade our asset base through a targeted disposition program of approximately $450 milllion of non-core assets producing approximately 8,900 boe per day at the time of sale. In the first half of the year, Pengrowth completed asset sales of approximxately $282 million. The proceeds were used to partially repay the $600 million bridge facility associated with the CP properties acquisition and Pengrowth now anticipates our disposition program to be completed prior to year end 2007. Pengrowth's remaining high quality, long-life assets provide the trust with a stable production profile.
Distributions to unitholders during the quarter totaled $0.75 per trust unit and Pengrowth has maintained the monthly distribution at $0.25 per trust unit since December 31, 2005. However, distributions can and may fluctuate in the future. Distributable cash is derived mainly from producing and selling our oil, natural gas and related products and as such, distributable cash is highly dependent on commodity prices. Pengrowth's board of directors will continue to examine distributions on a monthly basis while considering overall market conditions to set the distribution level each month. I am pleased to report that we have made significant progress on our key targets in 2007 and we continue to seek opportunities through acquisition, industry consolidation, development and synergies to add value on behalf of our unitholders. As such, it remains paramount that the trust retain the necessary financial flexibility to capitalize on future growth opportunities. Accordingly, Pengrowth has taken steps to reduce indebtedness and strengthen its financial position. On June 15, 2007, Pengrowth increased its syndicated bank facility to $1.2 billion of available credit and extended the maturity date to June 16, 2010. On July 13, 2007, with proceeds from Pengrowth's increased bank facility, Pengrowth fully repaid the remaining $322 million outstanding on the $600 million bridge facility due January 22, 2008 obtained in conjunction with the CP properties acquisition. Also subsequent to quarter-end, Pengrowth closed a U.S. $400 million offering of notes issued on a private placement basis on July 26, 2007 in the United States. The private placement consists of 6.35 percent notes due in 2017. The notes are unsecured and rank equally with Pengrowth's bank facilities and existing term notes and we intend to use the net proceeds of the notes to reduce amounts outstanding on our bank facilities which will increase our unused credit capacity. This increased financial flexibility gives Pengrowth unused credit capacity at this time of approximately $580 million which should allow us to complete future value-adding transactions should they arise. The second quarter showcased our team's commitment to seek out opportunities to add value on behalf of unitholders through the successful execution of our 2007 key targets thus far. I am pleased with the accomplishments our team achieved during the period and I believe we are well positioned both operationally and financially for continued success in 2007. James S. Kinnear, Chairman, President and Chief Executive Officer August 1, 2007
Summary of Financial and Operating Results
(thousands, except per unit Three Months ended June 30
amounts) 2007 2006 % Change
---------------------------------------------------------------------------
INCOME STATEMENT
Oil and gas sales $ 443,977 $ 283,532 57
Net income (loss) $ 271,659 $ 110,116 147
Net income (loss) per trust unit $ 1.11 $ 0.69 61
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CASH FLOW
Cash flows from operating
activities(1) $ 249,960 $ 126,800 97
Cash flows from operating
activities per trust unit $ 1.02 $ 0.79 29
Distributable cash(i)(2) $ 196,934 $ 152,266 29
Distributable cash per
trust unit(i)(2) $ 0.80 $ 0.95 (16)
Distributions paid or declared $ 184,327 $ 120,597 53
Distributions paid or declared
per trust unit $ 0.75 $ 0.75 -
Payout ratio(i) (2) 94% 79% 15
Capital expenditures $ 49,467 $ 47,999 3
Capital expenditures per
trust unit $ 0.20 $ 0.30 (33)
Weighted average number of
trust units outstanding 245,127 160,592 53
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BALANCE SHEET
Working capital
Property, plant and equipment
Long term debt
Trust unitholders' equity
Trust unitholders' equity per
trust unit
Number of trust units outstanding
at period end
---------------------------------------------------------------------------
DAILY PRODUCTION
Crude oil (barrels) 27,083 20,342 33
Heavy oil (barrels) 7,254 4,869 49
Natural gas (mcf) 280,667 150,976 86
Natural gas liquids (barrels) 8,519 5,952 43
Total production (boe) 89,633 56,325 59
TOTAL PRODUCTION (mboe) 8,157 5,126 59
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PRODUCTION PROFILE
Crude oil 30% 36%
Heavy oil 8% 9%
Natural gas 52% 45%
Natural gas liquids 10% 10%
---------------------------------------------------------------------------
AVERAGE REALIZED PRICES (after
commodity risk management)
Crude oil (per barrel) $ 71.81 $ 72.67 (1)
Heavy oil (per barrel) $ 43.52 $ 50.07 (13)
Natural gas (per mcf) $ 7.61 $ 6.76 13
Natural gas liquids (per barrel) $ 56.42 $ 58.92 (4)
Average realized price per boe $ 54.39 $ 54.91 (1)
Summary of Financial and Operating Results
(thousands, except per unit Six Months ended June 30
amounts) 2007 2006 % Change
---------------------------------------------------------------------------
INCOME STATEMENT
Oil and gas sales $ 876,085 $ 575,428 52
Net income (loss) $ 201,825 $ 176,451 14
Net income (loss) per trust unit $ 0.82 $ 1.10 (25)
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CASH FLOW
Cash flows from operating
activities(1) $ 386,389 $ 283,160 36
Cash flows from operating
activities per trust unit $ 1.58 $ 1.77 (11)
Distributable cash(i)(2) $ 396,328 $ 293,135 35
Distributable cash per
trust unit(i)(2) $ 1.62 $ 1.83 (11)
Distributions paid or declared $ 367,861 $ 240,899 53
Distributions paid or declared
per trust unit $ 1.50 $ 1.50 -
Payout ratio(i)(2) 93% 82% 11
Capital expenditures $ 148,252 $ 123,060 20
Capital expenditures per trust unit $ 0.61 $ 0.77 (21)
Weighted average number of trust
units outstanding 244,745 160,372 53
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BALANCE SHEET
Working capital $ (444,394) $ (97,150) 357
Property, plant and equipment $4,633,861 $2,081,403 123
Long term debt $1,038,328 $ 488,310 113
Trust unitholders' equity $2,913,152 $1,430,850 104
Trust unitholders' equity per
trust unit $ 11.86 $ 8.90 33
Number of trust units outstanding
at period end 245,560 160,777 53
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DAILY PRODUCTION
Crude oil (barrels) 27,271 20,800 31
Heavy oil (barrels) 7,015 4,943 42
Natural gas (mcf) 278,096 154,407 80
Natural gas liquids (barrels) 9,215 6,101 51
Total production (boe) 89,850 57,578 56
TOTAL PRODUCTION (mboe) 16,263 10,422 56
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PRODUCTION PROFILE
Crude oil 30% 36%
Heavy oil 8% 8%
Natural gas 52% 45%
Natural gas liquids 10% 11%
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AVERAGE REALIZED PRICES (after
commodity risk management)
Crude oil (per barrel) $ 69.52 $ 67.91 2
Heavy oil (per barrel) $ 42.57 $ 39.52 8
Natural gas (per mcf) $ 7.76 $ 7.77 -
Natural gas liquids (per barrel) $ 52.81 $ 58.57 (10)
Average realized price per boe $ 53.85 $ 54.98 (2)
(1) Prior year restated. See Note 1 to financial statements
(2) Prior year restated to conform to presentation adopted in current year
- See the section entitled "Non-GAAP Financial Measures".
Summary of Trust Unit Trading Data
Three Months ended Six Months ended
June 30 June 30
(thousands, except per
trust unit amounts) 2007 2006 2007 2006
TRUST UNIT TRADING
(Class A)
PGH (NYSE)
High $ 19.84 U.S. $ 25.00 U.S. $ 19.84 U.S. $ 25.15 U.S.
Low $ 16.45 U.S. $ 21.85 U.S. $ 15.82 U.S. $ 21.50 U.S.
Close $ 19.09 U.S. $ 24.09 U.S. $ 19.09 U.S. $ 24.09 U.S.
Value $ 428,571 U.S. $ 336,990 U.S. $ 877,712 U.S. $ 653,208 U.S.
Volume 23,668 14,277 50,301 27,698
PGF.A (TSX)(i)
High $ - $ 28.50 $ - $ 28.96
Low $ - $ 24.20 $ - $ 24.20
Close $ - $ 26.70 $ - $ 26.70
Value $ - $ 47,608 $ - $ 81,449
Volume - 1,810 - 3,054
TRUST UNIT TRADING
(Class B)
PGF.B (TSX)(i)
High $ - $ 26.05 $ - $ 26.05
Low $ - $ 22.41 $ - $ 20.71
Close $ - $ 26.05 $ - $ 26.05
Value $ - $ 459,628 $ - $ 879,690
Volume - 18,982 - 37,321
PGF.UN (TSX)(i)
High $ 21.04 $ - $ 21.04 $ -
Low $ 18.82 $ - $ 18.62 $ -
Close $ 20.27 $ - $ 20.27 $ -
Value $ 561,471 $ - $1,306,290 $ -
Volume 28,348 - 66,090 -
(i) July 27, 2006, Pengrowth's Class A trust units and Class B trust
units were consolidated into a single class of trust units whereas
the Class A trust units were delisted from the Toronto Stock
Exchange and the Class B trust units were renamed as trust units and
their trading symbol changed to PGF.UN.The following discussion of financial results should be read in conjunction with the interim unaudited consolidated financial statements for the six months ended June 30, 2007 and the audited consolidated financial statements for the year ended December 31, 2006 of Pengrowth Energy Trust and is based on information available to August 1, 2007. Frequently Recurring Terms For the purposes of this discussion, we use certain frequently recurring terms as follows: the "Trust" refers to Pengrowth Energy Trust, the "Corporation" refers to Pengrowth Corporation, "Pengrowth" refers to the Trust and its subsidiaries and the Corporation on a consolidated basis and the "Manager" refers to Pengrowth Management Limited. Pengrowth uses the following frequently recurring industry terms in this discussion: "bbls" refers to barrels, "boe" refers to barrels of oil equivalent, "mboe" refers to a thousand barrels of oil equivalent, "mcf" refers to thousand cubic feet, "gj" refers to gigajoule and "mmbtu" refers to million British thermal units. Advisory Regarding Forward-Looking Statements This discussion contains forward-looking statements within the meaning of securities laws, including the "safe harbour" provisions of Canadian securities legislation and the United States Private Securities Litigation Reform Act of 1995. Forward-looking information is often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "intend", "forecast", "target", "project", "guidance" "may", "will", "should", "could", "estimate", "predict" or similar words suggesting future outcomes or language suggesting an outlook. Forward-looking statements in this discussion include, but are not limited to, statements with respect to: reserves, 2007 production, production additions from Pengrowth's 2007 development program, the impact on production of divestitures in 2007, royalty obligations, 2007 operating expenses, future income taxes, goodwill, asset retirement obligations, taxability of distributions, remediation and abandonment expenses, capital expenditures, new head office expenses, general and administration expenses, proceeds from the disposal of properties and the impact of the proposed changes to the Canadian tax legislation. Statements relating to "reserves" are deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the reserves described exist in the quantities predicted or estimated and can profitably be produced in the future. Forward-looking statements and information are based on Pengrowth's current beliefs as well as assumptions made by and information currently available to Pengrowth concerning anticipated financial performance, business prospects, strategies, regulatory developments, future oil and natural gas commodity prices and differentials between light, medium and heavy oil prices, future oil and natural gas production levels, future exchange rates, the proceeds of anticipated divestitures, the amount of future cash distributions paid by Pengrowth, the cost of expanding our property holdings, our ability to obtain equipment in a timely manner to carry out development activities, our ability to market our oil and natural gas successfully to current and new customers, the impact of increasing competition, our ability to obtain financing on acceptable terms and our ability to add production and reserves through our development and exploitation activities. Although management considers these assumptions to be reasonable based on information currently available to it, they may prove to be incorrect. By their very nature, forward-looking statements involve inherent risks and uncertainties, both general and specific, and risks that predictions, forecasts, projections and other forward-looking statements will not be achieved. We caution readers not to place undue reliance on these statements as a number of important factors could cause the actual results to differ materially from the beliefs, plans, objectives, expectations and anticipations, estimates and intentions expressed in such forward-looking statements. These factors include, but are not limited to: the volatility of oil and gas prices; production and development costs and capital expenditures; the imprecision of reserve estimates and estimates of recoverable quantities of oil, natural gas and liquids; Pengrowth's ability to replace and expand oil and gas reserves; environmental claims and liabilities; incorrect assessments of value when making acquisitions; increases in debt service charges; the loss of key personnel; the marketability of production; defaults by third party operators; unforeseen title defects; fluctuations in foreign currency and exchange rates; inadequate insurance coverage; compliance with environmental laws and regulations; changes in tax laws; the failure to qualify as a mutual fund trust; and Pengrowth's ability to access external sources of debt and equity capital. Further information regarding these factors may be found under the heading "Business Risks" herein and under "Risk Factors" in Pengrowth's most recent Annual Information Form (AIF), and in Pengrowth's most recent consolidated financial statements, management information circular, quarterly reports, material change reports and news releases. Copies of the Trust's Canadian public filings are available on SEDAR at www.sedar.com . The Trust's U.S. public filings, including the Trust's most recent annual report form 40-F as supplemented by its filings on form 6-K, are available at www.sec.gov. Pengrowth cautions that the foregoing list of factors that may affect future results is not exhaustive. When relying on our forward-looking statements to make decisions with respect to Pengrowth, investors and others should carefully consider the foregoing factors and other uncertainties and potential events. Furthermore, the forward-looking statements contained in this discussion are made as of the date of this discussion and Pengrowth does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law. The forward-looking statements contained in this discussion are expressly qualified by this cautionary statement. Critical Accounting Estimates As discussed in Note 1 to the financial statements, the financial statements are prepared in accordance with Canadian Generally Accepted Accounting Principles (GAAP). Management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and revenues and expenses for the period ended. The amounts recorded for depletion, depreciation and amortization of injectants and the provision for asset retirement obligations, goodwill and future taxes are based on estimates. The ceiling test calculation is based on estimates of proved reserves, production rates, oil and natural gas prices, future costs and other relevant assumptions. As required by National Instrument 51-101 (NI 51-101) Standards of Disclosure for Oil and Gas Activities, Pengrowth uses independent qualified reserve evaluators in the preparation of reserve evaluations. By their nature, these estimates are subject to measurement uncertainty and changes in these estimates may impact the consolidated financial statements of future periods. The amounts recorded for the fair value of risk management contracts and the unrealized gains or losses on the change in fair value are based on estimates. These estimates can change significantly from period to period. Non-GAAP Financial Measures This discussion refers to certain financial measures that are not determined in accordance with GAAP in Canada or the United States. These measures do not have standardized meanings and may not be comparable to similar measures presented by other trusts or corporations. Measures such as funds generated from operations, funds generated from operations per trust unit, distributable cash, distributable cash per trust unit, payout ratio and operating netbacks do not have standardized meanings prescribed by GAAP. We discuss these measures because we believe that they facilitate the understanding of the results of our operations and financial position. Conversion and Currency When converting natural gas to equivalent barrels of oil within this discussion. Pengrowth uses the industry standard of six thousand cubic feet to one barrel of oil equivalent. Barrels of oil equivalent may be misleading, particularly if used in isolation; a conversion ratio of six mcf of natural gas to one boe is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Production volumes, revenues and reserves are reported on a company interest gross basis (before royalties) in accordance with Canadian practice. All amounts are stated in Canadian dollars unless otherwise specified. OVERVIEW Production for the second quarter of 2007 was 89,633 boe per day compared to 90,068 boe per day in the prior quarter reflecting a full quarter of additional volumes from the January 2007 ConocoPhillips (the "CP properties") acquisition and internal development and was offset by planned maintenance shutdowns and property divestments. For the six months ended June 30, 2007, production was 89,850 boe per day compared to 57,578 boe per day in the prior year. This increase is primarily due to additional volumes from acquisitions made in the second half of 2006 and early 2007. Pengrowth had net income for the second quarter of $271.7 million due in part to an unrealized mark-to-market gain on outstanding commodity contracts of $79.7 million resulting from the change in the fair value of the contracts during the period and a future income tax reduction in the amount of $147.7 million (see Taxes section for additional information). These non-cash amounts do not affect distributable cash for the quarter which was $196.9 million compared to $199.4 million in the prior quarter and $152.3 million in the second quarter of 2006. RESULTS OF OPERATIONS This discussion contains the results of Pengrowth Energy Trust and its subsidiaries. Production Average daily production remained relatively stable in the second quarter of 2007 compared to the first quarter of 2007. The slight decrease is primarily attributable to additional volumes from the CP properties acquisition which closed on January 22, 2007 being offset by planned maintenance shutdowns and non-core property divestments. In comparison to the second quarter of 2006, average daily production increased approximately 59 percent. In addition to the volumes from the CP properties acquisition, the increase is largely due to the Carson Creek and Esprit Trust acquisitions which were completed late in the third quarter and in the fourth quarter of 2006, respectively, and contributions from ongoing development activities. Daily production for the first half of 2007 increased approximately 56 percent compared to the same period of 2006. This is primarily due to the previously mentioned acquisitions made in the third and fourth quarters of 2006 and in January 2007. At this time, Pengrowth anticipates 2007 full year production of 85,000 to 87,500 boe per day. This estimate reflects expected divestitures during the year of approximately 8,900 boe per day of production at the time of sale. The above estimate excludes the impact from any potential future acquisitions.
Daily Production
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Light crude oil (bbls) 27,083 27,461 20,342 27,271 20,800
Heavy oil (bbls) 7,254 6,773 4,869 7,015 4,943
Natural gas (mcf) 280,667 275,495 150,976 278,096 154,407
Natural gas liquids (bbls) 8,519 9,918 5,952 9,215 6,101
----------------------------------------------------------------------------
Total boe per day 89,633 90,068 56,325 89,850 57,578
----------------------------------------------------------------------------Light crude oil production decreased one percent in the second quarter of 2007 compared to the first quarter of 2007. Property divestments in the second quarter more than offset the additional volumes from a full quarter of the CP properties acquisition. Production volumes increased 33 percent in the second quarter of 2007 compared to the second quarter of 2006 and 31 percent for the first half of 2007 compared to the same period in 2006. This increase is primarily due to the addition of approximately 8,700 bbls per day from the CP properties, Esprit Trust and Carson Creek acquisitions that more than offset natural production declines. Heavy oil production increased seven percent in the second quarter of 2007 compared to the first quarter of 2007 and 49 percent compared to the second quarter of 2006. Production increased 42 percent in the first half of 2007 versus the first half of 2006. Additional volumes from the CP properties acquisition were partially offset by production declines and property divestments. Natural gas production increased two percent compared to the first quarter of 2007. Additional volumes due to the Sable Offshore Energy Project (SOEP) compression project and the CP properties acquisition mostly offset impacts from planned maintenance shutdowns, property divestments and natural declines. In addition to the above increases, second quarter production increased 86 percent compared to the second quarter of 2006 due to the Esprit Trust and Carson Creek acquisitions, partially offset by production decline. Production for the first half of 2007 increased 80 percent from the first half of 2006. Natural gas liquids (NGLs) production decreased 14 percent versus the first quarter of 2007. The main reason for the decrease was lower NGL production being sold at Judy Creek compared to the first quarter of 2007 because additional volumes were being used to meet miscible flooding requirements. Compared to the second quarter of 2006, production is up approximately 43 percent due to additional volumes from the Esprit Trust, Carson Creek and CP properties acquisitions. Production for the first half of 2007 increased 51 percent due to the acquisitions. Pricing and Commodity Risk Management Compared to the prior quarter, higher U.S. dollar benchmark prices for crude oil and liquids were partially offset by lower natural gas market prices and the strengthening of the Canadian dollar. As part of our financial management strategy, Pengrowth uses forward price swap and option contracts to manage its exposure to commodity price fluctuations, to provide a measure of stability to monthly cash distributions and to partially secure returns on significant new acquisitions. Thus, in conjunction with the CP properties acquisition, Pengrowth increased the volume of commodity price risk management contracts. Pengrowth has committed approximately 15,000 bbls per day and 9,300 bbls per day of crude oil and 100,000 mcf per day and 60,000 mcf per day of natural gas for the remainder of 2007 and 2008, respectively. Each $1 per barrel change in future oil prices would result in approximately $6 million change in the value of the crude contracts. Similarly, each $0.50 per mcf change in future natural gas prices would result in a $19 million change in the value of the natural gas contracts. In prior periods, hedge accounting was followed for commodity risk management contracts entered into prior to May 2006 and therefore fair valuation and recording of these contracts was not required by GAAP. Pengrowth has not designated currently outstanding commodity contracts as hedges for accounting purposes and therefore must record these contracts on the balance sheet at their fair value and recognize changes in fair value on the statement of income as unrealized commodity risk management gains or losses. There will continue to be volatility in earnings to the extent that the fair value of commodity contracts fluctuates, however, these non-cash amounts do not impact Pengrowth's operating cash flows. Realized commodity risk management gains or losses are recorded in oil and gas sales on the statement of income.
Average Realized Prices
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
(Cdn$) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Light crude oil (per bbl) 69.61 63.59 75.67 66.59 70.27
after realized commodity
risk management 71.81 67.24 72.67 69.52 67.91
Heavy oil (per bbl) 43.52 41.54 50.07 42.57 39.52
Natural gas (per mcf) 7.41 7.59 6.69 7.50 7.72
after realized commodity
risk management 7.61 7.91 6.76 7.76 7.77
Natural gas liquids
(per bbl) 56.42 49.67 58.92 52.81 58.57
----------------------------------------------------------------------------
Total per boe 53.10 51.22 55.80 52.17 55.71
after realized commodity
risk management 54.39 53.30 54.91 53.85 54.98
----------------------------------------------------------------------------
Benchmark prices
WTI oil (U.S.$ per bbl) 64.98 58.23 70.72 61.63 67.13
AECO spot gas
(Cdn$ per gj) 6.99 7.07 5.95 7.03 7.37
NYMEX gas (U.S.$ per
mmbtu) 7.55 6.77 6.76 7.16 7.87
Currency (U.S.$/Cdn$) 0.90 0.87 0.89 0.88 0.88
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Realized Commodity Risk Management Gains (Losses)
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Light crude oil ($ millions) 5.5 9.0 (5.6) 14.5 (8.9)
Light crude oil ($ per bbl) 2.20 3.65 (3.00) 2.93 (2.36)
Natural gas ($ millions) 5.1 7.8 1.0 12.9 1.3
Natural gas ($ per mcf) 0.20 0.32 0.07 0.26 0.05
----------------------------------------------------------------------------
Combined ($ millions) 10.6 16.8 (4.6) 27.4 (7.6)
Combined ($ per boe) 1.29 2.08 (0.89) 1.68 (0.73)
----------------------------------------------------------------------------Commodity price contracts in place at June 30, 2007 are detailed in Note 14 to the consolidated financial statements. Additionally, the fair value of the outstanding contracts has been recorded on the balance sheet as a net asset of $32.8 million at period end. An unrealized loss of $4.3 million resulting from the change in fair value from January 1 to June 30, 2007 has been recognized on the statement of income (January 1 to June 30, 2006 - $3.4 million loss). An unrealized gain of $79.7 million resulting from the change in fair value from April 1 to June 30, 2007 has been recognized on the statement of income (April 1 to June 30, 2006 - $3.4 million loss). Oil and Gas Sales - Contribution Analysis ($ millions) Three months ended Six months ended ---------------------------------------------------------------------------- Sales June 30, % of Mar 31, % of June 30, % of June 30, % of June 30, % of Revenue 2007 total 2007 total 2006 total 2007 total 2006 total ---------------------------------------------------------------------------- Light crude oil 177.0 40 166.2 38 134.6 47 343.2 39 255.7 45 Natural gas 194.3 44 196.2 46 92.8 33 390.5 45 217.2 38 Natural gas liquids 43.8 10 44.3 10 31.9 11 88.1 10 64.7 11 Heavy oil 28.6 6 25.4 6 22.2 8 54.0 6 35.4 6 Brokered sales/ sulphur 0.3 - - - 2.0 1 0.3 - 2.4 - ---------------------------------------------------------------------------- Total oil and gas sales 444.0 432.1 283.5 876.1 575.4 ---------------------------------------------------------------------------- Oil and Gas Sales - Price and Volume Analysis The following table illustrates the effect of changes in prices and volumes on the components of oil and gas sales, including the impact of realized commodity risk management activity, for the second quarter of 2007 compared to the first quarter of 2007.
----------------------------------------------------------------------------
Light Natural Heavy
($ millions) oil gas NGL oil Other Total
----------------------------------------------------------------------------
Quarter ended March 31, 2007 166.2 196.2 44.3 25.4 - 432.1
Effect of change in product
prices 14.8 (4.9) 5.2 1.3 - 16.4
Effect of change in sales
volumes (0.4) 5.7 (5.8) 2.1 - 1.6
Effect of change in realized
commodity risk management
activities (3.5) (2.7) - - - (6.2)
Other (0.1) - 0.1 (0.2) 0.3 0.1
----------------------------------------------------------------------------
Quarter ended June 30, 2007 177.0 194.3 43.8 28.6 0.3 444.0
----------------------------------------------------------------------------The following table illustrates the effect of changes in prices and volumes on the components of oil and gas sales, including the impact of realized commodity risk management activity, for the first six months of 2007 compared to the same period of 2006.
----------------------------------------------------------------------------
Light Natural Heavy
($ millions) oil gas NGL oil Other Total
----------------------------------------------------------------------------
Period ended June 30, 2006 255.7 217.2 64.7 35.4 2.4 575.4
Effect of change in product
prices (18.2) (11.1) (9.6) 3.9 - (35.0)
Effect of change in sales
volumes 82.3 172.8 33.0 14.8 - 302.9
Effect of change in realized
commodity risk management
activities 23.4 11.6 - - - 35.0
Other - - - (0.1) (2.1) (2.2)
----------------------------------------------------------------------------
Period ended June 30, 2007 343.2 390.5 88.1 54.0 0.3 876.1
----------------------------------------------------------------------------
Processing and Other Income
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Processing, interest & other
income 5.0 4.7 4.1 9.7 7.9
$ per boe 0.62 0.58 0.80 0.60 0.76
----------------------------------------------------------------------------Processing, interest and other income is primarily derived from fees charged for processing and gathering third party gas, road use and oil and water processing. This income represents the partial recovery of operating expenses reported separately.
Royalties
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Royalty expense 84.0 81.6 45.3 165.6 110.6
$ per boe 10.30 10.06 8.84 10.18 10.61
----------------------------------------------------------------------------
Royalties as a percent of
sales 18.9% 18.9% 16.0% 18.9% 19.2%Royalties include Crown, freehold and overriding royalties as well as mineral taxes. The royalty rate for the second quarter of 2007 has increased from the second quarter of 2006. The lower royalty rate in the second quarter of 2006 was due to a $5 million positive adjustment to the SOEP royalties. The royalty rate for the first half of 2007 is lower than the same period in 2006 and should continue to decrease primarily from the CP properties' average royalty rate of approximately 15 percent. The outlook for 2007 is that royalties will average approximately 19 percent of Pengrowth's sales.
Operating Expenses
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Operating expenses 112.1 101.0 58.0 213.1 112.0
$ per boe 13.74 12.46 11.32 13.10 10.75
----------------------------------------------------------------------------Operating expenses increased eleven percent from the first quarter of 2007 or ten percent on a per boe basis. Higher maintenance and a full quarter of expenses related to the CP properties acquisition increased expenses $4 million. In addition, increased expenses were due to higher maintenance expenses at Quirk Creek, Judy Creek and Nipisi. Expenses for the second quarter of 2007 compared to the same period of 2006 increased $54 million. Operating expenses related to the CP properties ($25 million or $15.51 per boe), Esprit ($16 million or $12.58 per boe), and Carson Creek ($6 million or $13.91 per boe) acquisitions accounted for 87 percent of the increase. In addition, increased operations personnel and maintenance costs at Quirk Creek resulted in higher expenses. Operating expenses for the first half of 2007 compared to the first half of 2006 increased 90 percent or $101 million. In addition to the CP properties, Esprit Trust, Carson Creek and Dunvegan acquisitions ($89 million), higher maintenance at Swan Hills and Weyburn, a planned maintenance shutdown at Quirk Creek in June 2007, partly offset by lower utility costs at Tangleflags and Nipisi. Operating expenses include costs incurred to earn processing and other income which are reported separately. Pengrowth expects total operating expenses for 2007 of approximately $410 million or $13.00 per boe.
Net Operating Expenses
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Net operating expenses 107.0 96.3 53.9 203.3 104.1
$ per boe 13.12 11.88 10.51 12.50 9.99Included in the table above are operating expenses net of the previously reported processing and other income.
Transportation Costs
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Light oil transportation 0.8 0.4 0.5 1.2 1.0
$ per bbl 0.34 0.17 0.27 0.25 0.27
Natural gas transportation 2.3 2.2 1.2 4.5 2.5
$ per mcf 0.09 0.09 0.09 0.09 0.09
----------------------------------------------------------------------------Pengrowth incurs transportation costs for its product once the product enters a feeder or main pipeline to the title transfer point. The transportation cost is dependant upon third party rates and distance the product travels on the pipeline prior to changing ownership or custody. Oil transportation costs increased in the second quarter of 2007 due to additional transportation incurred related to the CP properties. Pengrowth has the option to sell some of its natural gas directly to premium markets outside of Alberta by incurring additional transportation costs. Pengrowth sells most of its natural gas without incurring significant additional transportation costs. Similarly, Pengrowth has elected to sell approximately 65 percent of its crude oil at market points beyond the wellhead but at the first major trading point, requiring minimal transportation costs.
Amortization of Injectants for Miscible Floods
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Purchased and capitalized 5.9 4.7 6.7 10.6 17.3
Amortization 8.6 9.5 8.5 18.1 16.5
----------------------------------------------------------------------------The cost of injectants (primarily natural gas and ethane) purchased for injection in miscible flood programs is amortized equally over the period of expected future economic benefit. The cost of injectants purchased in 2006 and 2007 is amortized over a 24 month period. As of June 30, 2007, the balance of unamortized injectant costs was $27.8 million. The amount purchased and capitalized was lower in the first half of 2007 compared to the same period in 2006 due to the timing of the program. It is expected that the program will increase in upcoming quarters and therefore higher amounts will be purchased. The value of Pengrowth's proprietary injectants is not recorded as an asset or a sale; the cost of producing these injectants is included in operating expenses. 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, heavy oil, natural gas and natural gas liquids production. Pengrowth recorded an average operating netback of $29.56 per boe in the second quarter of 2007 compared to $29.87 per boe in the first quarter of 2007 and $33.94 per boe for the second quarter of 2006. The decrease over the second quarter of 2006 is mainly due to slightly lower commodity prices and higher operating costs and royalties. The decrease from the first half of 2006 to the first half of 2007 is a result of lower commodity prices and higher operating costs which are partially offset by lower royalties. The sales price used in the calculation of operating netbacks is after realized commodity risk management.
----------------------------------------------------------------------------
Three months ended Six months ended
Combined Netbacks June 30, Mar 31, June 30, June 30, June 30,
($ per boe) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Sales price 54.39 53.30 54.91 53.85 54.98
Other production income 0.04 - 0.41 0.02 0.24
----------------------------------------------------------------------------
54.43 53.30 55.32 53.87 55.22
Processing, interest and
other income 0.62 0.58 0.80 0.60 0.76
Royalties (10.30) (10.06) (8.84) (10.18) (10.61)
Operating expenses (13.74) (12.46) (11.32) (13.10) (10.75)
Transportation costs (0.39) (0.32) (0.35) (0.35) (0.34)
Amortization of injectants (1.06) (1.17) (1.67) (1.11) (1.58)
----------------------------------------------------------------------------
Operating netback 29.56 29.87 33.94 29.73 32.70
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Three months ended Six months ended
Light Crude Netbacks June 30, Mar 31, June 30, June 30, June 30,
($ per bbl) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Sales price 71.81 67.24 72.67 69.52 67.91
Other production income 0.08 0.04 1.07 0.06 0.56
----------------------------------------------------------------------------
71.89 67.28 73.74 69.58 68.47
Processing, interest and
other income 0.34 0.35 0.50 0.34 0.54
Royalties (11.90) (9.88) (11.27) (10.89) (9.22)
Operating expenses (14.77) (13.14) (12.17) (13.95) (11.53)
Transportation costs (0.34) (0.17) (0.27) (0.25) (0.27)
Amortization of injectants (3.51) (3.84) (4.61) (3.67) (4.38)
----------------------------------------------------------------------------
Operating netback 41.71 40.60 45.92 41.16 43.61
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Three months ended Six months ended
Heavy Oil Netbacks June 30, Mar 31, June 30, June 30, June 30,
($ per bbl) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Sales price 43.52 41.54 50.07 42.57 39.52
Processing, interest and
other income 0.18 0.18 0.16 0.19 0.27
Royalties (5.33) (5.23) (4.75) (5.29) (3.14)
Operating expenses (15.37) (13.15) (16.03) (14.30) (15.09)
----------------------------------------------------------------------------
Operating netback 23.00 23.34 29.45 23.17 21.56
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Three months ended Six months ended
Natural Gas Netbacks June 30, Mar 31, June 30, June 30, June 30,
($ per mcf) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Sales price 7.61 7.91 6.76 7.76 7.77
Other production income - - 0.01 - 0.01
----------------------------------------------------------------------------
7.61 7.91 6.77 7.76 7.78
Processing, interest
and other income 0.16 0.15 0.23 0.16 0.20
Royalties (1.47) (1.67) (0.93) (1.57) (1.75)
Operating expenses (2.15) (2.01) (1.66) (2.08) (1.60)
Transportation costs (0.09) (0.09) (0.09) (0.09) (0.09)
----------------------------------------------------------------------------
Operating netback 4.06 4.29 4.32 4.18 4.54
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Three months ended Six months ended
NGLs Netbacks June 30, Mar 31, June 30, June 30, June 30,
($ per bbl) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Sales price 56.42 49.67 58.92 52.81 58.57
Royalties (17.53) (14.05) (17.67) (15.67) (21.97)
Operating expenses (13.57) (12.02) (10.20) (12.74) (9.41)
----------------------------------------------------------------------------
Operating netback 25.32 23.60 31.05 24.40 27.19
----------------------------------------------------------------------------Interest Interest expense decreased eight percent to $21.6 million in the second quarter from $23.4 million in the first quarter of 2007. Interest expense increased $15.1 million from $6.5 million in the second quarter of 2006, reflecting a higher average debt level resulting from the CP properties and Esprit Trust acquisitions combined with higher interest rates and standby fees in the quarter. Approximately 20 percent of Pengrowth's outstanding long term debt as at June 30, 2007 incurs interest expense payable in U.S. dollars and therefore remains subject to fluctuations in the U.S. dollar exchange rate.
General and Administrative (G&A) Expenses
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Cash G&A expense 14.7 15.1 8.1 29.8 15.6
$ per boe 1.81 1.86 1.59 1.83 1.50
Non-cash G&A expense 1.5 1.7 0.6 3.2 1.9
$ per boe 0.18 0.22 0.11 0.20 0.18
----------------------------------------------------------------------------
Total G&A 16.2 16.8 8.7 33.0 17.5
Total G&A ($ per boe) 1.99 2.08 1.70 2.03 1.68
----------------------------------------------------------------------------The cash component of G&A for the second quarter of 2007 compared to the first quarter of 2007 decreased three percent. In comparison to the second quarter of 2006, the cash component increased $6.6 million due to the transition services fee associated with the CP properties acquisition ($1.4 million), additional salaries and benefits resulting from the recent acquisitions ($2.3 million), higher rent and other professional fees. Cash G&A increased $14.2 million in the first half of 2007 compared to the same period of 2006. This is due to additional salaries and benefits resulting from the recent acquisitions ($5.3 million), the CP transition services fee ($3.0 million), legal fees associated with ongoing litigation ($0.8 million) and professional fees associated with tax matters ($0.9 million), higher rent and other professional fees. The CP transition contract finished on May 31, 2007. The non-cash component of G&A represents the compensation expense associated with Pengrowth's long term incentive programs including trust unit rights and deferred entitlement units. The increase in the second quarter and the first half of 2007 versus the same periods in 2006 is due to the significant increase in the number of employees due to recent acquisitions.
Management Fees
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Management Fee 3.0 3.2 3.4 6.2 7.6
$ per boe 0.37 0.39 0.65 0.38 0.73
----------------------------------------------------------------------------Commencing July 1, 2006, for the remaining three year term, the maximum fees payable to the Manager are limited to 60 percent of the fees that would have been payable under the original agreement or $12 million plus certain expenses, whichever is lower. The current agreement expires on June 30, 2009 and does not contain a further right of renewal. Taxes In determining its taxable income, the Corporation deducts payments made to the Trust, effectively transferring the income tax liability to unitholders thus reducing the Corporation's taxable income to nil. Under the Corporation's current distribution policy, at the discretion of the Board, funds can be withheld from distributable cash to fund future capital expenditures, repay debt or other corporate purposes. In the event withholdings increased sufficiently, the Corporation could become subject to taxation on a portion of its income in the future. This can be mitigated through various options including the issuance of additional trust units, increased tax pools from additional capital spending, modifications to the distribution policy or potential changes to the corporate structure. The CP properties acquisition resulted in Pengrowth recording an additional future tax liability of $310.6 million, representing the difference between the tax basis and the fair value assigned to the acquired assets. Bill C-52 Budget Implementation Act 2007 On October 31, 2006, the Minister of Finance announced legislative tax proposals which modify the taxation of certain flow-through entities including mutual fund trusts and their unitholders (the "October 31 Proposals"). The October 31 Proposals apply to a specified investment flow-through (SIFT) trust and apply a tax at the trust level on distributions of certain income from such SIFT trust at a rate of tax comparable to the combined federal and provincial corporate tax rate. These distributions will be treated as dividends to the trust unitholders. On March 19, 2007, the Government of Canada tabled in Parliament Bill C-52 Budget Implementation Act 2007 which contains the October 31 Proposals. As of June 22, 2007, Bill C-52 received Royal Assent thereby legislating the October 31 Proposals. Pengrowth believes that it is characterized as a SIFT trust and, as a result, is subject to the October 31 Proposals. The October 31 Proposals are to apply commencing January 1, 2007 for all SIFT trusts that begin to be publicly traded after October 31, 2006 and commencing January 1, 2011 for all SIFT trusts that were publicly traded on or before October 31, 2006. Subject to the qualification below regarding the possible loss of the four year grandfathering period in the case of undue expansion, it is expected that Pengrowth will not be subject to the October 31 Proposals until January 1, 2011. Under the previous provisions of the Tax Act, Pengrowth could generally deduct in computing its income for a taxation year any amount of income that it distributes to unitholders in the year and, on that basis, Pengrowth was generally not liable for any material amount of tax. Pursuant to the October 31 Proposals, commencing January 1, 2011, (subject to the qualification below regarding the possible loss of the four year grandfathering period in the case of undue expansion), Pengrowth will not be able to deduct certain of its distributed income (referred to as specified income). Pengrowth will become subject to a distribution tax on this specified income at a special rate estimated to be 31.5 percent. Pengrowth may lose the benefit of the four year grandfathering period if Pengrowth exceeds the limits on the issuance of new trust units and convertible debt that constitute normal growth during the grandfathering period (subject to certain exceptions). The normal growth limits are calculated as a percentage of Pengrowth's market capitalization of $4.8 billion on October 31, 2006 as follows: 40 percent for the period November 1, 2006 to December 31, 2007, 20 percent for each of 2008, 2009 and 2010. Unused portions may be carried forward until December 31, 2010. It is anticipated that the issuance of 21,100,000 trust units on December 8, 2006 for proceeds of $461 million will constitute a portion of the 40 percent normal growth limit for the period ending on December 31, 2007. Pursuant to the October 31 Proposals, the distribution tax will only apply in respect of distributions of income and will not apply to returns of capital. Future Income Taxes Future income tax is a non-cash item relating to temporary differences between the accounting and tax basis of Pengrowth's assets and liabilities and has no immediate impact on Pengrowth's cash flows. During the second quarter of 2007, Pengrowth recorded a future tax reduction of $147.7 million. Since the October 31 Proposals have received Royal Assent, the tax legislation is considered "substantively enacted" under Canadian accounting guidelines. As a result, we have recorded a future income tax reduction of approximately $71.1 million for the quarter ending June 30, 2007, resulting from the tax basis of the assets in the Trust exceeding their book basis. Other non-recurring items contributing to the second quarter reduction include the asset disposition program ($46.2 million) and tax rate reduction ($10.0).
Depletion, Depreciation and Accretion
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Depletion and depreciation 163.1 162.5 67.8 325.6 138.9
$ per boe 20.00 20.05 13.23 20.02 13.33
Accretion 6.5 6.5 3.9 13.0 7.2
$ per boe 0.79 0.81 0.76 0.80 0.69
----------------------------------------------------------------------------Depletion and depreciation of property, plant and equipment is provided on the unit of production method based on total proved reserves. The increase in 2007 rates for depletion and depreciation and accretion is due to the inclusion of the property, plant and equipment from the CP properties, Carson Creek and Esprit Trust acquisitions, over the applicable periods. Pengrowth's Asset Retirement Obligations (ARO) liability increased due to acquisitions and by the amount of accretion, which is a charge to net income as a result of the passage of time. Asset Retirement Obligations The total future ARO is estimated by management based on estimated costs to remediate, reclaim and abandon wells and facilities having regard for Pengrowth's working interest and the estimated timing of the costs to be incurred in future periods. Pengrowth has estimated the net present value of its total ARO to be $334.2 million as at June 30, 2007 (December 31, 2006 - $255.3 million), based on a total escalated future liability of $2,052 million (December 31, 2006 - $1,530 million). These costs are expected to be incurred over 50 years with the majority of the costs incurred between 2035 and 2054. A credit adjusted risk free rate of eight percent and an inflation rate of two percent per annum were used to calculate the net present value of the ARO. Capital Expenditures During the first half of 2007, Pengrowth spent $141.3 million on development and optimization activities. The largest expenditures were at Judy Creek ($19.0 million), Tangleflags ($8.4 million), Twining ($7.4 million), Carson Creek ($6.8 million), Swan Hills ($5.6 million), Weyburn ($5.6 million), SOEP ($4.8 million) and Wildmint ($4.6 million).
Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
($ millions) 2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Geological and geophysical 2.3 3.5 1.1 5.8 2.3
Drilling and completions 36.6 77.6 33.5 114.2 91.3
Plant and facilities 2.6 9.6 7.5 12.2 20.9
Land purchases 2.9 6.2 5.0 9.1 7.7
----------------------------------------------------------------------------
Development capital 44.4 96.9 47.1 141.3 122.2
Other capital 5.1 1.9 0.9 7.0 0.9
Total capital expenditures 49.5 98.8 48.0 148.3 123.1
----------------------------------------------------------------------------
Business acquisitions 0.6 922.7 - 923.3 -
----------------------------------------------------------------------------
Property acquisitions - - 3.5 - 53.3
Proceeds on property
dispositions (197.3) (74.7) (1.1) (272.0) (17.8)
----------------------------------------------------------------------------
Net capital expenditures
and acquisitions (147.2) 946.8 50.4 799.6 158.6
----------------------------------------------------------------------------Pengrowth currently anticipates capital expenditures for maintenance and development of approximately $275 million for 2007 and $25 million for other capital including leasehold improvements (net of tenant leasehold inducements), furniture and equipment for its new head office building. Acquisitions and Dispositions Pengrowth completed asset sales for proceeds of approximately $207 million ($197 million net of adjustments) in the second quarter of 2007 and $282 million ($272 million net of adjustments) for the first six months of 2007. The proceeds were used to partially repay the $600 million bridge facility. Pengrowth expects to realize additional proceeds of approximately $180 million bringing the total for 2007 to approximately $450 million from non-core property dispositions. Working Capital The working capital deficiency increased by $294.5 million from $149.9 million at December 31, 2006 to $444.4 million at June 30, 2007. Most of the increased working capital deficiency is attributable to an increase in short term bank indebtedness due to the CP properties acquisition which closed on January 22, 2007. The proceeds of the property disposition program have been applied to reduce the bank indebtedness in the first half of 2007. On July 13, 2007, additional revolving term debt capacity was used to fully repay the balance of the short term bank indebtedness which had $322 million outstanding at June 30, 2007. Pengrowth frequently operates with a working capital deficiency as a result of the fact that distributions related to two production months of operating income are payable to unitholders at the end of any month, but only one month of production is still receivable. For example, at the end of May, distributions related to April and May production months were payable on June 15 and July 15 respectively. April's production revenue, received on May 25, is temporarily applied against Pengrowth's term credit facility until the distribution payment on June 15. Financial Resources and Liquidity Pengrowth's capital structure is as follows:
As at As at As at
June 30 December 31 June 30
($ thousands) 2007 2006 2006
----------------------------------------------------------------------------
Term credit facilities 720,000 257,000 162,000
Senior unsecured notes 318,328 347,200 326,310
Working capital deficit 117,201 140,563 78,347
Note payable - - 20,000
Bank indebtedness 327,193 9,374 (1,197)
----------------------------------------------------------------------------
Net debt excluding convertible debentures 1,482,722 754,137 585,460
----------------------------------------------------------------------------
Convertible debentures 75,079 75,127 -
----------------------------------------------------------------------------
Net debt including convertible debentures 1,557,801 829,264 585,460
----------------------------------------------------------------------------
Trust unitholders' equity 2,913,152 3,049,677 1,430,850
Net debt excluding convertible debentures
as a percentage of total book
capitalization 33.7% 19.8% 29.0%
Net debt including convertible debentures
as a percentage of total book
capitalization 34.8% 21.4% 29.0%
----------------------------------------------------------------------------
12 months trailing cash flow from
operating activities 657,597 554,368 638,724
Net debt excluding convertible debentures
to cash flow from operating activities 2.3 1.4 0.9
Net debt including convertible debentures
to cash flow from operating activities 2.4 1.5 0.9
----------------------------------------------------------------------------The $729 million increase in net debt excluding convertible debentures from December 31, 2006 is attributable to the funds borrowed for the CP properties acquisition and Pengrowth's capital program. The net debt to cash flow is higher in the first half of 2007 compared to the same period in 2006 as a result of the increased debt levels associated with the CP properties, Esprit Trust and Carson Creek acquisitions and 12 months trailing cash flow from operating activities not including a full 12 month contribution from the acquired assets. Pengrowth funds its capital expenditures through a combination of cash withholdings, available credit from its bank credit facilities and proceeds from exercise of trust unit rights and the distribution reinvestment plan. The credit facilities and other sources of cash are expected to be sufficient to meet Pengrowth's near term capital requirements and provide the flexibility to pursue profitable growth opportunities. A significant decline in oil and natural gas prices could impact our access to bank credit facilities and our ability to fund operations, maintain distributions and pursue profitable growth opportunities. On June 15, 2007, Pengrowth increased its term credit facility and extended the maturity date to June 16, 2010. At June 30, 2007, Pengrowth maintained a $1.2 billion term credit facility and a $35 million operating line of credit. These facilities were reduced by drawings of $720 million and by $17 million in letters of credit outstanding at quarter end. Pengrowth remains well positioned to fund its 2007 development program and to take advantage of acquisition opportunities as they arise. At June 30, 2007, Pengrowth had approximately $489 million available to draw from its credit facilities. At June 30, 2007, Pengrowth also maintained a $600 million bridge facility which was drawn to fund the CP properties acquisition. The bridge facility was drawn by $322 million at June 30, 2007. On July 13, 2007, with proceeds from Pengrowth's increased term credit facility, Pengrowth fully repaid the remaining $322 million outstanding on the bridge facility that was due January 22, 2008. On July 26, 2007, Pengrowth closed a U.S. $400 million offering of notes issued on a private placement basis in the United States. The private placement consists of 6.35 percent notes due in 2017. The notes are unsecured and rank equally with Pengrowth's bank facilities and existing term notes. As of July 31, 2007, Pengrowth had unused credit capacity of approximately $580 million. Pengrowth does not have any off balance sheet financing arrangements. Pengrowth's U.S. $200 million senior unsecured notes, pound sterling denominated Pounds Sterling 50 million senior unsecured notes and the credit facilities have certain financial covenants which may restrict the total amount of Pengrowth's borrowings. The calculation for each ratio is based on specific definitions, is not in accordance with GAAP and cannot be readily replicated by referring to Pengrowth's financial statements. The financial covenants are different between the credit facilities and the senior unsecured notes and some of the covenants are summarized below: 1. Total senior debt should not be greater than three times Earnings Before Income Taxes Depreciation and Amortization (EBITDA) for the last four fiscal quarters 2. Total debt should not be greater than 3.5 times EBITDA for the last four fiscal quarters 3. Total senior debt should be less than 50 percent of total book capitalization 4. EBITDA should not be less than four times interest expense In the event that Pengrowth enters into a significant acquisition, certain credit facility financial covenants are relaxed for two fiscal quarters after the close of the acquisition. Pengrowth may also make certain pro forma adjustments in calculating the financial covenant ratios. The actual loan documents are filed on SEDAR as Other Material Contracts. As at June 30, 2007, Pengrowth was in compliance with all its financial covenants. Failing a financial covenant may result in one or more of Pengrowth's loans being in default. In certain circumstances, being in default of one loan may result in other loans to also be in default. In the event that Pengrowth was not in compliance with any one of the financial covenants in its credit facility or senior unsecured notes, Pengrowth would be in default of one or more of its loans and would have to repay the debt, refinance the debt or negotiate new terms with the debt holders and may have to suspend distributions to unitholders. As a result of the October 2, 2006 business combination with Esprit Trust, Pengrowth assumed all of Esprit Trust's 6.5 percent convertible unsecured subordinated debentures (the "debentures"). The debentures were originally issued on July 28, 2005 with interest paid semi-annually in arrears on June 30 and December 31 of each year. Each $1,000 principal amount of debentures is convertible at the option of the holder at any time into fully paid Pengrowth trust units at a conversion price of $25.54 per trust unit. The debentures mature on December 31, 2010. After December 31, 2008, Pengrowth may elect to redeem all or a portion of the outstanding Debentures at a price of $1,050 per debenture or $1,025 per debenture after December 31, 2009. As at June 30, 2007, the principal amount of debentures outstanding was $74.7 million. Distributable Cash and Distributions There is no standardized measure of distributable cash and therefore distributable cash, as reported by Pengrowth, may not be comparable to similar measures presented by other trusts. The following table provides a reconciliation of distributable cash and payout ratio:
($ thousands, except
per trust unit amounts) Three months ended Six months ended
----------------------------------------------------------------------------
June 30, Mar 31, June 30, June 30, June 30,
2007 2007 2006 2007 2006
----------------------------------------------------------------------------
Cash flows from
operating activities(1)249,960 136,429 126,800 386,389 283,160
Change in non-cash
operating working
capital(1) (51,428) 64,330 25,745 12,902 10,645
----------------------------------------------------------------------------
Funds generated from
operations 198,532 200,759 152,545 399,291 293,805
Change in
remediation trust
funds (1,598) (1,365) (279) (2,963) (670)
Distributable cash(2) 196,934 199,394 152,266 396,328 293,135
----------------------------------------------------------------------------
Capital expenditures (49,467) (98,785) (47,999) (148,252) (123,060)
Distributable cash
after capital 147,467 100,609 104,267 248,076 170,075
----------------------------------------------------------------------------
Distributions paid
or declared 184,327 183,534 120,597 367,861 240,899
Distributable cash
per trust unit 0.80 0.82 0.95 1.62 1.83
Distributions paid
or declared per
trust unit 0.75 0.75 0.75 1.50 1.50
Payout ratio(3) 94% 92% 79% 93% 82%
Payout ratio after
capital(4) 125% 182% 116% 148% 142%
(1) Prior year restated, see Note 1 to financial statements.
(2) Prior year restated to conform to current presentation.
(3) Payout ratio is calculated as distributions paid or declared divided
by distributable cash.
(4) Payout ratio after capital is calculated as distributions paid or
declared divided by distributable cash after capital.Pengrowth does not deduct capital expenditures when calculating distributable cash. As a result of the depleting nature of Pengrowth's oil and gas assets, some level of capital expenditures is required to minimize production declines while other capital is required to optimize facilities. Pengrowth's 2007 capital expenditures are projected to be insufficient to fully replace production. There can be no certainty that Pengrowth will be able to maintain productive capacity in future periods. While Pengrowth does deduct actual expenditures on ARO and contributions to remediation trust funds, no deduction is made for future remediation commitments or accretion expense charged to the ARO reported on the balance sheet as those obligations will be funded out of cash flow generated in the future. The distributable cash calculation makes no provision for the repayment of short or long term debt. Pengrowth's calculation of distributable cash also adds back changes in operating working capital. In times of commodity price volatility, including working capital changes results in cash flows from operations which may be inconsistent with actual results. Pengrowth calculates and presents distributable cash to provide investors with a measure of the changes in cash available to be distributed to unitholders. As a result of the volatility in commodity prices and changes in production levels, Pengrowth may not report the same amount of distributable cash in each period and may temporarily borrow to fund distributions recommended by the Board. Distributable cash is derived from producing and selling oil, natural gas and related products. As such, distributable cash is highly dependent on commodity prices. Pengrowth entered into forward commodity contracts to fix the commodity price and mitigate price volatility on a portion of its 2007 and 2008 sales volumes. Details of commodity contracts are contained in Note 14 to the financial statements. The Board of Directors and Management regularly monitor forecast distributable cash and payout ratio. When reviewing the level of distributions, the Board considers a number of factors, including expectations of future commodity prices, capital expenditure requirements, and the availability of debt and equity capital. Pursuant to the Royalty Indenture, the Board can establish a reserve for certain items including up to 20 percent of the Corporation's gross revenue to fund various costs including future capital expenditures, royalty income in any future period and future abandonment costs. Cash distributions are generally paid to unitholders on or about the 15th day of the second month following the month of production. Pengrowth paid $0.75 per trust unit as cash distributions during the second quarter of 2007. The following is a summary of recent monthly distributions and future key dates:
Distribution
Amount
per US $
Ex-Distribution Distribution Trust Amount
Date(i) Record Date Payment Date Unit (ii)
---------------------------------------------------------------------------
December 27, 2006 December 29, 2006 January 15, 2007 $0.25 $0.21
January 30, 2007 February 1, 2007 February 15, 2007 $0.25 $0.21
February 27, 2007 March 1, 2007 March 15, 2007 $0.25 $0.21
March 28, 2007 March 30, 2007 April 15, 2007 $0.25 $0.22
April 27, 2007 May 1, 2007 May 15, 2007 $0.25 $0.23
May 30, 2007 June 1, 2007 June 15, 2007 $0.25 $0.24
June 27, 2007 June 29, 2007 July 15, 2007 $0.25 $0.24
July 27, 2007 July 31, 2007 August 15, 2007 $0.25 $0.24
August 29, 2007 August 31, 2007 September 15, 2007
September 26, 2007 September 28, 2007 October 15, 2007
October 30, 2007 November 1, 2007 November 15, 2007
November 29, 2007 December 3, 2007 December 15, 2007
(i) To benefit from the monthly cash distribution, unitholders must
purchase or hold trust units prior to the ex-distribution date.
(ii) Before applicable withholding taxes.Taxability of Distributions At this time, Pengrowth anticipates that approximately 90 to 95 percent of 2007 distributions will be taxable to Canadian residents. 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. The following discussion relates to the taxation of Canadian unitholders only. Cash distributions are comprised of a return of capital portion which is tax deferred and return on capital portion which is taxable income. The return of capital portion reduces the cost base of a unitholders trust units for purposes of calculating a capital gain or loss upon ultimate disposition. For detailed tax information relating to non-residents, please refer to our website www.pengrowth.com. Summary of Quarterly Results The following table is a summary of quarterly results for 2007, 2006 and 2005. ---------------------------------------------------------- 2007 Q1 Q2 ---------------------------------------------------------- Oil and gas sales ($000's) 432,108 443,977 Net income/(loss) ($000's) (69,834) 271,659 Net income/(loss) per trust unit ($) (0.29) 1.11 Net income/(loss) per trust unit - diluted ($) (0.29) 1.10 Distributable cash ($000's) 199,394 196,934 Actual distributions paid or declared per trust unit ($) 0.75 0.75 Daily production (boe) 90,068 89,633 Total production (mboe) 8,106 8,157 Average realized price ($ per boe) 53.30 54.39 Operating netback ($ per boe) 29.87 29.56 ---------------------------------------------------------------------------- 2006 Q1 Q2 Q3 Q4 ---------------------------------------------------------------------------- Oil and gas sales ($000's) 291,896 283,532 287,757 350,908 Net income ($000's) 66,335 110,116 82,542 3,310 Net income per trust unit ($) 0.41 0.69 0.51 0.01 Net income per trust unit - diluted ($) 0.41 0.68 0.51 0.01 Distributable cash ($000's) 140,869 152,266 142,344 140,405 Actual distributions paid or declared per trust unit ($) 0.75 0.75 0.75 0.75 Daily production (boe) 58,845 56,325 58,344 77,614 Total production (mboe) 5,296 5,126 5,368 7,141 Average realized price ($ per boe) 55.04 54.91 53.67 49.24 Operating netback ($ per boe) 31.44 33.94 30.82 24.17 ---------------------------------------------------------------------------- 2005 Q1 Q2 Q3 Q4 ---------------------------------------------------------------------------- Oil and gas sales ($000's) 239,913 253,189 304,484 353,923 Net income ($000's) 56,314 53,106 100,243 116,663 Net income per trust unit ($) 0.37 0.34 0.63 0.73 Net income per trust unit - diluted ($) 0.37 0.34 0.63 0.73 Distributable cash ($000's) 126,144 134,779 157,915 189,379 Actual distributions paid or declared per trust unit ($) 0.69 0.69 0.69 0.75 Daily production (boe) 59,082 57,988 58,894 61,442 Total production (mboe) 5,317 5,277 5,418 5,653 Average realized price ($ per boe) 44.97 47.79 56.07 62.55 Operating netback ($ per boe) 27.70 29.26 33.94 38.81 Production has increased over the quarters as a result of the acquisitions completed by Pengrowth and internal development activities over these periods. Oil and gas sales have increased along with the increase in production. Changes in commodity prices have also impacted oil and gas sales but have been partially muted by risk management activity. Net income increased in 2005 along with the higher oil and gas sales. Net income in 2006 and 2007 has been impacted by non-cash charges, in particular depletion, depreciation and accretion and future taxes. Distributable cash has not been impacted by these charges and the level of distributions has been stable over these periods. Business Risks The amount of distributable cash available to unitholders and the value of Pengrowth trust units are subject to numerous risk factors. As the trust units allow investors to participate in the net cash flow from Pengrowth's portfolio of producing oil and natural gas properties, the principal risk factors that are associated with the oil and gas business include, but are not limited to, the following influences: - The prices of Pengrowth's products (crude oil, natural gas, and NGLs) fluctuate due to many factors including local and global market supply and demand, weather patterns, pipeline transportation and political stability. - The marketability of our production depends in part upon the availability, proximity and capacity of gathering systems, pipelines and processing facilities. Operational or economic factors may result in the inability to deliver our products to market. - Geological and operational risks affect the quantity and quality of reserves and the costs of recovering those reserves. Our actual results will vary from our reserve estimates and those variations could be material. - Government royalties, income taxes, commodity taxes and other taxes, levies and fees have a significant economic impact on Pengrowth's financial results. Changes to federal and provincial legislation including implementation of the October 31 Proposals governing such royalties, taxes and fees could have a material impact on Pengrowth's financial results and the value of Pengrowth trust units. - Oil and gas operations carry the risk of damaging the local environment in the event of equipment or operational failure. The cost to remediate any environmental damage could be significant. - Environmental laws and regulatory initiatives impact Pengrowth financially and operationally. We may incur substantial capital and operating expenses to comply with increasingly complex laws and regulations covering the protection of the environment and human health and safety. In particular, we may be required to incur significant costs to comply with future regulations to reduce greenhouse gas and other emissions. - Pengrowth's oil and gas reserves will be depleted over time and our level of distributable cash and the value of our trust units could be reduced if reserves and production are not replaced. The ability to replace production depends on Pengrowth's success in developing existing reserves, acquiring new reserves and financing this development and acquisition activity within the context of the capital markets. Additional uncertainty with new legislation may limit access to capital or increase the cost of raising capital. - Increased competition for properties will drive the cost of acquisitions up and expected returns from the properties down. - A significant portion of our properties are operated by third parties. If these operators fail to perform their duties properly, or become insolvent, we may experience interruptions in production and revenues from these properties or incur additional liabilities and expenses as a result of the default of these third party operators. - Increased activity within the oil and gas sector has increased the cost of goods and services and makes it more difficult to hire and retain professional staff. - Changing interest rates influence borrowing costs and the availability of capital. - Investors' interest in the oil and gas sector may change over time which would affect the availability of capital and the value of Pengrowth trust units. - Inflation may result in escalating costs which could impact unitholder distributions and the value of Pengrowth trust units. - Canadian / U.S. exchange rates influence revenues and, to a lesser extent, operating and capital costs. - The value of Pengrowth trust units is impacted directly by the related tax treatment of the trust units and the trust unit distributions, and indirectly by the tax treatment of alternative equity investments. Changes in Canadian or U.S. tax legislation could adversely affect the value of our trust units. These factors should not be considered to be exhaustive. Additional risks are outlined in the AIF of the Trust available on SEDAR at www.sedar.com. Subsequent Events On July 26, 2007, Pengrowth closed a U.S. $400 million offering of notes issued on a private placement basis in the United States. The private placement consists of 6.35 percent notes due in 2017. The notes are unsecured and rank equally with Pengrowth's bank facilities and existing term notes. Pengrowth has eliminated the $600 million bridge facility and maintained its $1.2 billion term credit facility, all other term notes and convertible debentures. Outlook At this time, Pengrowth has increased the average 2007 production guidance to between 85,000 to 87,500 boe per day from our existing properties. This estimate takes into account the expected divestiture during 2007 of approximately 8,900 boe per day production at the time of sale. The above estimate excludes the impact from other future acquisitions or divestitures. Pengrowth's total operating expenses for 2007 are expected to increase when compared to 2006 and are anticipated to total approximately $410 million or $13.00 per boe. On a per boe basis, G&A is anticipated to be approximately $2.20, which includes management fees of approximately $0.40 per boe. This increased guidance is largely due to the costs associated with the transition services agreement for the CP properties acquisition. Pengrowth currently anticipates capital expenditures for maintenance and development opportunities at existing properties of approximately $275 million for 2007. Two thirds of the 2007 program is expected to be spent on the drilling program and the remainder of the budget is expected to be spent on facility maintenance and optimization and land and seismic purchases. In addition to the 2007 development capital program, Pengrowth expects to invest $25 million for leasehold improvements (net of tenant leasehold inducements), furniture and equipment for its new head office building. Recent Accounting Pronouncements Effective January 1, 2007, Pengrowth prospectively adopted new Canadian accounting standards relating to financial instruments. The impacts of adopting the new standards are reflected in Pengrowth's current quarter results and prior year comparative financial statements have not been restated. While the new rules resulted in changes to how Pengrowth accounts for its financial instruments and comparability with prior periods, there were no material impacts on Pengrowth's current quarter financial results. For a description of the new accounting rules and the impact on Pengrowth's financial statements of adopting such rules, including the impact on Pengrowth's deferred financing charges, long term debt and deferred foreign exchange gains, see Note 1 to the unaudited interim financial statements for the quarter ending June 30, 2007. New Canadian accounting recommendations for capital disclosures have been issued which will require additional disclosure of both qualitative and quantitative information about objectives, policies and processes for managing capital. These recommendations are effective beginning January 1, 2008. New Canadian accounting recommendations for additional disclosures about financial instruments have been issued which will require disclosure and presentation of financial instruments about the nature and extent of risks arising from financial instruments to which Pengrowth is exposed. These recommendations are effective beginning January 1, 2008. Subsequent to June 30, 2007, new Canadian interpretive guidance has been released for the preparation and disclosure of distributable cash, income trusts and other indirect offerings. The guidance is effective for the third quarter 2007. Disclosure Controls and Procedures As a Canadian reporting issuer with securities listed on both the TSX and the NYSE, Pengrowth is required to comply with Multilateral Instrument 52-109 - Certification of Disclosure in Issuers' Annual and Interim Filings, as well as the Sarbanes Oxley Act (SOX) enacted in the United States. Both the Canadian and U.S. certification rules include similar requirements where both the Chief Executive Officer (CEO) and the Chief Financial Officer (CFO) must assess and certify as to the effectiveness of the disclosure controls and procedures as defined in Canada by Multilateral Instrument 52-109 Certification of Disclosure in Issuers' Annual and Interim Filings and in the United States by Rules 13a-15(e) and 15d-15(e) under the Securites Exchange Act of 1934, as amended. The CEO, James S. Kinnear, and the CFO, Christopher Webster, evaluated the effectiveness of Pengrowth's disclosure controls and procedures for the period ending June 30, 2007. This evaluation considered the functions performed by its Disclosure Committee, the review and oversight of all executive officers and the board, as well as the process and systems in place for filing regulatory and public information. Pengrowth's established review process and disclosure controls are designed to ensure that all required information, reports and filings required under Canadian securities legislation and United States securities laws are properly submitted and recorded in accordance with those requirements. Based on that evaluation, the CEO and CFO concluded that the design and operation of our disclosure controls and procedures were effective as at June 30, 2007 to ensure that information required to be disclosed by us in reports that we file under Canadian and U.S. securities laws is gathered, recorded, processed, summarized and reported within the time periods specified under Canadian and U.S. securities laws and is accumulated and communicated to the management of Pengrowth Corporation, including the CEO and CFO, to allow timely decisions regarding required disclosure as required under Canadian and U.S. securities laws. During the period ended June 30, 2007, no change occurred to Pengrowth's internal control over financial reporting that has materially affected or is reasonably likely to materially affect, Pengrowth's internal control over financial reporting. Management's evaluation specifically excluded the controls and procedures of the recently acquired CP properties. The acquisition and the accounting of the CP properties acquisition were included in our evaluation. CONFERENCE CALL AND CONTACT INFORMATION Pengrowth will hold a conference call beginning at 9:00 A.M. Mountain Time on Thursday, August 2, 2007 during which management will review Pengrowth's 2007 second quarter financial and operating results and respond to inquiries from the investment community. To participate callers may dial (866) 249-1964 or Toronto local (416) 644-3428. To ensure timely participation in the teleconference, callers are encouraged to dial in 10 to 15 minutes prior to commencement of the call to register. A live audio webcast will be accessible through the Presentations and Webcasts section of Pengrowth's website at www.pengrowth.com. The webcast will be archived on the Pengrowth website. A telephone replay will be available through to midnight Eastern Time on Thursday, August 16, 2007 by dialing (877) 289-8525 or Toronto local (416) 640-1917 and entering passcode number 21241656#. For further information about Pengrowth, please visit our website www.pengrowth.com or contact: Investor Relations, E-mail: investorrelations@pengrowth.com Telephone: (403) 233-0224 Toll Free: 1-888-744-1111 Facsimile: (403) 294-0051 Operations Review REVIEW OF DEVELOPMENT ACTIVITIES (All volumes stated below are net to Pengrowth unless otherwise stated) In the second quarter of 2007, Pengrowth's daily production averaged 89,633 boe per day and development capital totaled approximately $44.4 million with approximately 82 percent directed towards drilling and completions. Pengrowth participated in drilling 34 gross wells (15.3 net wells) with a success rate of 94 percent. In addition, Pengrowth participated in drilling three injection and one water disposal well (0.9 net). The relatively flat quarter over quarter production levels resulted from production additions associated with the Carson Creek, Esprit Trust and CP properties acquisitions as well as ongoing development activities primarily in the Northern business unit which includes new wells at Dunvegan and in the Southern business unit which includes new wells at Weyburn. These additions were offset by reduced activity during the quarter due to an early and extended spring break-up, completion of the second phase of our disposition program and natural production declines. During the quarter, Pengrowth added to its land position by acquiring 12,382 acres at Crown land sales in various areas to supplement our operations and provide opportunities for future drilling. Northern: Production in the second quarter of 2007 from Pengrowth's Northern business unit remained relatively stable quarter over quarter and averaged 12,699 boe per day with 48 percent of production comprised of natural gas and 52 percent crude oil and natural gas liquids (NGLs). Natural declines were offset by three months of production from new wells drilled at Elm, Weasel and Karr during the first quarter of 2007. After an active first quarter drilling program, particularly in winter-access only areas, Pengrowth did not drill any new operated wells during the second quarter. However, two partner-operated horizontal wells were drilled at Cutbank (27.5 percent working interest). One well was production tested at Cutbank yielding 6.7 mmcf per day (1.84 mmcf per day net). Capital development in the quarter totaled $9.7 million with 66 percent targeted towards drilling related activities including completions and tie-ins with the majority spent at Wildmint, Tupper and Elm. In addition, approximately 34 percent was targeted towards maintenance capital with projects being completed at Weasel and Dunvegan. Results of note include the start-up of the new well at Karr on May 12, 2007 with an initial production rate of 1 mmcf per day and a current rate of 1.4 mmcf per day and the start up of the new well at Weasel on June 7, 2007 with an initial production rate of 700 mcf per day. Central: The Central business unit averaged approximately 26,339 boe per day in the second quarter of 2007 with 67 percent of production comprised of crude oil and NGLs and 33 percent comprised of natural gas. Production volumes were down approximately five percent when compared to first quarter of 2007. This reduction is partially due to turnaround activities at Judy Creek, a production shut-in at Deer Mountain and unanticipated downtime during the quarter. However, on a year-to-date basis, production levels in the Central business unit are exceeding 2007 budget expectations. During the second quarter, capital development totaled approximately $18.5 million with approximately two thirds of capital spent on drilling related activities including completions and tie-ins with the remainder targeted mainly towards maintenance capital and seismic activity. There was no operated drilling activity during the second quarter. At the partner-operated Swan Hills Unit No. 1 (22.35 percent working interest), eight wells were drilled consisting of four oil wells, three injection wells and one water disposal well. The four oil wells had in aggregate production test rates of 500 boe per day (112 boe per day net). In addition, Pengrowth agreed to participate in a C02 pilot at the partner-operated South Swan Hills Unit (8.8 percent working interest). Other key activities during the quarter included the commencement of four new hydrocarbon miscible flood patterns at Judy Creek. One pattern began solvent injection during the quarter with the remaining three expected to begin solvent injection during the third quarter with pattern response expected in the latter half of the year. CO2 injection continues at the Judy Creek CO2 pilot project that began in February of 2007 and is expected to continue for 18 months with target injection rates of approximately 200 tonnes per day. At Carson Creek development activities added more than 100 boe per day through a combination of stimulations, reactivations and other optimization activities The 16-7-61-12 W5 well (working interest 23.8 percent) came onstream in the second quarter and has averaged 1.2 mmcf per day (0.29 mmcf per day net). The production is very liquids rich yielding 90 bbls per mmcf of condensate and natural gas liquids. Pengrowth obtained approval for one drilling location during the quarter and has initiated scoping in the gas unit to perform a field optimization study which should result in additional site-specific compression and well recompletions. In addition, interpretation began on the Carson Creek 3D seismic survey which was acquired in the first quarter of the year. The data will be used to generate infill drilling locations over the coming quarters. Southern: Production in the second quarter of 2007 averaged approximately 27,602 boe per day in the Southern business unit with 38 percent comprised of crude oil and NGLS and 62 percent natural gas. Year to date production is tracking slightly ahead of budgeted production levels and has increased by approximately five percent when compared to first quarter 2007 levels. Development capital for the second quarter of 2007 totaled approximately $9.1 million with the large majority targeted towards drilling activities and the balance on workover and maintenance costs. There was a high level of activity during the quarter with 27 gross (12.9 net) wells drilled. All but one well was successful which resulted in a 96.3 percent success rate. The drilling program included 7 gross (5.3 net) gas wells drilled at Twining, Berry, Three Hills, Sounding Lake and two coalbed methane (CBM) gas wells at Ghost Pine and Wimborne. Three of the gas wells have been initially tested at a combined rate of approximately 3.7 mmcf per day (3.4 mmcf per day net) and extended flow tests are underway to confirm these encouraging initial rates. At Parkdale/Claresholm, the last three commitment wells (2.3 net)of a four well farm-in have been drilled resulting in two oil wells (1.3 net) which had initial test rates of 355 boe per day (125 boe per day net). One well was drilled and abandoned. The first well of the farm-in program was drilled in the first quarter and was also tested during this quarter and resulted in a gas well with an initial rate of 450 mcf per day (150 mcf per day net). There were 17 gross (5.3 net) oil wells drilled at Weyburn, Nevis, Richdale and Twining during the second quarter and are expected to be tied in during the third quarter. One of the Twining wells had a significant uphole sand that will be tested in the third quarter and, depending on the results, may lead to additional opportunities in the area. Tie-ins and completions were delayed due to this year's extended spring break-up compounded by extremely wet field conditions. However, during the quarter, eight wells were placed on production at a number of producing properties including Aden, Manyberries, Mikwan, Three Hills and Sounding Lake. Initial production rates of 405 bbls per day were recorded for three oil wells (100 percent working interest) and five gas wells were brought on with combined gross production of 2.5 mmcf per day (combined net production of 1.9 mmcf). Olds: Production at the Olds business unit averaged 10,569 boe per day during the second quarter of 2007 comprised of 96 percent natural gas and associated NGLs and 4 percent crude oil. Production levels decreased slightly by two percent in the second quarter due in part to scheduled plant turnarounds at non-operated processing facilities in both Quirk Creek and High River. Capital spending in the quarter was targeted towards drilling related activities, maintenance and workover costs. There were no significant capital expenditures during the second quarter of 2007. There was no operated drilling activity in the second quarter; however, industry partners drilled two wells where Pengrowth retains a royalty. Both wells are expected to come onstream during the third quarter this year. Key activities during the quarter included: the completion of sulphur solvent treatments on three sour Wabamun wells at Olds which resulted in total production gains of approximately 300 mcf per day; one non-operated Ellerslie well came on production at an initial rate of 192 mcf per day net to Pengrowth; and the conclusion of facility upgrades at the new 2006 Quirk Creek well resulting in an overall gain of approximately 1.9 mmcf per day net to Pengrowth. Heavy: In the second quarter of 2007, production in the Heavy Oil business unit averaged 5,214 boe per day with 78 percent of production comprised of heavy oil and 22 percent comprised of natural gas. Second quarter production levels decreased approximately ten percent compared to first quarter 2007 due mainly to planned dispositions that closed during the quarter and delay in well repairs due to the extended spring break-up. During the quarter, capital development totaled approximately $6.7 million with the majority targeted towards drilling and related activities with the balance targeted towards facilities and workovers. Pengrowth drilled one gas well during the quarter for a success rate of 100 percent. This well production tested at a rate of 330 mcf per day and will be tied in during the third quarter. Other activities during the quarter included the completion and tie-in of 11 Viking gas wells (100 percent working interest) which were drilled in late 2006. Testing of the wells was initiated in June and was completed in July with all wells on production. Initial rates from the first ten wells averaged 190 mcf per day per well on a restricted flow rate. Completion and flow testing on the last well of a six gas well program at Primate, also drilled in late 2006, was concluded during the quarter. Combined initial test rates from four of the wells (100 percent working interest) were 5.7 mmcf per day and tie-in of these wells will proceed in the third quarter. Construction of the gathering line for the horizontal wells drilled at East Bodo late last year continued throughout the second quarter. The project is scheduled to be completed during the third quarter 2007 and is anticipated to reduce operating costs for these wells as the produced fluids will no longer need to be transported by truck. Also during the quarter, work was completed at Cactus which diverted produced fluid to the main North Cactus battery allowing Pengrowth to shut down the facilities at West Cactus resulting in maintenance and fuel gas cost reductions. SOEP: The Sable Offshore Energy Project (SOEP) produced approximately 41,864 mmcf of raw gas in the second quarter of 2007. Gross production averaged approximately 460 mmcf per day in the second quarter, an increase of 32 percent when compared to first quarter 2007 levels. Production is comprised of approximately 87 percent natural gas and 17 percent NGLs. Pengrowth's working interest is 8.4 percent in this ExxonMobil Canada operated property. Monthly raw gas production for April, May and June was 445 mmcf per day (37.4 mmcf per day net), 494 mmcf per day (41.6 mmcf per day net) and 440 mmcf per day (37 mmcf per day), respectively. Downtime associated with the Goldboro sales gas compressors in April and a compression platform shut in June due to mechanical issues resulted in the lower levels recorded during those months. Capital development during the quarter totaled $0.9 million and has been significantly reduced due to the completion of the compression project. Capital spending was mainly targeted towards maintenance during the quarter.
Consolidated Balance Sheets
(Stated in thousands of dollars)
(unaudited)
As at As at
June 30 December 31
2007 2006
----------------------------------------------------------------------------
ASSETS
CURRENT ASSETS
Accounts receivable $ 169,094 $ 151,719
Fair value of risk management contracts (Note 14) 25,071 37,972
----------------------------------------------------------------------------
194,165 189,691
FAIR VALUE OF RISK MANAGEMENT CONTRACTS (Note 14) 8,260 495
DEPOSIT ON ACQUISITION - 103,750
OTHER ASSETS (Note 3) 21,142 36,132
PROPERTY, PLANT AND EQUIPMENT 4,633,861 3,741,602
GOODWILL (Note 2) 657,191 598,302
----------------------------------------------------------------------------
$ 5,514,619 $ 4,669,972
----------------------------------------------------------------------------
----------------------------------------------------------------------------
LIABILITIES AND UNITHOLDERS' EQUITY
CURRENT LIABILITIES
Bank indebtedness (Note 5) $ 327,193 $ 9,374
Accounts payable and accrued liabilities 180,380 201,056
Distributions payable to unitholders 123,008 122,080
Due to Pengrowth Management Limited 3,138 2,101
Contract liabilities 4,840 5,017
----------------------------------------------------------------------------
638,559 339,628
FAIR VALUE OF RISK MANAGEMENT CONTRACTS (Note 14) 321 1,367
CONTRACT LIABILITIES 14,494 16,825
CONVERTIBLE DEBENTURES 75,079 75,127
LONG TERM DEBT (Note 4) 1,038,328 604,200
ASSET RETIREMENT OBLIGATIONS (Note 7) 334,171 255,331
FUTURE INCOME TAXES (Note 6) 500,515 327,817
TRUST UNITHOLDERS' EQUITY (Note 8)
Trust Unitholders' capital 4,410,716 4,383,993
Equity portion of convertible debentures 160 160
Contributed surplus 7,719 4,931
Deficit (Note 10) (1,505,443) (1,339,407)
----------------------------------------------------------------------------
2,913,152 3,049,677
----------------------------------------------------------------------------
SUBSEQUENT EVENTS (Note 16)
$ 5,514,619 $ 4,669,972
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See accompanying notes to the consolidated financial statements.
Consolidated Statements of Income and Deficit
(Stated in thousands of dollars)
(unaudited)
Three months ended | ||||