Peyto Energy Trust
TSX : PEY.UN

August 12, 2009 16:30 ET

Peyto Energy Trust Announces Second Quarter 2009 Results

CALGARY, ALBERTA--(Marketwire - Aug. 12, 2009) - Peyto Energy Trust (TSX:PEY.UN) ("Peyto") is pleased to present the operating and financial results for the second quarter of the 2009 fiscal year. Peyto is an explorer and producer of unconventional tight gas assets in Alberta's Deep Basin and using its trust structure is able to flow profits from the success of that business to its unitholders in the form of distributions.

Peyto is well known for owning high quality, sweet natural gas assets that exhibit long reserve life, low operating costs and high revenue per mcfe. The following summarizes the Trust's foundation:

- Long reserve life - Proved Producing 14 years, Total Proved 17 years, Proved plus Probable 23 years

- Low operating costs - $0.43/mcfe ($2.56/boe), three months ending June 30, 2009

- High heat content natural gas stream - Realized revenue of $4.52/mcfe ($27.12/boe) before hedging, $6.32/mcfe ($37.90/boe) after hedging, three months ending June 30, 2009

- Low base general and administrative costs - $0.19/mcfe ($1.16/boe), three months ending June 30, 2009

- High field netback - $5.23/mcfe ($31.35/boe) or 83% of revenue, three months ending June 30, 2009

- High level of operatorship - operates over 97% of its production

- Cash distributions - cash distributions of $39.2 million were 86% of funds from operations for the three months ending June 30, 2009

- Since inception, Peyto has raised a total of $500 million issuing units from treasury, accumulated earnings of $1.0 billion, and distributed $890 million to unitholders

- Transparent capital structure - no convertible debentures, no exchangeable shares, no stock options, no warrants

The second quarter of 2009 was highlighted by improved financial flexibility and strong margins, amid weak natural gas prices, as illustrated by the following:

- Closed an offering of 9,000,000 trust units at $10.50/unit for net proceeds of $89 million

- Net debt decreased $91.1 million from Q1 2009 to $399.5 million in Q2 2009 and was down 12% from $454.4 million in Q2 2008. This leaves available borrowing capacity of $150 million on bank lines of $550 million, secured by over $2.7 billion in Proved Producing assets (2008 PP NPV5)

- Natural gas prices before hedges were 62% lower in Q2 2009 with prices averaging $3.99/mcf versus $10.46/mcf in Q2 2008. After hedging, Q2 2009 gas prices were 34% lower at $6.14/mcf versus $9.32/mcf for the previous period

- Cash netbacks for the quarter averaged $4.65/mcfe ($27.82/boe) versus $6.94/mcfe ($41.70/boe) a year ago which represents 73% of revenue

- Capital expenditures - $4.7 million was invested into finding and developing new natural gas reserves, down from $13.0 million in the previous quarter, and down from $21.5 million in Q2 2008

- Production - decreased 8% from 117,175 mcfe/d (19,530 boe/d) in the second quarter of 2008 to 107,892 mcfe/d (17,982 boe/d) in the second quarter of 2009

- Per unit funds from operations - decreased 39% from the previous year to $0.43/unit

- Hedging - a $17.6 million gain for the three months ending June 30, 2009 was realized

- A total of $39.2 million or $0.37/unit was distributed to unitholders in the second quarter of 2009. For 2009 to date, $80.5 million has been distributed out of $92.8 million in earnings

Natural gas volumes recorded in thousand cubic feet (mcf) are converted to barrels of oil equivalent (boe) using the ratio of six (6) thousand cubic feet to one (1) barrel of oil (bbl). Natural gas liquids and oil volumes in barrel of oil (bbl) are converted to thousand cubic feet equivalent (mcfe) using a ratio of one (1) barrel of oil to six (6) thousand cubic feet. This could be misleading if used in isolation as it is based on an energy equivalency conversion method primarily applied at the burner tip and does not represent a value equivalency at the wellhead.



----------------------------------------------------------------------------
3 Months 6 Months
Ended June 30 % Ended June 30 %
2009 2008 change 2009 2008 change
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Operations
Production
Natural gas
(mcf/d) 90,191 97,819 (8)% 93,078 99,644 (7)%
Oil & NGLs
(bbl/d) 2,950 3,226 (9)% 2,986 3,430 (13)%
Thousand cubic
feet
equivalent
(mcfe/d @ 1:6) 107,892 117,175 (8)% 110,993 120,224 (8)%
Barrels of
oil
equivalent
(boe/d @ 6:1) 17,982 19,530 (8)% 18,499 19,936 (7)%
Realized
product prices
Natural gas
($/mcf) 6.14 9.32 (34)% 6.93 8.90 (22)%
Oil & NGLs
($/bbl) 43.42 107.45 (60)% 43.94 95.08 (54)%
Operating
expenses
($/mcfe) 0.43 0.43 - 0.44 0.44 -
Transportation
($/mcfe) 0.11 0.11 - 0.11 0.11 -
Field netback
($/mcfe) 5.23 7.69 (32)% 5.76 7.40 (22)%
General &
administrative
expenses
($/mcfe) 0.19 0.18 6% 0.21 0.19 11%
Interest
expense
($/mcfe) 0.39 0.56 (30)% 0.37 0.54 (31)%
Financial ($000,
except per unit)
Revenue 62,016 114,543 (46)% 140,439 218,971 (36)%
Royalties 5,417 26,861 (80)% 13,707 46,125 (70)%
Funds from
operations 45,527 74,113 (39)% 104,134 145,068 (28)%
Funds from
operations
per unit 0.43 0.70 (39)% 0.98 1.37 (28)%
Total
distributions 39,211 46,605 (16)% 80,520 91,403 (12)%
Total
distributions
per unit 0.37 0.44 (16)% 0.76 0.86 (12)%
Payout ratio 86 63 37% 77 63 22%
Earnings 29,189 31,412 (7)% 92,763 63,852 45%
Earnings per
diluted unit 0.28 0.30 (7)% 0.87 0.60 45%
Capital
expenditures 4,671 21,528 (78)% 17,707 54,587 (68)%
Weighted average
trust units
outstanding 106,315,789 105,920,194 - 106,119,089 105,876,470 -

As at June 30
Net debt
(before future
compensation
expense and
unrealized
hedging gains) 399,513 454,417 (12)%
Unitholders' equity 661,003 419,922 57%
Total assets 1,292,556 1,196,367 8%

Cash flows from
operating
activities 50,193 66,087 102,295 118,570
Provision for
performance
based
compensation (536) 5,349 614 8,845

Change in non-cash
working capital (4,130) 2,677 1,226 17,653
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Funds from
operations (1) 45,527 74,113 104,134 145,068
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(1) Funds from operations - Management uses funds from operations to
analyze the operating performance of its energy assets. In order to
facilitate comparative analysis, funds from operations is defined
throughout this report as earnings before performance based
compensation, non-cash and non-recurring expenses. Management believes
that funds from operations is an important parameter to measure the
value of an asset when combined with reserve life. Funds from
operations is not a measure recognized by Canadian generally accepted
accounting principles ("GAAP") and does not have a standardized
meaning prescribed by GAAP. Therefore, funds from operations, as
defined by Peyto, may not be comparable to similar measures presented
by other issuers, and investors are cautioned that funds from
operations should not be construed as an alternative to net earnings,
cash flow from operating activities or other measures of financial
performance calculated in accordance with GAAP. Funds from operations
cannot be assured and future distributions may vary.


Quarterly Review

Peyto invested $4.7 million into drilling and connecting new Deep Basin gas wells in the second quarter of 2009. The majority of this capital was spent in June following spring breakup access restrictions. Drilling and completions accounted for $3.1 million, while wellsite equipment and pipelines accounted for $1.5 million. Minor amounts were spent on additional land and seismic data, making up the balance of the capital expenditures.

In the second quarter, the Trust spud 3 gross (2.5 net, 83% working interest) gas wells and brought on production 2 gross (1.5 net) zones. No new completions were commenced in the quarter. Production for the quarter averaged 107,892 mcfe/d (17,982 boe/d) down from 117,177 mcfe/d (19,530 boe/d) in Q2 2008.

Peyto's industry leading operating costs of $0.43/mcfe ($2.56/boe) and transportation expenses of $0.11/mcfe ($0.67/boe) were maintained in Q2 2009, in line with the previous quarter and prior year period. Royalties totaled $5.4 million in the quarter, representing 8.7% of sales or $0.55/mcfe ($3.31/boe). Natural gas prices for the second quarter 2009 averaged $6.14/mcf, after hedging gains of $2.15/mcf, while liquids prices averaged $43.42/boe. The high heat content, premium gas price that Peyto achieved, elevated by hedging gains, combined with its low operating costs, transportation and royalty expense resulted in field netbacks of $5.23/mcfe ($31.35/boe) for the quarter. Subtracting G&A and interest expense of $0.19/mcfe and $0.39/mcfe respectively, reduced field netbacks to a corporate netback of $4.65/mcfe or 73% of revenue. Peyto believes this is one of the highest margins in the industry.

On June 26, 2009, Peyto closed an offering of 9,000,000 trust units at a price of $10.50 per unit. Net proceeds of this offering were used to initially pay down outstanding bank debt and will subsequently fund an increased capital program for the balance of the year.

Activity Update

Since the end of the second quarter, Peyto has been active with three drilling rigs in the Alberta Deep Basin. Two of the rigs are exploring in the Kakwa and Greater Sundance areas while the third rig is being used to develop proven reserves in the Nosehill and Oldman areas using horizontal multi-stage fracture technology. Along with early positive indicators from offsetting analog producers and the 3-point Crown royalty incentives, this technology is expected to yield greater profitability than can be achieved with traditional vertical wells.

Peyto continues to closely monitor existing producing wells for positive funds flow during this time of low natural gas prices. To date, only a few low rate wells have been shut in because of low gas prices (30 to 40 boe/d). This is a reflection of the high profitability of Peyto's production, even at low commodity prices. New production additions will be scheduled to maximize overall returns while at the same time allowing the Trust to further prove the enhanced profitability of new technologies.

Marketing

North American natural gas prices continue to come under pressure as storage volumes have reached record levels for this time of year and there continues to be excess supply. Further, the Canadian dollar has strengthened against its US counterpart, putting additional pressure on prices here. Alberta daily spot prices for July 2009 averaged $2.94/GJ, a price not seen since July of 2002. At the same time, there is a growing consensus that supply reductions caused by reduced North American drilling activity will eventually correct the over supply situation. This consensus is evidenced by stronger futures prices for this coming winter and beyond which are trading in excess of $5/GJ. Peyto has continued to secure these better future prices and as of June 30 2009, committed to the forward sale of 15,680,000 gigajoules (GJ) of natural gas at an average price of $7.38/GJ or $8.63/mcf (representing a 17% premium heat content). Had these contracts been closed on June 30, 2009, the Trust would have realized a gain of $39.2 million.

The Trust will continue to forward sell small portions of production, up to 24 months into the future, to secure prices for upcoming distributions and capital programs. This strategy has worked successfully in the past to smooth out much of the volatility in natural gas prices caused by periods of excess supply or demand.

Outlook

Current economic conditions remain challenging for natural gas producers. Peyto's strong hedge position and low cost structure give it a competitive advantage over others, allowing for the continued exploration and inventory development during this downturn in the natural gas cycle. Financial flexibility has been enhanced, ensuring that Peyto will be well positioned to respond at the front of the price recovery. A long reserve life means that the majority of the Trust's reserves will benefit from the higher gas prices which are forecast for the future. In the meantime, reduced industry activity levels have provided downward pressure on service costs allowing for Peyto to drill more wells with less capital. As a result of these improved efficiencies, the capital program has been expanded for 2009 to between $90 and $120 million.

Unitholders are encouraged to visit the Peyto website at www.peyto.com where there is a wealth of information designed to inform and educate investors.

Conference Call and Webcast

A conference call will be held with the senior management of Peyto to answer questions with respect to the 2009 second quarter financial results on Thursday, August 13th, 2009, at 9:00 a.m. Mountain Daylight Time (MDT), or 11:00 a.m. Eastern Daylight Time (EDT). To participate, please call 1- 416-340-8018 (Toronto area) or 1- 866-223-7781 for all other participants. The conference call will also be available on replay by calling 1-416-695-5800 (Toronto area) or 1-800-408-3053 for all other parties, using passcode 5317640. The replay will be available at 11:00 a.m. MDT, 1:00 p.m. EDT Thursday, August 13th, 2009 until midnight EDT on Wednesday, August 20th, 2009. The conference call can also be accessed through the internet at http://events.onlinebroadcasting.com/peyto/081309/index.php. After this time the conference call will be archived on the Peyto Energy Trust website at www.peyto.com.

Management's Discussion and Analysis

A copy of the second quarter report to Unitholders, including the Management's Discussion and Analysis, and unaudited interim financial statements and related notes is available at http://www.peyto.com/news/Q22009MDandA.pdf and will be filed at SEDAR, www.sedar.com , at a later date.

Darren Gee, President and CEO

August 11, 2009

Certain information set forth in this document and Management's Discussion and Analysis, including management's assessment of Peyto's future plans and operations, contains forward-looking statements. By their nature, forward-looking statements are subject to numerous risks and uncertainties, some of which are beyond these parties' control, including the impact of general economic conditions, industry conditions, volatility of commodity prices, currency fluctuations, imprecision of reserve estimates, environmental risks, competition from other industry participants, the lack of availability of qualified personnel or management, stock market volatility and ability to access sufficient capital from internal and external sources. Readers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise and, as such, undue reliance should not be placed on forward-looking statements. Peyto's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits Peyto will derive therefrom.




Peyto Energy Trust

Consolidated Balance Sheets
($000)

(unaudited)

June 30, December 31,
2009 2008

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Assets
Current
Cash 41,564 -
Accounts receivable (Note 3 and 10) 44,050 65,662
Financial derivative instruments (Note 10) 35,709 27,788
Prepaid expenses and deposits 5,809 3,367
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127,132 96,817
Financial derivative instruments (Note 10) 3,474 2,458
Prepaid capital 2,188 3,069
Property, plant and equipment (Note 4) 1,159,762 1,177,902
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1,292,556 1,280,246
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Liabilities and Unitholders' Equity
Current
Accounts payable and accrued liabilities 17,146 48,854
Distributions payable 13,790 15,888
Provision for future performance based compensation 614 -
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31,550 64,742
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Long-term debt (Note 5) 460,000 500,000
Asset retirement obligations 9,928 9,479
Future income taxes 130,075 155,308
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600,003 664,787
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Unitholders' equity
Unitholders' capital (Note 6) 499,644 410,233

Accumulated earnings (Note 7) 122,481 110,238
Accumulated other comprehensive income 38,878 30,246
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661,003 550,717
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1,292,556 1,280,246
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See accompanying notes

On behalf of the Board:

(signed) "Michael MacBean" (signed) "Darren Gee"
Director Director


Peyto Energy Trust

Consolidated Statements of Earnings
($000 except per unit amounts)

(unaudited)

Three Months Ended Six Months Ended
June 30 June 30
2009 2008 2009 2008

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Revenue
Oil and gas sales 44,386 124,682 109,549 224,809
Realized gain (loss) on hedges 17,629 (10,139) 30,890 (5,838)
Royalties (5,417) (26,861) (13,707) (46,125)
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Petroleum and natural gas sales, net 56,598 87,682 126,732 172,846
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Expenses
Operating (Note 8) 4,197 4,580 8,757 9,545
Transportation 1,094 1,133 2,272 2,293
General and administrative(Note 9) 1,904 1,918 4,142 4,121
Future performance based
compensation provision (536) 5,349 614 8,845
Interest on long term debt 3,876 5,938 7,426 11,819
Depletion, depreciation and
accretion (Note 4) 17,718 17,842 36,295 37,128
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28,253 36,760 59,506 73,751
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Earnings before taxes 28,345 50,922 67,226 99,095
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Taxes
Future income tax (recovery)
expense (844) 19,510 (25,537) 35,243
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----------------------------------------------------------------------------
Earnings for the period 29,189 31,412 92,763 63,852
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Earnings per unit (Note 6)
Basic and diluted 0.28 0.30 0.87 0.60
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See accompanying notes


Peyto Energy Trust

Consolidated Statements of Comprehensive Income (Loss)
($000 except per unit amounts)

(unaudited)


Three Months Ended Six Months Ended
June 30 June 30
2009 2008 2009 2008

----------------------------------------------------------------------------
Earnings for the period 29,189 31,412 92,763 63,852
Other comprehensive income (loss)
Change in unrealized gain (loss) on
cash flow hedges 19,022 (52,534) 39,522 (91,289)
Realized (gain) loss on cash flow
hedges (17,629) 10,150 (30,890) 5,838
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Comprehensive income (loss) 30,582 (10,972) 101,395 (21,599)
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See accompanying notes


Peyto Energy Trust

Consolidated Statements of Accumulated Earnings and Accumulated Other
Comprehensive Income (Loss)
($000)

(unaudited)

Three Months Ended Six Months Ended
June 30 June 30
2009 2008 2009 2008

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Accumulated earnings, beginning of
period 132,503 105,214 110,238 117,572
Net earnings for the period 29,189 31,412 92,763 63,852
Distributions (Note 7) (39,211) (46,605) (80,520) (91,403)
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Accumulated earnings, end of period 122,481 90,021 122,481 90,021
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Accumulated other comprehensive
income (loss), beginning of period 37,485 (37,948) 30,246 5,119
Other comprehensive income (loss) 1,393 (42,384) 8,632 (85,451)
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Accumulated other comprehensive
income (loss), end of period 38,878 (80,332) 38,878 (80,332)
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See accompanying notes


Peyto Energy Trust

Consolidated Statements of Cash Flows
($000)

(unaudited)

Three Months Ended Six Months Ended
June 30 June 30
2009 2008 2009 2008

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Cash provided by (used in)
Operating Activities
Earnings for the period 29,189 31,412 92,763 63,852
Items not requiring cash:
Future income tax expense (844) 19,510 (25,537) 35,243
Depletion, depreciation and
accretion 17,718 17,842 36,295 37,128
Change in non-cash working capital
related to operating activities 4,130 (2,677) (1,226) (17,653)
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50,193 66,087 102,295 118,570
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Financing Activities
Issuance of trust units 94,500 - 94,500 3,932
Issuance costs (5,089) - (5,089) -
Distributions declared (Note 7) (39,211) (46,605) (80,520) (91,403)
Increase (decrease) in bank debt (50,000) 10,000 (40,000) 20,000
Change in non-cash working capital
related to financing activities 1,081 1,059 (2,097) 1,088
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1,281 (35,546) (33,206) (66,383)
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Investing Activities
Additions to property, plant and
equipment (4,671) (21,520) (17,707) (54,587)
Change in non-cash working capital
related to investing activities (5,239) (5,759) (9,818) (12,421)
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(9,910) (27,279) (27,525) (67,008)
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Net increase (decrease) in cash 41,564 3,262 41,564 (14,821)
Cash, beginning of period - 2,464 - 20,547
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Cash, end of period 41,564 5,726 41,564 5,726
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See accompanying notes


Peyto Energy Trust

Notes to Consolidated Financial Statements

(unaudited)

June 30, 2009 and 2008

1. Summary of Significant Accounting Policies

The unaudited interim consolidated financial statements of Peyto Energy Trust (the "Trust" or "Peyto") follow the same accounting policies as the most recent annual audited consolidated financial statements. The interim consolidated financial statement note disclosures do not include all of those required by Canadian generally accepted accounting principles ("GAAP") applicable for annual financial statements. Accordingly, these interim financial statements should be read in conjunction with the 2008 audited consolidated financial statements.

These financial statements include the accounts of Peyto Energy Trust and its wholly owned subsidiaries, Peyto Exploration & Development Corp., Peyto Operating Trust, Peyto Energy Limited Partnership and Peyto Energy Administration Corp.

2. Changes in Accounting Policies

Current Year Accounting Changes

Goodwill and Intangible Assets

On January 1, 2009, the Trust retrospectively adopted the Canadian Institute of Chartered Accountants (CICA) Section 3064, Goodwill and Intangible Assets issued by the Accounting Standards Board ("AcSB"). This section clarifies the criteria for the recognition of assets, intangible assets and internally developed intangible assets. Adoption of this standard did not have an impact the Trust's results of operations or financial position.

Credit Risk and the Fair Value of Financial Assets and Financial Liabilities

Effective January 1, 2009, the Trust adopted the CICA Emerging Issues Committee (EIC) Abstract No.173, Credit Risk and the Fair Value of Financial Assets and Financial Liabilities (EIC 173). EIC 173 clarifies how an entity's own credit risk and that of the relevant counterparty should be taken into account in determining the fair value of financial assets and financial liabilities, including derivative instruments. The new guidance did not have any impact on the financial position or earnings of the Trust.

Business Combinations

On January 1, 2009, the Trust prospectively adopted CICA Section 1582, Business Combinations issued by the AcSB. This section establishes principles and requirements of the acquisition method for business combinations and related disclosures. Adoption of this statement did not have an impact on the Trust's results of operations or financial position.

Consolidated Financial Statements and Non-Controlling Interests

On January 1, 2009, the Trust adopted CICA Sections 1601, Consolidated Financial Statements, and 1602, Non-Controlling Interests issued by the AcSB. Section 1601 establishes standards for the preparation of consolidated financial statements. Section 1602 provides guidance on accounting for non-controlling interests in consolidated financial statements subsequent to a business combination. Adoption of this statement did not have an impact on the Trust's results of operations or financial position.

Pending Accounting Pronouncements

Financial Instruments - Disclosures

In May 2009, the CICA amended Section 3862, Financial Instruments - Disclosures, to include additional disclosure requirements about fair value measurement for financial instruments and liquidity risk disclosures. These amendments require a three level hierarchy that reflects the significance of the inputs used in making the fair value measurements. Fair values of assets and liabilities included in Level 1 are determined by reference to quoted prices in active markets for identical assets and liabilities. Assets and liabilities in Level 2 include valuations using inputs other than quoted prices for which all significant outputs are observable, either directly or indirectly. Level 3 valuations are based on inputs that are unobservable and significant to the overall fair value measurement. These amendments are effective for the Trust on December 31, 2009.



3. Accounts Receivable

($000) June 30, 2009 December 31, 2008
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Accounts receivable - general 36,782 58,394
Accounts receivable - income taxes 7,268 7,268
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44,050 65,662
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Canada Revenue Agency ("CRA") has conducted an audit of restructuring costs claimed as a result of the Trust conversion in 2003 that has resulted in the reclassification of $41.0 million dollars in employment related costs as eligible capital. In October, 2008, the Trust received a notice of reassessment from the CRA and paid an amount of $7.3 million related to this audit. Based upon consultation with legal counsel, Management's view is that CRA's position has no merit. A notice of appeal was filed May 19, 2009 and the appeal has been denied. Examination for discovery is being scheduled.



4. Property, Plant and Equipment

($000) June 30, 2009 December 31, 2008
----------------------------------------------------------------------------
Property, plant and equipment 1,569,616 1,551,789
Accumulated depletion and depreciation (409,854) (373,887)
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1,159,762 1,177,902
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At June 30, 2009 costs of $40.3 million (December 31, 2008 - $36.8 million) related to undeveloped land have been excluded from the depletion and depreciation calculation.

5. Long-Term Debt

The Trust has a syndicated $550 million extendible revolving credit facility with a stated term date of April 30, 2010. The facility is made up of a $20 million working capital sub-tranche and a $530 million production line. The facilities are available on a revolving basis for a period of at least 364 days and upon the term out date may be extended for a further 364 day period at the request of the Trust, subject to approval by the lenders. In the event that the revolving period is not extended, the facility is available on a non-revolving basis for a further one year term, at the end of which time the facility would be due and payable. Outstanding amounts on this facility bear interest at rates determined by the Trust's debt to cash flow ratio that range from prime to prime plus 0.75% for debt to earnings before interest, taxes, depreciation, depletion and amortization (EBITDA) ratios ranging from less than 1:1 to greater than 2.5:1. A General Security Agreement with a floating charge on land registered in Alberta is held as collateral by the bank. The average borrowing rate for the three and six months ended June 30, 2009 was 3.1% and 3.0% respectively (2008 - 5.4% and 5.4% respectively).



6. Unitholders' Capital

Authorized: Unlimited number of voting trust units

Issued and Outstanding
Trust Units (no par value) ($000) Number of Units Amount
----------------------------------------------------------------------------
Balance, December 31, 2008 105,920,194 410,233
Trust units issued 9,000,000 94,500
Trust unit issuance costs - (5,089)
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Balance, June 30, 2009 114,920,194 499,644
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On June 26, 2009, Peyto closed an offering of 9,000,000 trust units at a price of $10.50 per trust unit, receiving net proceeds of $89 million.

Per Unit Amounts

Earnings per unit have been calculated based upon the weighted average number of units outstanding for three months ended June 30, 2009 of 106,315,798 (2008 - 105,920,194) and for the six months ended June 30, 2009 of 106,119,089 (2008 - 105,876,470). There are no dilutive instruments outstanding.

7. Accumulated Distributions

The Trust declared total distributions to the unitholders in the aggregate amount of $39.2 million in the three months ended June 30, 2009 (2008 - total $46.6 million) and $80.5 million for the six months ended June 30, 2009 (2008 - total $91.4 million) in accordance with the following schedule:



Production Period Record Date Distribution Date Per Unit (1)
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January 2009 January 31, 2009 February 13, 2009 $0.15
February 2009 February 28, 2009 March 13, 2009 $0.12
March 2009 March 31, 2009 April 15, 2009 $0.12
April 2009 April 30, 2009 May 15, 2009 $0.12
May 2009 May 31, 2009 June 15, 2009 $0.12
June 2009 June 30, 2009 July 15, 2009 $0.12
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(1) Distributions per trust unit reflect the sum of the per trust unit
amounts declared monthly to unitholders.


Accumulated Earnings and Distributions
($000) June 30, 2009 December 31, 2008
----------------------------------------------------------------------------
Accumulated earnings, beginning of period 919,435 740,038
Earnings for the period 92,763 179,397
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Total accumulated earnings 1,012,198 919,435
Total accumulated distributions (889,717) (809,197)
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Accumulated earnings, end of period 122,481 110,238
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8. Operating Expenses

The Trust's operating expenses include all costs with respect to day-to-day well and facility operations. Processing and gathering income related to joint venture and third party natural gas reduces operating expenses.



Three Months Ended June 30 Six Months Ended June 30
($000) 2009 2008 2009 2008
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Field expenses 6,728 7,328 14,096 14,878
Processing and
gathering income (2,531) (2,748) (5,339) (5,333)
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Total operating costs 4,197 4,580 8,757 9,545
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9. General and Administrative Expenses (G & A)

General and administrative expenses are reduced by operating and capital overhead recoveries on operated properties.



Three Months Ended June 30 Six Months Ended June 30
($000) 2009 2008 2009 2008
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General and
administrative expenses 2,270 2,579 5,008 5,468
Overhead recoveries (366) (661) (866) (1,347)
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Net general and
administrative expenses 1,904 1,918 4,142 4,121
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10. Financial Instruments and Risk Management

Market Risk

Market risk is the risk that changes in market prices will affect the Trust's net earnings or the value of its financial instruments. Market risk is comprised of commodity price risk and interest rate risk. The objective of market risk management is to manage and control its exposures within acceptable limits, while maximizing returns. The Trust's objectives, processes and policies for managing market risks have not changed from the previous year.

Commodity Price Risk Management

The Trust is a party to certain derivative financial instruments, including fixed price contracts. The Trust enters into these contracts with well established counterparties for the purpose of protecting a portion of its future earnings and cash flows from operations from the volatility of commodity prices. The Trust believes the derivative financial instruments are effective as hedges, both at inception and over the term of the instrument, as the term and notional amount do not exceed the Trust's firm commitment or forecasted transaction and the underlying basis of the instrument correlates highly with the Trust's exposure. A summary of contracts outstanding in respect of the hedging activities at June 30, 2009 are as follows:



Natural Gas
Period Hedged Type Daily Volume Price (CAD)
----------------------------------------------------------------------------
April 1, 2009 to October 31, 2009 Fixed price 5,000 GJ $7.85/GJ
April 1, 2009 to October 31, 2009 Fixed price 5,000 GJ $8.12/GJ
April 1, 2009 to October 31, 2009 Fixed price 5,000 GJ $8.95/GJ
April 1, 2009 to October 31, 2009 Fixed price 5,000 GJ $9.30/GJ
April 1, 2009 to October 31, 2009 Fixed price 5,000 GJ $10.20/GJ
April 1, 2009 to October 31, 2009 Fixed Price 5,000 GJ $7.50/GJ
April 1 , 2009 to March 31, 2010 Fixed Price 5,000 GJ $7.65/GJ
April 1 , 2009 to March 31, 2010 Fixed Price 5,000 GJ $6.90/GJ
November 1, 2009 to March 31, 2010 Fixed Price 5,000 GJ $8.39/GJ
November 1, 2009 to March 31, 2010 Fixed Price 5,000 GJ $8.35/GJ
November 1, 2009 to March 31, 2011 Fixed Price 5,000 GJ $6.20/GJ
November 1, 2010 to March 31, 2011 Fixed Price 5,000 GJ $8.91/GJ
November 1, 2010 to March 31, 2011 Fixed Price 5,000 GJ $9.15/GJ
November 1 , 2009 to March 31, 2011 Fixed price 5,000 GJ $5.81/GJ
April 1, 2010 to October 31, 2010 Fixed price 5,000 GJ $6.10/GJ
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As at June 30, 2009, the Trust had committed to the future sale of 15,680,000 gigajoules (GJ) of natural gas at an average price of $7.38 per GJ. Had these contracts been closed on June 30, 2009, the Trust would have realized a gain in the amount of $39.2 million. If the AECO gas price on June 30, 2009 were to increase by $1/GJ, the unrealized gain on these closed contracts would change by approximately $15.7 million. An opposite change in commodity prices rates will result in an opposite impact on earnings which would have been reflected in the other comprehensive income of the Trust.



Subsequent to June 30, 2009 the Trust entered into the following contract:

Natural Gas
Period Hedged Type Daily Volume Price (CAD)
----------------------------------------------------------------------------
November 1 , 2009 to October 31, 2010 Fixed price 5,000 GJ $5.20/GJ
----------------------------------------------------------------------------
----------------------------------------------------------------------------


Interest rate risk

The Trust is exposed to interest rate risk in relation to interest expense on its revolving credit facility. Currently, the Trust has not entered into any agreements to manage this risk. If interest rates applicable to floating rate debt were to have increased by 100 bps (1%) it is estimated that the Trust's earnings for the three and six month periods ended June 30, 2009 would decrease by $1.3 million and $2.5 million respectively. An opposite change in interest rates will result in an opposite impact on earnings.

Fair Values of Financial Assets and Liabilities

The Trust's financial instruments include cash, accounts receivable, financial derivative instruments, current liabilities (excluding future income tax), provision for future performance based compensation and long term debt. At June 30, 2009, the carrying value of cash, accounts receivable, financial derivative instruments, current liabilities and provision for future performance based compensation approximate their fair value. The carrying value of the long term debt approximates its fair value due to the floating rate of interest charged under the credit facility.

Credit Risk

A substantial portion of the Trust's accounts receivable is with petroleum and natural gas marketing entities.

Industry standard dictates that commodity sales are settled on the 25th day of the month following the month of production. The Trust generally extends unsecured credit to these companies, and therefore, the collection of accounts receivable may be affected by changes in economic or other conditions and may accordingly impact the Trust's overall credit risk. Management believes the risk is mitigated by the size, reputation and diversified nature of the companies to which they extend credit. The Trust has not previously experienced any material credit losses on the collection of accounts receivable. Of the Trust's significant individual accounts receivable at June 30, 2009, approximately 29% was due from four companies (December 31, 2008 - 43%, three companies). Of the Trust's revenue for the six months ended June 30, 2009, approximately 89% was received from four companies (June 30, 2008 - 83%, three companies). The maximum exposure to credit risk is represented by the carrying amount on the balance sheet. There are no material financial assets that the Trust considers past due and no accounts have been written off.

The Trust may be exposed to certain losses in the event of non-performance by counterparties to commodity price contracts. The Trust mitigates this risk by entering into transactions with counter-parties that have investment grade credit ratings, in accordance with policy as established by the Board of Directors. Counterparties for derivative instrument transactions are limited to financial institutions which are all members of our syndicated credit facility.

The Trust assesses quarterly if there should be any impairment of financial assets. At June 30, 2009, there was no impairment of any of the financial assets of the Trust.

Liquidity Risk

Liquidity risk includes the risk that, as a result of operational liquidity requirements:

- The Trust will not have sufficient funds to settle a transaction on the due date;

- The Trust will be forced to sell financial assets at a value which is less than what they are worth; or

- The Trust may be unable to settle or recover a financial asset at all.

The Trust's operating cash requirements, including amounts projected to complete our existing capital expenditure program, are continuously monitored and adjusted as input variables change. These variables include, but are not limited to, available bank lines, oil and natural gas production from existing wells, results from new wells drilled, commodity prices, cost overruns on capital projects and changes to government regulations relating to prices, taxes, royalties, land tenure, allowable production and availability of markets. As these variables change, liquidity risks may necessitate the need for the Trust to conduct equity issues or obtain project debt financing.

The following are the contractual maturities of financial liabilities as at June 30, 2009:



($000s) less than 1 Year 1-2 Years 2-5 Years Thereafter
----------------------------------------------------------------------------
Accounts payable
and accrued
liabilities 17,146
Distributions
payable 13,790
Provision for
future
performance
based compensation 614
Long-term debt(1) 460,000
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1)Revolving credit facility renewed annually (see Note 5)


11. Capital Disclosures

The Trust's objectives when managing capital are: (i) to maintain a flexible capital structure, which optimizes the cost of capital at acceptable risk; and (ii) to maintain investor, creditor and market confidence to sustain the future development of the business.

The Trust manages its capital structure and makes adjustments to it in light of changes in economic conditions and the risk characteristics of our underlying assets. The Trust considers its capital structure to include unitholders' equity, debt and working capital. To maintain or adjust the capital structure, the Trust may from time to time, issue trust units, raise debt and/or adjust its capital spending to manage its current and projected debt levels. The Trust monitors capital based on the following non-GAAP measures: current and projected debt to earnings before interest, taxes, depreciation, depletion and amortization ("EBITDA") ratios, payout ratios and net debt levels. To facilitate the management of these ratios, the Trust prepares annual budgets, which are updated depending on varying factors such as general market conditions and successful capital deployment. Currently, all ratios are within acceptable parameters. The annual budget is approved by the Board of Directors. The Trust's unitholders' capital is not subject to any external financial covenants.

There were no changes in the Trust's approach to capital management from the previous year.



($000s) June 30, 2009 December 31, 2008
----------------------------------------------------------------------------
Unitholders' equity 661,003 550,717
Long-term debt 460,000 500,000
Working capital (surplus) deficit (1) (95,582) (32,075)
----------------------------------------------------------------------------
1,025,421 1,018,642
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(1)Current liabilities less current assets (includes unrealized hedging
asset of $35.7 million)


12. Supplemental Cash Flow Information

Three Months Ended June 30 Six Months Ended June 30
($000) 2009 2008 2009 2008
----------------------------------------------------------------------------
Cash interest paid
during the period 3,876 5,938 7,426 11,819
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13. Contingencies and Commitments

Following is a summary of the Trust's commitments related to operating leases as at June 30, 2009. The Trust has no other contractual obligations or commitments as at June 30, 2009.



($000) June 30, 2009
----------------------------------------------------------------------------

2009 97
2010 1,036
2011 1,036
2012 1,036
Thereafter 2,072
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5,277
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Contingent Liability

From time to time, Peyto is the subject of litigation arising out of its day-to-day operations. Damages claimed pursuant to such litigation, may be material or may be indeterminate and the outcome of such litigation may materially impact Peyto's financial position or results of operations in the period of settlement. While Peyto assesses the merits of each lawsuit and defends itself accordingly Peyto may be required to incur significant expenses or devote significant resources to defending itself against such litigation. These claims are not currently expected to have a material impact on Peyto's financial position or results of operations.

14. Subsequent Events

On July 6, 2009, the Trust repaid $40,000,000 on the revolving credit facility.



Peyto Exploration & Development Corp. Information

Officers

Darren Gee Glenn Booth
President and Chief Executive Officer Vice-President, Land

Scott Robinson Stephen Chetner
Executive Vice-President and Chief Operating Officer Corporate Secretary

Kathy Turgeon
Vice-President, Finance and Chief Financial Officer


Directors
Don Gray, Chairman
Michael MacBean, Lead Independent Director
Rick Braund
Brian Davis
Darren Gee
Gregory Fletcher
Stephen Chetner

Auditors
Deloitte & Touche LLP

Solicitors
Burnet, Duckworth & Palmer LLP

Bankers
Bank of Montreal
Union Bank, Canada Branch
BNP Paribas (Canada)
Royal Bank of Canada
Alberta Treasury Branches
Societe Generale (Canada Branch)
HSBC Bank Canada
Canadian Western Bank

Transfer Agent
Valiant Trust Company

Head Office
2900, 450 - 1st Street SW
Calgary, AB
T2P 5H1

Phone: 403.261.6081
Fax: 403.451.4100
Web: www.peyto.com

Stock Listing Symbol: PEY.UN
Toronto Stock Exchange

Contact Information

  • Peyto Energy Trust
    Darren Gee
    President & CEO
    (403) 237-8911
    (403) 451-4100 (FAX)
    Website: www.peyto.com