SYMBOL: PEY.UN - TSX
CALGARY, May 13 /CNW/ - Peyto Energy Trust ("Peyto") is pleased to present the operating and financial results for the first 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 - $0.44/mcfe ($2.66/boe), three months ending
March 31, 2009
- High heat content natural gas stream - Realized revenue of $6.34/mcfe
($38.04/boe) before hedging, $7.63/mcfe ($45.78/boe) after hedging,
three months ending March 31, 2009
- Low base general and administrative costs - $0.22/mcfe ($1.32/boe),
three months ending March 31, 2009
- High field netback - $6.27/mcfe ($37.62/boe) or 82% of revenue, three
months ending March 31, 2009
- High level of operatorship - operates over 97% of its production
- Cash distributions - cash distributions of $41.3 million were 70% of
funds from operations for the three months ended March 31, 2009
- Since inception, Peyto has raised a total of $410 million issuing
units from treasury, accumulated earnings of $983 million, and
distributed $851 million to unitholders
- Transparent capital structure - no convertible debentures, no
exchangeable shares, no stock options, no warrants
The first quarter of 2009 was highlighted by strong cash netbacks despite
weak natural gas prices and reduced activity due to changing royalty
incentives as illustrated by the following:
- Natural gas prices before hedges were 22% lower in Q1 2009 with
prices averaging $6.15/mcf versus $7.93/mcf in Q1 2008. After
hedging, gas prices were 10% lower at $7.68/mcf and $8.49/mcf
respectively
- Cash netbacks for the quarter averaged $5.70/mcfe ($34.23/boe) versus
$6.38/mcfe ($38.33/boe) a year ago which represents 75% of revenue or
a 75% pre-tax profit margin
- Capital expenditures - $13.0 million was invested into finding and
developing new natural gas reserves, down from $22.5 million in the
previous quarter, and down from $33.1 million in Q1 2008
- Production - decreased 6% from 122,048 mcfe/d (20,342 boe/d) in the
first quarter of 2008 to 114,128 mcfe/d (19,021 boe/d) in the first
quarter of 2009
- Per unit funds from operations - decreased 15% from the previous year
to $0.55/unit
- Hedging - a $13.3 million gain for the three months ending March 31,
2009 was realized
- A total of $41.3 million or $0.39/unit was distributed to unitholders
in the first quarter of 2009 out of $63.6 million in earnings or
$0.60/unit
- Net debt decreased $2.1 million from Q4 2008 to $490.6 million in Q1
2009 but was up 7% from $460.4 million in Q1 2008. This leaves
available borrowing capacity of $59 million on bank lines of
$550 million, secured by over $2.7 billion in Proved Producing assets
(2008 PP NPV5)
Natural gas volumes recorded in thousand cubic feet (mcf) are converted to barrels of oil equivalent (boe) using the ratio of six (6) thousand cubic feet to one (1) barrel of oil (bbl). Natural gas liquids and oil volumes in barrel of oil (bbl) are converted to thousand cubic feet equivalent (mcfe) using a ratio of one (1) barrel of oil to six (6) thousand cubic feet. This could be misleading if used in isolation as it is based on an energy equivalency conversion method primarily applied at the burner tip and does not represent a value equivalency at the wellhead.
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3 Months Ended Mar. 31 %
2009 2008 Change
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Operations
Production
Natural gas (mcf/d) 95,998 101,468 (5)%
Oil & NGLs (bbl/d) 3,022 3,430 (12)%
Thousand cubic feet equivalent
(mcfe/d @ 1:6) 114,128 122,048 (6)%
Barrels of oil equivalent
(boe/d @ 6:1) 19,021 20,342 (6)%
Product prices
Natural gas ($/mcf) 7.68 8.49 (10)%
Oil & NGLs ($/bbl) 44.46 83.45 (47)%
Operating expenses ($/mcfe) 0.44 0.45 (2)%
Transportation ($/mcfe) 0.11 0.11 -
Field netback ($/mcfe) 6.27 7.11 (12)%
General & administrative
expenses ($/mcfe) 0.22 0.20 10%
Interest expense ($/mcfe) 0.35 0.53 (34)%
Financial ($000, except per unit)
Revenue 78,423 104,428 (25)%
Royalties 8,290 19,264 (57)%
Funds from operations 58,607 70,955 (17)%
Funds from operations per unit 0.55 0.67 (18)%
Total distributions 41,309 44,798 (8)%
Total distributions per unit 0.39 0.42 (7)%
Payout ratio 70 63 11%
Earnings 63,574 32,440 96%
Earnings per diluted unit 0.60 0.31 94%
Capital expenditures 13,036 33,054 (61)%
Weighted average trust units
outstanding 105,920,194 105,744,338 -
As at December 31
Net debt (before future
compensation expense and
unrealized hedging gains) 490,570 460,397 7%
Unitholders' equity 580,221 477,499 22%
Total assets 1,271,770 1,179,705 7%
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Earnings 63,574 32,440
Items not requiring cash:
Provision for performance based
compensation 1,150 3,496
Future income tax expense (24,694) 15,733
Depletion, depreciation and
accretion 18,577 19,286
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Funds from operations(1) 58,607 70,955
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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 $13.0 million into drilling and connecting new Deep Basin gas wells in the first quarter of 2009. Drilling and completions accounted for $10.5 million, while wellsite equipment and pipelines accounted for $2.3 million. Additional seismic data and land was acquired for $0.2 million, making up the balance of the capital expenditures. On March 3, 2009 the Alberta government announced a new royalty incentive program that became effective April 1, 2009 and included both new drilling royalty credits and new production royalty relief. This announcement caused Peyto to halt new well spuds and new production startups until the program became effective in order to capture the available incentives. For this reason, activity in January and February 2009 made up over 90% of the capital spending.
In the first quarter, the Trust drilled 6 gross (5.5 net, 91% working interest) gas wells, completed 7 gross (6.5 net) gas zones and brought 3 gross (3 net) zones on production. Production for the quarter averaged 114,128 mcfe/d (19,021 boe/d) down from 122,048 mcfe/d (20,342 boe/d) in Q1 2008.
Transportation and operating costs in the first quarter 2009 were effectively flat from a year earlier at $0.11/mcfe ($0.69/boe) and $0.44/mcfe ($2.66/boe) respectively. Reduced methanol prices were primarily responsible for maintaining operating costs at this level despite a decline in production. Royalties to the province of Alberta totaled $8.3 million in the quarter, representing 11% of sales or $0.81/mcfe ($4.84/boe). Natural gas prices for the first quarter 2009 averaged $7.68/mcf, after hedging gains of $1.53/mcf, while liquids prices averaged $44.46/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 $6.27/mcfe ($37.62/boe) for the quarter or an 82% operating margin.
Peyto underwent its annual bank review in the quarter and after the engineering appraisal reaffirmed the high value of the reserve assets, the Trust's banking syndicate extended the $550 million revolving credit facility. Net debt for the quarter remained manageable at $490.6 million.
Activity Update
Peyto tied in 2 gross (1.6 net) wells between April 1, 2009 and spring breakup but was unable to commence any drilling operations in that time. The economic impact of the new "Three Point Royalty Incentive Program" has been reviewed and although it is not expected it will have a significant influence on the future drilling strategies of the Trust, it will provide additional economic return for new wells drilled within the program. It is anticipated that the capital program for the balance of 2009 will be achieved with two drilling rigs commencing operations after breakup. Activity will be spread throughout Peyto's core operational areas and include several exploratory ideas as well as an evaluation of the potential for horizontal multi-stage fracture technology.
So far, production for the second quarter has averaged 111.5 mmcfe/d. Peyto is continuously monitoring individual wells for their ability to generate positive funds flow during this period of low natural gas prices. By operating over 97% of production and having low operating costs, Peyto ensures that its gas wells are making money even when many others are not.
Marketing
The current global economic recession and reduced energy demand has created excess supply in North American natural gas. Fears that surplus international LNG might find its way to North America are exacerbating the situation. This has caused Alberta spot natural gas prices to drop to levels not experienced since 2002. While there is much speculation on when prices will recover, Peyto has, as of March 31 2009, committed to the forward sale of 15,670,000 gigajoules (GJ) of natural gas at an average price of $7.94/GJ or $9.29/mcf (representing a 17% premium heat content). Had these contracts been closed on March 31, 2009, the Trust would have realized a gain of $37.8 million.
The Trust continues 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
Although the current economic conditions discourage bringing on new production into a depressed natural gas price environment, Peyto continues to build upon its inventory of high quality Deep Basin drilling prospects. A recent personnel addition to the Trust's exploration team will strengthen this process. The profitability of drilling projects will continue to guide investment decisions while a low cost structure and strong hedge position offer significant protection during this period of low gas prices. Ongoing optimization of already low operating costs will ensure Peyto's competitive advantage is maintained.
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 first quarter financial results on Thursday, May 14th, 2009, at 9:00 a.m. Mountain Daylight Time (MDT), or 11:00 a.m. Eastern Daylight Time (EDT). To participate, please call 1-416-644-3423 (Toronto area) or 1-800-732-1073 for all other participants. The conference call will also be available on replay by calling 1-416-640-1917 (Toronto area) or 1-877-289-8525 for all other parties, using passcode 21304757 followed by the pound key (Number sign). The replay will be available at 11:00 a.m. MDT, 1:00 p.m. EDT Thursday, May 13th, 2009 until midnight EDT on Thursday, May 21st, 2009. The conference call can also be accessed through the internet at http://www.newswire.ca/en/webcast/viewEvent.cgi?eventID(equal sign)2642860. 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 first 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/Q12009MDandA.pdf and will be filed at SEDAR, www.sedar.com, at a later date.
Darren Gee President and CEO May 13, 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 disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.
Peyto Energy Trust
Consolidated Balance Sheets
($000)
(unaudited)
March 31, December 31,
2009 2008
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Assets
Current
Accounts receivable 56,645 65,662
Financial derivative instruments (Note 10) 35,296 27,788
Prepaid expenses and deposits 2,488 3,367
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94,429 96,817
Financial derivative instruments (Note 10) 2,546 2,458
Prepaid capital 2,188 3,069
Property, plant and equipment (Note 4) 1,172,607 1,177,902
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1,271,770 1,280,246
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Liabilities and Unitholders' Equity
Current
Accounts payable and accrued liabilities 26,992 48,854
Distributions payable 12,710 15,888
Provision for future performance based compensation 1,150 -
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40,852 64,742
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Long-term debt (Note 5) 510,000 500,000
Asset retirement obligations 9,726 9,479
Future income taxes 130,971 155,308
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650,697 664,787
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Unitholders' equity
Unitholders' capital (Note 6) 410,233 410,233
Accumulated earnings (Note 7) 132,503 110,238
Accumulated other comprehensive income 37,485 30,246
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580,221 550,717
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1,271,770 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)
For the three months ended March 31,
2009 2008
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Revenue
Oil and gas sales 65,163 100,126
Realized gain on hedges 13,260 4,302
Royalties (8,290) (19,264)
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Petroleum and natural gas sales, net 70,133 85,164
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Expenses
Operating (Note 8) 4,560 4,965
Transportation 1,178 1,160
General and administrative (Note 9) 2,238 2,202
Future performance based compensation provision 1,150 3,496
Interest on long term debt 3,550 5,882
Depletion, depreciation and accretion (Note 4) 18,577 19,286
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31,253 36,991
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Earnings before taxes 38,880 48,173
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Taxes
Future income tax (recovery) expense (24,694) 15,733
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Earnings for the period 63,574 32,440
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Earnings per unit (Note 6)
Basic and diluted 0.60 0.31
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See accompanying notes
Peyto Energy Trust
Consolidated Statements of Comprehensive Income (Loss)
($000 except per unit amounts)
(unaudited)
For the three months ended March 31,
2009 2008
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Earnings for the period 63,574 32,440
Other comprehensive income (loss)
Change in unrealized gain (loss) on cash
flow hedges 20,499 (38,765)
Realized (gain) on cash flow hedges (13,260) (4,302)
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Comprehensive income (loss) 70,813 (10,627)
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See accompanying notes
Peyto Energy Trust
Consolidated Statements of Accumulated Earnings and Accumulated Other
Comprehensive Income (Loss)
($000)
(unaudited)
For the three months ended March 31,
2009 2008
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Accumulated earnings, beginning of period 110,238 117,572
Earnings for the period 63,574 32,440
Distributions (Note 7) (41,309) (44,798)
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Accumulated earnings, end of period 132,503 105,214
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Accumulated other comprehensive income,
beginning of period 30,246 5,119
Other comprehensive income (loss) 7,239 (43,067)
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Accumulated other comprehensive income (loss),
end of period 37,485 (37,948)
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See accompanying notes
Peyto Energy Trust
Consolidated Statements of Cash Flows
($000)
(unaudited)
For the three months ended March 31,
2009 2008
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Cash provided by (used in)
Operating Activities
Earnings for the period 63,574 32,440
Items not requiring cash:
Future income tax (recovery) expense (24,694) 15,733
Depletion, depreciation and accretion 18,577 19,286
Change in non-cash working capital related to
operating activities (5,355) (14,976)
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52,102 52,483
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Financing Activities
Issue of trust units, net of costs - 3,932
Distribution paid (41,309) (44,798)
Increase in bank debt 10,000 10,000
Change in non-cash working capital related
to financing activities (3,178) 29
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(34,487) (30,837)
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Investing Activities
Additions to property, plant and equipment (13,036) (33,067)
Change in non-cash working capital related
to investing activities (4,579) (6,662)
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(17,615) (39,729)
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Net decrease in cash - (18,083)
Cash, beginning of period - 20,547
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Cash, end of period - 2,464
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See accompanying notes
Notes to Consolidated Financial Statements
(unaudited)
March 31, 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. Accounting Pronouncements
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 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 on the Trust's results of operations or financial
position.
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.
3. Accounts Receivable
($000) March 31, 2009 December 31, 2008
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Accounts receivable - general 49,377 58,394
Accounts receivable - income
taxes 7,268 7,268
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56,645 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 objection has been filed and a notice of appeal
will be filed shortly.
4. Property, Plant and Equipment
March 31, December 31,
2009 2008
($000) $ $
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Property, plant and equipment 1,564,907 1,551,789
Accumulated depletion and
depreciation (392,300) (373,887)
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1,172,607 1,177,902
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At March 31, 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 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 months ended March 31, 2009 was
2.8% (2008 - 5.4%).
6. Unitholders' Capital
Authorized: Unlimited number of voting trust units
Issued and Outstanding
Trust Units (no par value) ($000) Number of Units Amount
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Balance, December 31, 2008
and March 31, 2009 105,920,194 410,233
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Per Unit Amounts
Earnings per unit have been calculated based upon the weighted
average number of units outstanding for the three months ended
March 31, 2009 of 105,920,194 (2008 - 105,744,338). There are no
dilutive instruments outstanding.
7. Accumulated Distributions
The Trust paid total distributions to the unitholders in the
aggregate amount of $41.3 million in the three months ended March 31,
2009 of which all was settled in cash (2008 - total $44.8 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
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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) March 31, 2009 December 31, 2008
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Accumulated earnings,
beginning of period 919,435 740,038
Earnings for the period 63,574 179,397
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Total accumulated earnings 983,009 919,435
Total accumulated distributions (850,506) (809,197)
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Accumulated earnings,
end of period 132,503 110,238
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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 March 31
2009 2008
($000) $ $
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Field expenses 7,395 7,550
Processing and gathering income (2,835) (2,585)
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Operating expenses 4,560 4,965
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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 March 31
2009 2008
($000) $ $
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General and administrative expenses 2,739 2,694
Overhead recoveries (501) (492)
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Net General and administrative expenses 2,238 2,202
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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 March 31, 2009
are as follows:
Natural Gas Daily Price
Period Hedged Type Volume (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
As at March 31, 2009, the Trust had committed to the future sale of
15,670,000 gigajoules (GJ) of natural gas at an average price of
$7.94 per GJ. Had these contracts been closed on March 31, 2009, the
Trust would have realized a gain in the amount of $37.8 million. If
the AECO gas price on March 31, 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 March 31, 2009 the Trust entered into the following
contracts:
Natural Gas Daily Price
Period Hedged Type Volume (CAD)
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
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 period
ended March 31, 2009 would decrease by $1.3 million. 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 March 31, 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 March 31,
2009, approximately 33% was due from four companies (December 31,
2008 - 43%, three companies). Of the Trust's revenue for the period
ended March 31, 2009, approximately 83% was received from four
companies (December 31, 2008 - 90%, four 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 March 31, 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 March 31, 2009:
($000s) (less than) 1 Year 1-2 Years 2-5 Years Thereafter
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Accounts payable
and accrued
liabilities 26,992
Provision for
future performance
based compensation 1,150
Distributions
payable 12,710
Long-term debt(1) 510,000
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(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) March 31, 2009 December 31, 2008
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Unitholders' equity 580,221 550,717
Long-term debt 510,000 500,000
Working capital (surplus)
deficit (1) (53,577) (32,075)
---------------------------------------------------------------------
1,036,644 1,018,642
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---------------------------------------------------------------------
(1) Current liabilities less current assets (includes unrealized
hedging asset of $35.3 million)
12. Supplemental Cash Flow Information
Changes in non-cash working capital balances
Three Months Ended March 31
($000) 2009 2008
---------------------------------------------------------------------
Cash interest paid during the year 3,550 5,882
---------------------------------------------------------------------
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13. Contingencies and Commitments
Following is a summary of the Trust's commitments related to
operating leases as at March 31, 2009. The Trust has no other
contractual obligations or commitments as at March 31, 2009.
($000) March 31, 2009
---------------------------------------------------------------------
2009 903
2010 1,203
2011 903
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3,009
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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.
Peyto Exploration & Development Corp. Information
Officers
Darren Gee Glenn Booth
President and Chief Executive Vice-President, Land
Officer
Scott Robinson Stephen Chetner
Executive Vice-President and Corporate Secretary
Chief Operating Officer
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
%SEDAR: 00019597E