Perpetual Energy Inc. Releases Year End 2010 Financial and Operating Results, Updates 2011 Capital Spending Program and Operational Activities and Confirms March 2011 Dividend
By Perpetual Energy Inc., PRNEMonday, March 7, 2011
Please note all Dollars are Canadian
CALGARY, Alberta, March 8, 2011 - Perpetual Energy Inc. ("Perpetual" or the "Corporation") is pleased to
release its fourth quarter and year end 2010 financial and operating results.
Perpetual's natural gas price hedging program combined with strong operating
results led the Corporation to post strong funds flow for the year ending
2010 despite extremely weak natural gas prices related to high gas storage
levels and concerns about new supply.
Perpetual also confirms that its dividend to be paid on April 15, 2011 in
respect of income received by Perpetual for the month of March 2011, for
shareholders of record on March 22, 2011, will be $0.03 per share. The
ex-dividend date is March 18, 2011. The March 2010 dividend brings cumulative
dividends (including distributions paid since the inception of Perpetual's
predecessor, Paramount Energy Trust) to $14.414 per share. Perpetual reviews
dividends on a monthly basis. Future dividends are subject to change as
dictated by commodity price markets, operations, capital considerations and
future business development opportunities.
Until further notice, there will be no shares available under the Premium
Dividend(TM) and Dividend Reinvestment Plan (the "Plan"). At such time as the
Corporation elects to reinstate either or both components of the Plan,
shareholders that were enrolled at suspension and remain enrolled at
reinstatement will automatically resume participation in the Plan.
Perpetual's Board of Director's also today approved a $42 million capital
expenditure budget for the final three quarters of 2011 bringing the total
budget for the year to $90 million, including gas storage. Capital activity
for the remainder of the year will continue to be focused on oil and
liquids-rich projects including Wilrich drilling at Edson and Lloyd/Sparky
horizontal drilling in eastern Alberta.
A copy of Perpetual's audited consolidated financial statements and
related management's discussion and analysis ("MD&A") can be obtained through
the Corporation's website at www.perpetualenergyinc.com and SEDAR at
www.sedar.com.
2010 Annual Highlights
Corporate Activity
- On June 30, 2010, the corporate conversion of Paramount Energy Trust
into Perpetual Energy Inc. was completed. Trading of the common
shares of Perpetual began on July 6, 2010.
- Perpetual declared dividends of $75.8 million or $0.56 per Share in
2010, representing a payout ratio of 33.2 percent of funds flow for
the year.
- Dividends for the fourth quarter of 2010 totaled $0.11 per
Share, including $0.05 per Share paid on November 15, 2010,
and $0.03 per Share paid on December 15, 2010 and January 17,
2011. Perpetual's payout ratio was 23.1 percent for the quarter.
Financial
- Perpetual reduced net bank debt by 20 percent from $270.8 million at
December 31, 2009 to $214.5 million at December 31, 2010. Including
Perpetual's convertible debentures of $234.9 million, total net debt
dropped 10 percent from $501.0 million at December 31, 2009 to $449.4
million at December 31, 2010.
- Operating costs decreased 13 percent to what Perpetual believes to be
a sustainable level of $1.64 per Mcfe, for an annual cost of $91.2
million in 2010 as compared to $105.1 million ($1.83 per Mcfe) in
2009, primarily due to lower repair and maintenance costs and higher
processing income.
- Funds flow increased three percent to $237.2 million in 2010 as
compared to $231.3 million for 2009 due primarily to higher oil and
NGL production and lower operating costs.
- The Corporation's effective royalty rate for 2010 of 5.3 percent of
revenues was 33 percent less than 2009 and lower than the
Corporation's historical royalty rates due to lower AECO gas prices,
realized gains on financial instruments and a recovery of $1.5
million in royalties related to prior years.
- The Corporation recorded a net loss of $28.5 million ($0.20 per basic
and diluted Share) in 2010 as compared to net earnings of
$13.6 million ($0.11 per basic and diluted Share) in 2009.
Production and Pricing
- Daily average actual and deemed production was essentially unchanged
year over year at 177.4 MMcfe/d in 2010 as compared to 177.6 MMcfe/d
in 2009.
- Daily average production decreased three percent to 152.6 MMcfe/d in
2010 as a result of the full year effect of gas over bitumen shut-ins
in late 2009, non-core asset dispositions and natural production
declines, partially offset by the Edson acquisition and successful
drilling activities during the year.
- Due to successful Cardium, Wilrich and Mannville drilling programs in
the second half of 2010, oil and NGL production increased 73 percent
to 1,245 Bbl/d in 2010 as compared to 721 Bbl/d in 2009.
- The Corporation's realized gas price including financial hedging and
physical forward sales, increased marginally to $7.10 per Mcfe in
2010 from $7.09 per Mcfe in 2009, as both average AECO gas prices and
Perpetual's hedging gains were fairly constant from year to year.
- Perpetual's hedging and risk management program continued to provide
a measure of stability to realized prices and funds flow in 2010
through the realization of $155.0 million in gains on financial
instruments and $1.9 million in call option premiums.
- The Corporation's realized gas price for the fourth quarter 2010 was
$7.83 per Mcfe, a 33 percent increase from the comparable quarter in
2009, driven by realized hedging gains of $49.4 million in the
quarter as compared to $20.5 million in 2009.
- Perpetual's realized oil & NGL price increased 10 percent to $68.29
per bbl in 2010 from $61.91 per bbl in 2009.
Reserves
- In 2010, Perpetual added 71.8 Bcfe (12.0 MMboe) of proved and
probable reserves, replacing 129% of its production.
- After dispositions of 53.1 Bcfe (8.9 MMboe) and production of 55.9
Bcfe (9.3 MMboe) in 2010, proved and probable reserves increased
three percent from 471.6 Bcfe (78.6 MMboe) at year-end 2009 to 487.7
Bcfe (81.3 MMboe) and proved reserves increased two percent to 250.4
Bcfe (41.7 MMboe) at year-end 2010.
- Including changes in future development capital ("FDC"), Perpetual
realized finding and development costs ("F&D") of $1.69 per Mcfe
($10.14 per BOE) on a proved and probable reserve basis in 2010.
- Perpetual's realized finding, development and acquisition costs
("FD&A"), including changes in FDC, was $2.16 per Mcfe ($12.96 per
BOE) on a proved and probable basis.
Exploration and Development Capital Activity
- Exploration and development capital spending increased to $115.2
million in 2010 from $57.4 million in 2009, as Perpetual accelerated
drilling activities on high-impact resource plays in west central
Alberta obtained through various acquisitions and grassroots
exploration efforts.
- Capital spending of $2.9 million was allocated to Perpetual's new
ventures areas.
- Eastern district expenditures of $39.4 million were concentrated on
low-cost shallow gas recompletions to maintain production levels, the
drilling and completion of nine gas and oil wells (7.5 net) in
Birchwavy, facilities optimization projects designed to reduce
production costs and evaluation of the Corporation's oilsands leases
at Panny and Marten Hills.
- West Central District capital spending totaled $59.1 million,
directed primarily to Cardium and Wilrich delineation and
development.
- Perpetual drilled 70 gross wells (63.9 net) in 2010 as compared to 52
gross (42.2 net) in 2009 with a 98 percent success rate. Drilling
activity included 48 gross (44.3 net) natural gas wells, 14 gross
(11.6 net) oil wells and 6 gross (6.0 net) wells at Perpetual's gas
storage facility.
- Land acquisitions totaled $13.8 million in 2010, a $10.3 million
increase from 2009 levels. Acquisitions included several exploratory
parcels in the Caroline, Waskahigan and Del Bonita areas of Alberta,
as well as additional land purchases in the West Central district and
minor maintenance acreage purchases in the Eastern district.
Acquisitions and Dispositions
- Acquisition spending totaled $141.9 million, including the
acquisition of oil and natural gas assets in the Edson area of west
central Alberta ("Edson Acquisition") and an acquisition of shallow
natural gas production in eastern Alberta for $16.6 million.
- Disposition proceeds increased to $91.3 million, including the
receipt of $7.1 million in shares of TriOil Resources Ltd., in 2010
from $26.6 million in 2009. The current year total includes the
disposal of shut-in gas over bitumen assets for $39.8 million, minor
oil and gas property dispositions in Birchwavy East and Athabasca,
and the sale of producing non-core assets in west central Alberta.
- As part of the disposition agreements for the shut-in gas over
bitumen assets, Perpetual will continue to receive the gas over
bitumen financial solution royalty reductions related to the sold
wells, although effective ownership of the natural gas reserves will
be transferred to the buyers. As a result, Perpetual expects there
will be no material impact on future funds flow as a result of this
disposition.
Wilrich
- Through the Edson Acquisition, Perpetual obtained lands prospective
for the undeveloped Wilrich formation. Capital spending on this play
in 2010 included the drilling of five wells (4.5 net) targeting
liquids-rich gas, completion and tie-in of
three wells and the expansion of a compressor station at Edson to
increase processing capacity by 20 MMcf/d plus associated liquids of
40 bbl/MMcf. The expanded infrastructure is expected to be operating
at full capacity in March 2011.
Cardium
- As part of the Edson Acquisition, Perpetual negotiated a farm-in
arrangement on 37 gross (31 net) sections of undeveloped Cardium
rights in the Edson area of which 22 net sections are believed by
Perpetual to be prospective for light oil. The farm-in includes a two
well horizontal drilling and completion commitment, each earning 50
percent of the vendor's net interest in four sections followed by a
rolling option to earn the additional lands on the same basis. In
2010 Perpetual drilled two Cardium wells (1.2 net) fulfilling its
farm-in commitment.
- Including the two well earning commitment, the Corporation drilled
and completed five Cardium oil wells (3.2 net) during 2010 to
delineate the potential for Cardium tight oil development on its
lands at Carrot Creek and Edson.
- Results from the five wells drilled in 2010 averaged the expected
type curve for the tight oil play, with initial production rates
averaging 125-150 boe/d. The top decile producer in Carrot Creek has
been the focus of Perpetual's follow-up development activity in the
first quarter of 2011, where four gross wells have been drilled and
are currently undergoing completion operations.
Elmworth Montney
- The first and second wells of a three-well commitment were drilled by
Perpetual's joint venture partner into the Montney formation at
Elmworth, as part of a previously announced farm-out agreement. The
first two wells were completed and flow-tested at approximately 7.5
MMcf/d of raw natural gas with 20 bbl/MMcf of condensate with an
additional estimated 25 to 45 bbl/MMcf of recoverable associated
natural gas liquids per MMcf, depending on processing. The third well
was rig released on January 11, 2011 and was completed later that
month. Difficulties encountered during completion restricted the flow
test but the extent of the resource was established as expected.
- Perpetual established 14.5 Bcfe (2.4 MMboe) of proven and 32.1 Bcfe
(5.3 MMboe) of proved and probable reserves at Elmworth net to
Perpetual's interest. Using the GLJ January 1, 2011 price forecast,
the net present value of the reserves discounted at 8 percent is
estimated at $14.7 million for proved reserves and $43.6 million for
total proved and probable reserves net to Perpetual, including
recovery of future development capital ("FDC").
Warwick Gas Storage ('WGSI")
- Capital expenditures for the fourth quarter of 2010 of $11.2 million
were incurred to finalize the construction and the final testing of
the Corporation's gas storage facility at Warwick, Alberta ("WGSI
Facility"). Full year 2010 expenditures totaled $57.6 million.
- Including seismic, land, drilling and other development expenditures
in 2009, the construction and testing of Perpetual's gas storage
facility came to a total cost of $68 million and was fully
operational for commercial injection in May 2010 and for withdrawal
purposes on January 1, 2011.
- The WGSI Facility generated operating funds flow of $6.6 million in
2010, which is expected to increase as the cycle capacity is
increased in 2011 and future years. WGSI provides a complementary
diversified cash flow stream to the Corporation's existing oil and
natural gas assets.
Subsequent Events
- On February 23, 2011, Perpetual announced the sale of its Mitsue
area, a minor, non-core shallow gas property in northeast Alberta,
for $9.0 million. At December 31, 2010 Perpetual had 3.7 Bcfe (3.1
Bcf gas and 0.1 MMbbl oil) proved and probable reserves recorded for
this asset. The production impact of this sale is 2.0 MMcfe/d. The
effective date of this sale is December 1, 2010.
- On March 1, 2011 Perpetual announced its intention to issue $150
million of seven-year Senior Unsecured Notes ("the Notes"). The
Notes will be direct senior unsecured obligations of Perpetual
ranking pari passu with all other present and future unsecured and
unsubordinated indebtedness of the Corporation. Net proceeds from the
Notes offering will be used to repay existing indebtedness under
Perpetual's existing credit facility. Additional benefits to
Perpetual include significant extension of the term of a portion of
its total debt and reduced exposure of its credit capacity to
commodity prices, particularly near term weakness in gas prices. Pro
forma for the Notes offering, Perpetual expects to be drawn
approximately $70 million on its credit facility and approximately 70
percent of Perpetual's total outstanding debt will have a term
extending beyond 2014. Closing is expected to occur on or about March
15, 2011 following a limited marketing process and determination of
pricing.
2011 OUTLOOK AND SENSITIVITIES
In November 2010, Perpetual's Board of Directors approved a $48 million
capital budget for the first quarter of 2011. Capital expenditures were
directed principally toward the advancement of Perpetual's large-scope
resource-style opportunities including:
- The completion of two gross (1.5 net) horizontal wells and the
drilling and completion of three gross (3.0 net) wells targeting the
liquids-rich Wilrich formation in the Edson area of west central
Alberta;
- The drilling of four gross(3.0 net) horizontal wells targeting oil
in the Cardium formation at Carrot Creek;
- Tie-in operations for the Elmworth Montney play to establish
production from the Montney;
- The drilling of seven oilsands evaluation wells at Hoole, Liege and
Clyde in northeast Alberta;
- The drilling of two vertical wells and one horizontal well to test
potential cold flow heavy oil production at Panny; and
- Detailed core and fracture stimulation analysis for development of
the Viking/Colorado shale pilot program in eastern Alberta scheduled
for the fourth quarter of 2011.
First quarter capital spending also incorporated the drilling of two
gross (2.0 net) heavy oil wells at Mannville in eastern Alberta, four gross
(4.0)drills and approximately 50 recompletions undertaken in various areas of
Perpetual's conventional asset base, in addition to development expenditures
to increase working gas capacity at the WGSI Facility.
The Corporation's Board of Directors has approved a capital spending
budget of $42 million for the remainder of 2011 for an annual total capital
expenditure budget of $90 million, including gas storage. Capital activity
for the remainder of the year will continue to be focused on oil and
liquids-rich projects including:
- The drilling and completion of two additional gross (2.0 net) wells
targeting the Wilrich in the Edson area;
- The drilling and completion an additional 25-30 (25-30 met)
horizontal heavy oil wells targeting the Lloyd and Sparky formation
at Mannville in eastern Alberta; and
- Completion of detailed core work and fracture stimulation modeling
work and commencement of the Viking/Colorado shale pilot program in
eastern Alberta and;
- The drilling of up to two additional gas storage wells at WGSI.
Incorporating production additions from these capital expenditures, the
following table shows Perpetual's estimate of key measures for 2011 based on
its current hedging portfolio and cost estimates under several different full
year 2011 AECO gas price assumptions and an average realized price of $88 per
bbl of oil and NGL sales, incorporating the non-core property disposition
closed in February 2011 for proceeds of $9 million and completion of the
Corporation's offering of $150 million of Senior Notes in March 2011.
Average full year AECO monthly index gas price ($/GJ)(3)
Funds flow outlook $3.00 $4.00 $5.00
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Natural gas production (MMcf/d) 135 135 135
Oil and NGL production (bbl/d) 1,800 1,800 1,800
Realized price ($/Mcfe) 4.13 5.09 6.04
Funds flow(1) ($ millions) 56 101 141
Per Share(1) ($/Share/month) 0.032 0.057 0.079
Payout ratio(1)(4) (%) 95 53 38
Ending net bank debt ($ millions) 145 100 60
Ending net bank debt to funds flow
ratio(2) (times) 2.6 1.0 0.4
Ending total net debt ($ millions) 526 482 442
Ending total net debt to funds flow
ratio(2)(times) 9.4 4.8 3.1
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(1) These are non-GAAP measures; see "Significant accounting policies
and non-GAAP measures" in management's discussion and analysis.
(2) Calculated as long-term bank debt net of working capital
(excluding financial instrument assets and liabilities) divided by
annualized funds flow. Total net debt includes net bank debt,
convertible debentures and medium term notes.
(3) Average AECO settled and forward price for 2011 as at March 7, 2011
was $3.44 per GJ.
(4) Estimated payout ratio assumes a dividend rate of $0.03 per month per
Share for January through December 2011.
Share for January through December 2011.
Below is a table that shows sensitivities of Perpetual's 2011 estimated
funds flow to operational changes and changes in the business environment:
Impact on funds flow per Common Share
Funds flow sensitivity
analysis ($ per Share)
Change Annual Monthly
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Business Environment
Natural gas price at AECO $0.25 per Mcf 0.075 0.006
Interest rate on bank debt 1% 0.008 0.001
Operational
Production volume 5 MMcf/d 0.043 0.004
Operating costs $0.10 per Mcfe 0.036 0.003
Cash general and
administrative expenses $0.10 per Mcfe 0.036 0.003
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The Corporation's outlook and sensitivities assume operating costs of
$1.70 per Mcfe, cash general and administrative expenses of $0.65 per Mcfe,
an interest rate on bank debt of 3.8 percent and incorporate the
Corporation's financial and physical forward sales portfolio at March 7,
2011. The Corporation's outlook and sensitivities vary substantially with
natural gas prices. The current settled and forward market at March 7, 2011
for natural gas at AECO is an average price of $3.64 per Mcf for full year
2011.
Forward-Looking Information
Certain information regarding Perpetual in this news release including
management's assessment of future plans and operations and including the
information contained under the heading "Outlook and Sensitivities" above may
constitute forward-looking statements under applicable securities laws. The
forward looking information includes, without limitation, statements
regarding expected access to capital markets; potential reinstatement of the
Premium Dividend(TM) and Dividend Reinvestment Plan; forecast production,
production capability, operations, funds flows, and timing thereof; expected
future funds flows generated by the gas storage facility; forecast and
realized commodity prices; forecast, funding and allocation of capital
expenditures; anticipated operating cost sustainability; projected use of
funds flow; planned drilling and development and the results thereof;
estimated payout ratios; expected levels of indebtedness under the credit
facility; anticipated closing date and use of proceeds of the Notes; expected
benefits of the Notes to Perpetual; marketing and transportation; reserve
estimates; and estimated funds flow sensitivity. Various assumptions were
used in drawing the conclusions or making the forecasts and projections
contained in the forward-looking information contained in this press release,
which assumptions are based on management analysis of historical trends,
experience, current conditions, and expected future developments pertaining
to Perpetual and the industry in which it operates as well as certain
assumptions regarding the matters outlined above. Forward-looking information
is based on current expectations, estimates and projections that involve a
number of risks, which could cause actual results to vary and in some
instances to differ materially from those anticipated by Perpetual and
described in the forward looking information contained in this press release.
Undue reliance should not be placed on forward-looking information, which is
not a guarantee of performance and is subject to a number of risks or
uncertainties, including without limitation those described under "Risk
Factors" in Paramount Energy Trust's MD&A for the year ended December 31,
2010 and those included in reports on file with Canadian securities
regulatory authorities which may be accessed through the SEDAR website
(www.sedar.com) and at Perpetual's website
(www.perpetualenergyinc.com). Readers are cautioned that the
foregoing list of risk factors is not exhaustive. Forward-looking
information is based on the estimates and
opinions of Perpetual's management at the time the information is released
and Perpetual disclaims any intent or obligation to update publicly any such
forward-looking information, whether as a result of new information, future
events or otherwise, other than as expressly required by applicable
securities laws.
Non-GAAP Measures
This news release contains financial measures that may not be calculated
in accordance with generally accepted accounting principles in Canada
("GAAP"). Readers are referred to advisories and further discussion on
non-GAAP measures contained in the "Significant Accounting Policies and
non-GAAP Measures" section of management's discussion and analysis.
Conference Call and Webcast
Perpetual will be hosting a conference call and webcast at 10:30 a.m.,
Mountain Time, Tuesday March 8, 2011 to review this information. Interested
parties are invited to take part in the conference call by dialing one of the
following telephone numbers 10 minutes before the start time:
Toronto and area - 1-647-427-7450; outside Toronto - 1-888-231-8191. For
a replay of this call please dial: Toronto and area - 1-416-849-0833; outside
Toronto - 1-800-642-1687, passcode 43089067 until Tuesday March 15, 2010. To
participate in the live webcast please visit www.perpetualenergyinc.com or
www.cnw.ca/en/webcast/index.cgi. The webcast will be archived shortly
following the presentation.
Perpetual Energy Inc. is a natural gas-focused Canadian energy company.
Perpetual's shares and convertible debentures are listed on the Toronto Stock
Exchange under the symbol "PMT", "PMT.DB.C", "PMT.DB.D" and "PMT.DB.E",
respectively. Further information with respect to Perpetual can be found at
its website at www.perpetualenergyinc.com .
The Toronto Stock Exchange has neither approved nor disapproved the
information contained herein.
SUMMARY OF RESULTS
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FINANCIAL AND OPERATING HIGHLIGHTS
Three months ended Year ended
December 31 December 31
($CDN thousands,
except volume
and per Common % %
Share amounts) 2010 2009 change 2010 2009 change
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FINANCIAL
Revenue(1)(2) 111,150 78,852 41 417,093 418,323 -
Funds flow(2) 70,509 39,409 79 237,165 231,347 3
Per Common
Share(2)(3) 0.48 0.32 50 1.69 1.96 (14)
Cash flow
provided by
operating
activities 80,210 36,446 120 240,126 228,352 5
Per Common
Share(3) 0.54 0.29 86 1.71 1.93 (11)
Net earnings
(loss) (19,874) (11,287) 76 (28,546) 14,393 (298)
Per Common
Share(3) (0.13) (0.09) 44 (0.20) 0.12 (266)
Dividends
declared 16,273 18,810 (13) 78,628 75,838 4
Per Common
Share(4) 0.11 0.15 (27) 0.56 0.64 (13)
Payout
ratio (%)(2) 23.1 47.7 (52) 33.2 32.8 1
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Total assets 1,038,206 1,065,305 (3) 1,038,206 1,065,305 (3)
Net bank and
other debt
outstanding
(2)(5) 214,546 270,843 (21) 214,546 270,843 (21)
Convertible
debentures,
measured at
principal
amount 234,897 230,168 2 234,897 230,168 2
Total net
debt(2)(5) 449,443 501,011 (10) 449,443 501,011 (10)
Shareholders'
equity 253,143 253,879 - 253,143 253,879 -
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Capital
expenditures
Exploration
and
development 38,158 4,512 743 115,202 57,371 201
Gas Storage 11,171 5,595 100 57,587 10,800 433
Acquisitions,
net of
dispositions (34,253) (10,016) 242 50,653 103,885 (51)
Other 332 377 (12) 707 649 9
Net capital
expenditures 15,408 468 3,192 224,149 172,705 30
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SHARES
OUTSTANDING
(thousands)
End of period 148,284 126,224 17 148,284 126,224 17
Weighted
average 147,742 125,064 18 140,624 118,181 19
Diluted 147,742 126,149 17 140,624 119,266 18
March 1, 2010 148,302 148,302
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OPERATING
Production
Average daily
natural gas
(MMcf/d) 135.9 139.8 (3) 145.1 153.4 (5)
Average daily
oil and
natural gas
liquids
("NGL")
(bbl/d) 1,535 1,014 51 1,245 721 73
Average daily
(MMcfe/d) 145.1 145.9 (1) 152.6 157.7 (3)
Per Common
Share
(cubic
feet
equivalent/d
Share)(3) 0.98 1.17 (16) 1.09 1.33 (18)
Gas over
bitumen deemed
production
(MMcf/d)(7) 24.2 24.6 (2) 24.8 19.9 25
Average daily
(actual and
deemed -
MMcfe/d)(6)(7) 169.3 170.5 (1) 177.4 177.6 -
Per Common
Share (cubic
feet
equivalent/d/
Share)(3) 1.15 1.36 (15) 1.26 1.50 (16)
Average prices
Natural Gas -
before
financial
instruments
($/Mcf)(8) 3.87 3.94 (2) 4.17 4.12 1
Natural Gas -
including
financial
instruments
($/Mcf)(8) 7.83 5.53 42 7.10 7.09 -
Oil and NGL
($/bbl) 75.88 67.33 13 68.29 61.91 10
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RESERVES (Bcfe)
Company interest
- proved(9)(10) 250.4 244.4 2 250.4 244.4 2
Company interest
- proved and
probable
(9)(10)(11) 487.7 471.6 3 487.7 471.6 3
Per Common Share
(Mcfe/Share)(12) 3.29 3.74 (12) 3.29 3.74 (12)
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Estimated present
value before
tax ($ millions)
(11)
Proved 710.4 834.6 (15) 710.4 834.6 (15)
Proved and
probable 1,201.1 1,387.3 (13) 1,201.1 1,387.3 (13)
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LAND (thousands
of net acres)
Total land
holdings 3,421 3,759 (9) 3,421 3,759 (9)
Undeveloped
land holdings 1,905 2,093 (9) 1,905 2,093 (9)
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DRILLING (wells
drilled
gross/net)
Gas 3/2.4 3/2.5 -/(4) 48/44.3 46/36.2 4/22
Oil 3/1.0 2/2.0 50/(50) 14/11.6 2/2.0 600/480
Gas Storage -/- 4/4.0 (100)/ 6/6.0 4/4.0 50/50
(100)
Service 1/1.0 -/- 100/100 1/1.0 -/- 100/100
Dry -/- -/- -/- 1/1.0 -/- 100/100
Total 7/4.4 9/8.5 (22)/ 70/63.9 52/42.2 35/51
(48)
Success Rate 100/100 100/100 -/- 99/98 100/100 (1)/(2)
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(1) Revenue includes realized gains and losses on financial instruments
and call option premiums received.
(2) This is a non-GAAP measure; please refer to "Significant accounting
policies and non-GAAP measures" included in the MD&A.
(3) Based on weighted average Common Shares outstanding for the period.
(4) Based on Common Shares outstanding at each dividend date.
(5) Net debt is measured as at the end of the period and includes net
working capital (deficiency), excluding short-term financial
instrument assets and liabilities related to the Corporation's
hedging activities and the current portion of convertible
debentures. Total net debt includes convertible debentures,
measured at principal amount.
(6) Production amounts are based on the Corporation's interest before
deduction of royalties.
(7) Deemed production describes all gas shut-in or denied production
pursuant to a decision report, corresponding order or general
bulletin of the Alberta Energy and Utilities Board ("AEUB"), or
through correspondence in relation to an AEUB ID 99-1 application.
This deemed production is not actual gas sales but represents
shut-in gas that is the basis of the gas over bitumen ("GOB")
financial solution received monthly from the Alberta Crown as a
reduction of other royalties payable. See "Gas over bitumen royalty
adjustments" in the MD&A.
(8) Perpetual's commodity hedging strategy employs both financial
forward contracts and physical natural gas delivery contracts at
fixed prices or price collars. In calculating the Corporation's
natural gas price before financial and physical hedging, Perpetual
assumes all natural gas sales based on physical delivery fixed-price
or price collar contracts during the period were instead sold at AECO
monthly index.
(9) As evaluated by McDaniel & Associates Consultants Ltd. ("McDaniel")
and GLJ Petroleum Consultants Ltd. ("GLJ") in accordance with
National Instrument 51-101. See "Reserves" included in the MD&A.
(10) Reserves are presented on a company interest basis, including
working interest and royalty interest volumes but before royalty
burdens.
(11) Discounted at five percent using McDaniel and GLJ forecast pricing.
Reserves at various other discount rates are located in the
"Reserves" section of the MD&A. Estimated present value amounts
should not be taken to represent an estimate of fair market value.
(12) Based on Common Shares outstanding at period end.
(12) Based on Common Shares outstanding at period end.
For further information: For further information: Perpetual Energy Inc.,
Suite 3200, 605 - 5 Avenue SW, Calgary, Alberta, Canada, T2P 3H5, Telephone:
+1-403-269-4400, Fax: +1-403-269-4444, Email: info(at)perpetualenergyinc.com;
Susan L. Riddell Rose, President and Chief Executive Officer; Cameron R.
Sebastian, Vice President, Finance and Chief Financial Officer; Sue M.
Showers, Investor Relations and Communications Advisor
For further information: For further information: Perpetual Energy Inc.,
Suite 3200, 605 - 5 Avenue SW, Calgary, Alberta, Canada, T2P 3H5, Telephone:
+1-403-269-4400, Fax: +1-403-269-4444, Email: info(at)perpetualenergyinc.com;
Susan L. Riddell Rose, President and Chief Executive Officer; Cameron R.
Sebastian, Vice President, Finance and Chief Financial Officer; Sue M.
Showers, Investor Relations and Communications Advisor
Tags: Alberta, Calgary, canada, March 8, Perpetual Energy Inc.
