PERPETUAL ENERGY INC. RELEASES YEAR END 2010 FINANCIAL AND OPERATING RESULTS, UPDATES 2011 CAPITAL SPENDING PROGRAM AND OPERATIONAL ACTIVITIES AND CONFIRMS MARCH 2011 DIVIDEND

Mar 07, 2011, 23:58 ET from Perpetual Energy Inc.

CALGARY, March 7 /PRNewswire-FirstCall/ - (TSX: PMT) 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   $5.00
    -------------------------------------------------------------------------
    Natural gas production (MMcf/d)                      135     135     135
    Oil and NGL production (bbl/d)                     1,800   1,800   1,800
    Realized price  ($/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
    -------------------------------------------------------------------------
    -------------------------------------------------------------------------
    (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.

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
    -------------------------------------------------------------------------
    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
    -------------------------------------------------------------------------

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 http://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
    -------------------------------------------------------------------------
    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
    -------------------------------------------------------------------------
    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
    -------------------------------------------------------------------------
    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       -
    -------------------------------------------------------------------------
    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
    -------------------------------------------------------------------------
    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
    -------------------------------------------------------------------------
    -------------------------------------------------------------------------
    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
    -------------------------------------------------------------------------
    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)
    -------------------------------------------------------------------------
    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)
    -------------------------------------------------------------------------
    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)
    -------------------------------------------------------------------------
    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)
    -------------------------------------------------------------------------
    (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.

SOURCE Perpetual Energy Inc.