Paramount Energy Trust releases 2009 year-end reserves, confirms February 2010 cash distribution and updates hedging
CALGARY, Feb. 9 /PRNewswire-FirstCall/ - (TSX - PMT.UN) - Paramount Energy Trust ("PET" or the "Trust") is pleased to confirm that its distribution to be paid on March 15, 2010 in respect of income received by PET for the month of February 2010, for Unitholders of record on February 23, 2010 will be $0.05 per Trust Unit. The ex-distribution date is February 19, 2010. The February distribution brings cumulative distributions paid since the inception of the Trust to $13.864 per Trust Unit.
HEDGING UPDATE
PET continues to actively manage its natural gas price risk. Natural gas prices in North America have recovered significantly with the erosion of surplus gas storage inventories driven by cold winter weather globally and the resultant increased heating demand. However, the Trust remains cautious with respect to near term natural gas prices as impacted by strong supply from shale gas plays in the United States, increased LNG supply and weak industrial gas demand due to the economic recession. PET closely monitors the market drivers with respect to natural gas prices and will continue to proactively manage the Trust's forward price exposure to meet PET's strategy of protecting the level of the Trust's monthly distributions and managing the balance sheet, enhancing or protecting the economics of acquisitions and capital programs, and capitalizing on perceived market anomalies.
The Trust has recently applied a portion of the value of its hedge portfolio to its balance sheet through the early crystallization of forward sale transactions. To date in the first quarter, PET has crystallized $9 million of future hedge positions while layering into new positions as dictated by market conditions. The current mark-to-market value of PET's net open hedging transactions is approximately $67 million.
PET's financial and physical natural gas forward sales arrangements at February 9, 2010 are as follows:
Financial hedges and physical forward sales contracts
Volumes % of Futures
Type of at AECO(2) Budget Price(1) Market(3)
Contract (GJ/d) Volume(4) ($/GJ) ($/GJ) Term
-------------------------------------------------------------------------
April -
Financial 85,000 43 7.22 5.16 October 2010
-------------------------------------------------------------------------
November 2010 -
Financial 85,000 7.76 March 2011
November 2010 -
Physical 10,000 7.75 March 2011
-------------------------------------------------------------------------
November 2010 -
Period Total 95,000 48 7.76 5.91 March 2011
-------------------------------------------------------------------------
April -
Financial 30,000 15 6.30 5.62 October 2011
-------------------------------------------------------------------------
January -
Financial 89,679 45 6.78 6.52 March 2013
-------------------------------------------------------------------------
(1) Average price calculated using weighted average price for sell
contracts.
(2) All transactions are at AECO unless identified specifically as a
NYMEX transaction.
(3) Futures market reflects AECO/NYMEX forward market prices as at
February 9, 2010.
(4) Calculated using 200,000 GJ/d and includes actual and gas over
bitumen deemed projected production volumes and voluntary production
shut-ins.
2010 OUTLOOK
At current AECO forward prices of $5.36 per GJ for 2010 the Trust estimates 2010 cash flow of $185 to $195 million. Incorporating PET's current hedging portfolio and forward natural gas prices into the Trust's production, operations and funds flow projections, the current level of distribution represents a payout ratio of approximately 42 percent for 2010. The current monthly distribution level and planned $80 million capital expenditure program can be funded completely through funds flow, with the additional $25 to35 million of forecast cash flow directed to reduce bank debt or to increased capital spending on PET's Cardium tight oil play in the Pembina area of west central Alberta. In addition, PET anticipates approximately $40 million in DRIP proceeds for 2010 will further reduce bank indebtedness by year end 2010, assuming participation in the Trust's DRIP and Premium DRIP programs continues at the current level of approximately 60 percent.
PET expects to have results from its first Cardium horizontal oil well prior to spring break up with two additional horizontal wells pending for the second quarter. Should the results of this activity be consistent with the positive industry results on neighboring acreage, PET has plans for an eight well pad development at Carrot Creek which could be initiated as early as the third quarter of 2010.
The Trust has increased its focus on growth opportunities in 2010, with plans in place to evaluate several of its large scope opportunities in the Montney formation at Elmworth, the Carrot Creek Cardium near Pembina, the shallow Colorado and Viking shale gas play in east central Alberta and two heavy oil opportunities in northeast Alberta. With success in these resource plays, PET is targeting to evolve its sustainable distribution model that balances short term cash returns to its Unitholders and long term value creation through capital reinvestment to incorporate a component of repeatable growth. PET reviews distributions on a monthly basis. Future distributions are subject to change as dictated by commodity price markets, operations and future business development opportunities.
YEAR-END 2009 RESERVES
PET is also pleased to release a summary of the Trust's year end 2009 reserves information, as evaluated by the independent engineering firm McDaniel and Associates Consultants Ltd. ("McDaniel").
Year-End Reserve Highlights
- In 2009, the Trust added 42.1 Bcfe of proved and probable reserves,
excluding production.
- After production of 57.6 Bcfe and dispositions of 16.7 Bcfe in 2009,
proved and probable reserves decreased three percent from 487.1 Bcfe
at year end 2008 to 471.6 Bcfe and proved reserves decreased seven
percent to 244.4 Bcfe at year end 2009. Reserve additions largely
offsetting production and dispositions were due to the successful
reinvestment of $68.2 million in capital spending programs,
representing approximately 27 percent of the Trust's 2009 funds flow,
as well as the acquisition of Profound Energy Inc. during the year.
- Including changes in future development capital, PET realized
finding, development and acquisition costs of $2.39 per Mcfe ($14.34
per BOE) on a proved and probable reserves basis in 2009 and $4.04
per Mcfe ($24.24 per BOE) on a proved reserves basis in 2009.
- The Trust's reserve to production ratio ("reserve life index")
increased 17 percent to 8.8 years on a proved and probable reserves
basis (4.8 years on a proved reserves basis) at year end 2009, as
compared to 7.5 years (4.5 years on a proved basis) in 2008.
- PET's net asset value at year end 2009 was $8.11 per Trust Unit
discounted at 5 percent compared to $10.64 per Trust Unit at
December 31, 2008, while the Trust distributed $0.64 per Trust Unit
to Unitholders in 2009. This decrease was principally due to lower
natural gas price forecasts used by McDaniel in 2009.
Reserves Disclosure
Company interest reserves included herein are before royalty burdens and including royalty interests. Reserves information is based on an independent reserves evaluation report prepared by McDaniel dated February 9, 2010 with an effective date of December 31, 2009, and has been prepared in accordance with National Instrument 51-101 ("NI 51-101") using McDaniel's forecast prices and costs. Complete NI 51-101 reserves disclosure including after-tax reserve values, reserves by major property and abandonment costs will be included in PET's Annual Information Form ("AIF"), which will be filed in March 2010.
PET reports the results of the Trust's 93 percent-owned subsidiary Severo Energy Corp. ("Severo") using consolidated accounting practices, and therefore the amounts shown include 100 percent of the volumes and values related to the natural gas reserves of Severo.
Approximately 96 percent of PET's proved and proved and probable reserves are natural gas and as such the Trust reports reserves in Mcf equivalent (Mcfe). Mcfe may be misleading, particularly if used in isolation. In accordance with NI 51-101 a Mcfe conversion ratio for oil of 1 Bbl: 6 Mcf has been used, which is based on an energy equivalency conversion method primarily applicable at the burner tip and does not necessarily represent a value equivalency at the wellhead.
Reserves at December 31, 2009
Company Interest (Working plus Royalty Interest)
-------------------------------------------------------------------------
Light and Natural Natural
Medium Heavy Natural Gas Gas
Crude Oil Oil Gas Liquids Equivalent
(MBbl) (MBbl) (MMcf) (MBbl) (MMcfe)
-------------------------------------------------------------------------
Proved Producing 629 415 192,034 744 202,757
Proved
Non-Producing 16 7 7,808 58 8,293
Proved Undeveloped 78 0 31,018 306 33,322
-------------------------------------------------------------------------
Total Proved 724 421 230,861 1,107 244,372
-------------------------------------------------------------------------
Total Probable 339 183 220,432 607 227,204
-------------------------------------------------------------------------
Total Proved and
Probable 1,063 604 451,293 1,714 471,576
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Gross Interest (Working Interest)
-------------------------------------------------------------------------
Light and Natural Natural
Medium Heavy Natural Gas Gas
Crude Oil Oil Gas Liquids Equivalent
(MBbl) (MBbl) (MMcf) (MBbl) (MMcfe)
-------------------------------------------------------------------------
Proved Producing 616 406 190,503 743 201,094
Proved
Non-Producing 16 7 7,808 58 8,293
Proved Undeveloped 78 0 31,018 306 33,322
-------------------------------------------------------------------------
Total Proved 710 413 229,330 1,107 242,709
-------------------------------------------------------------------------
Total Probable 335 180 219,840 607 226,574
-------------------------------------------------------------------------
Total Proved and
Probable 1,045 593 449,170 1,714 469,283
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Net Interest (Company Interest less Royalties Payable)
-------------------------------------------------------------------------
Light and Natural Natural
Medium Heavy Natural Gas Gas
Crude Oil Oil Gas Liquids Equivalent
(MBbl) (MBbl) (MMcf) (MBbl) (MMcfe)
-------------------------------------------------------------------------
Proved Producing 518 371 164,447 497 172,762
Proved
Non-Producing 15 5 6,709 37 7,051
Proved Undeveloped 54 0 27,431 196 28,932
-------------------------------------------------------------------------
Total Proved 587 376 198,587 730 208,745
-------------------------------------------------------------------------
Total Probable 267 162 181,497 388 186,396
-------------------------------------------------------------------------
Total Proved and
Probable 854 538 380,084 1,118 395,141
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Reserves Reconciliation
Company Interest (Working Interest + Royalty Interest)
-------------------------------------------------------------------------
PROVED Natural Gas
Equivalent (MMcfe)
-------------------------------------------------------------------------
Opening Balance 263,616
Discoveries and Extensions 13,837
Technical Revisions (Excluding Transfer of Shut-in
Gas over Bitumen to Probable) 7,083
Transfer of Shut-in Gas over
Bitumen to Probable(1) (12,567)
Acquisitions, net of Dispositions 32,791
Production (57,560)
Economic Factors (2,829)
-------------------------------------------------------------------------
Closing Balance 244,372
-------------------------------------------------------------------------
-------------------------------------------------------------------------
PROBABLE Natural Gas
Equivalent (MMcfe)
-------------------------------------------------------------------------
Opening Balance 223,441
Discoveries and Extensions 4,648
Technical Revisions (11,854)
Acquisitions, net of Dispositions 13,403
Production -
Economic Factors (2,433)
-------------------------------------------------------------------------
Closing Balance 227,204
-------------------------------------------------------------------------
-------------------------------------------------------------------------
PROVED AND PROBABLE Natural Gas
Equivalent (MMcfe)
-------------------------------------------------------------------------
Opening Balance 487,057
Discoveries and Extensions 18,485
Technical Revisions (17,335)
Acquisitions, net of Dispositions 46,194
Production (57,560)
Economic Factors (5,263)
-------------------------------------------------------------------------
Closing Balance 471,576
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) 12.6 Bcfe of proved gas reserves were shut in and transferred to
probable reserves due to ERCB Interim Shut In Order 09-003
With the interim shut-in of PET's Legend property related to the gas over bitumen issue, 12.6 Bcf of reserves were reclassified as probable non-producing at year end 2009 from proved producing at year end 2008. Anticipated cash flow from the reduction of future royalties related to the financial solution in place for gas shut-in as a result of the gas over bitumen regulatory issue is reflected in proven future net revenues.
Year over year, McDaniel recorded net downward technical revisions of 17.3 Bcf on a proved and probable basis, primarily due to a reduction of reserves booked on PET's unconventional shallow gas Viking resource play in east central Alberta. With depressed gas prices in 2009 the Trust deferred its originally-budgeted capital spending program on this play to land preserving activities only. Lack of activity to develop the proved and probable undeveloped reserves led to a reduction in the McDaniel reserves booked at year end 2009. The Trust is currently planning three development projects on this play in 2010; two in the Mannville/Duvernay area with a third development project at Craigend.
RESERVE LIFE INDEX
PET's proved and probable reserves to production ratio, also referred to as reserve life index ("RLI") was 8.8 years at year end 2009 while the proved RLI was 4.8 years, based upon the 2010 production estimates in the McDaniel Report. The following table summarizes PET's historical calculated RLI.
Reserve Life Index(1)
-------------------------------------------------------------------------
2009 2008 2007 2006 2005 2004
-------------------------------------------------------------------------
Total Proved 4.8 4.5 4.7 3.6 4.0 4.5
Proved and Probable 8.8 7.5 7.6 4.9 5.4 5.6
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) Calculated as year-end reserves divided by year one production
estimate from McDaniel Report.
NET PRESENT VALUE OF RESERVES SUMMARY
PET's light and medium oil, natural gas and natural gas liquids reserves were evaluated by McDaniel using McDaniel's product price forecasts effective January 1, 2010 prior to provision for financial natural gas price hedges, income taxes, interest, debt service charges and general and administrative expenses. The following table summarizes the net present value ("NPV") of cash flow from recognized reserves at January 1, 2010, assuming various discount rates. It should not be assumed that the discounted future net cash flows estimated by McDaniel represent the fair market value of the potential future production revenue of the Trust.
NPV of Cash Flow Using McDaniel January 1, 2010 Forecast Prices and Costs
-------------------------------------------------------------------------
NI 51-101 Net Interest Discounted at
($thousands) Undiscounted 5% 10% 15%
-------------------------------------------------------------------------
Proved Producing $ 914,211 $ 764,545 $ 664,353 $591,253
Proved Non-Producing 17,570 14,010 11,910 10,429
Proved Undeveloped 77,218 56,025 41,130 30,445
-------------------------------------------------------------------------
Total Proved 1,008,998 834,579 717,393 632,127
Total Probable 827,483 552,700 392,219 291,069
-------------------------------------------------------------------------
Total Proved and Probable $1,836,481 $1,387,279 $1,109,612 $923,196
-------------------------------------------------------------------------
-------------------------------------------------------------------------
At a 10 percent discount factor, the proved producing reserves comprise 60 percent of the proved and probable value while total proved reserves account for 65 percent of the proved and probable value. McDaniel's price forecast utilized in the evaluation is summarized below.
McDaniel January 1, 2010 Price Forecast
-------------------------------------------------------------------------
West Texas Edmonton Natural
Intermediate Light Gas at Foreign
Crude Oil Crude Oil AECO Exchange
Year ($US/Bbl) ($Cdn/Bbl) ($Cdn/MMBtu) ($US/$Cdn)
-------------------------------------------------------------------------
2010 80.00 83.20 6.05 0.950
2011 83.60 87.00 6.75 0.950
2012 87.40 91.00 7.15 0.950
2013 91.30 95.00 7.45 0.950
2014 95.30 99.20 7.80 0.950
2015 99.40 103.50 8.15 0.950
2016 101.40 105.60 8.40 0.950
2017 103.40 107.70 8.55 0.950
2018 105.40 109.80 8.70 0.950
2019 107.60 112.10 8.90 0.950
2020 109.70 114.30 9.05 0.950
2021 111.90 116.50 9.25 0.950
2022 114.10 118.80 9.45 0.950
2023 116.40 121.20 9.65 0.950
Escalate thereafter at 2% 2% 2% 0.950
-------------------------------------------------------------------------
-------------------------------------------------------------------------
NET ASSET VALUE
The following net asset value ("NAV") table shows what is normally referred to as a "produce-out" NAV calculation under which the Trust's reserves would be produced at forecast future prices and costs. The value is a snapshot in time and is based on various assumptions including commodity prices and foreign exchange rates that vary over time. It should not be assumed that the NAV represents the fair market value of PET Units. The calculations below do not reflect the value of the Trust's extensive prospect inventory to the extent that the prospects are not recognized within the NI-51-101 compliant reserve assessment.
Of particular note, there are no reserves assigned to the Trust's Elmworth Montney project or to PET's prospective Pembina Cardium tight oil play which will be evaluated through planned drilling activity in 2010. In addition, no reserves or contingent resources are yet assigned to any of PET's heavy oil projects in northeast Alberta. The value of PET's prospect inventory is captured only through the assessment of the fair market value of undeveloped land based on current land sale valuation parameters.
PET has developed internal data analysis tools to rigorously manage its prospect inventory. In addition to prospects to develop proved and probable undeveloped reserves captured in the reserve report, the Trust's prospect inventory contains over 700 uphole recompletion opportunities, in excess of 500 conventional drilling locations proximal to its northeast and east central Alberta assets, multiple horizontal and vertical drilling prospects targeting gas in west central Alberta as well as a risk-discounted prospect inventory to develop the Trust's larger scope resource play opportunities in the Montney at Elmworth, tight Cardium oil, additional shallow shale gas in the Viking and Colorado in eastern Alberta and several of its nearer term prospective heavy oil assets. PET runs its business on a going-concern basis, investing in opportunities to add value, improve profitability and increase reserves in an effort to enhance the Trust's NAV beyond the amounts shown in its annual reserve evaluation.
Pre-tax Net Asset Value at December 31, 2009(1)
-------------------------------------------------------------------------
($millions except as Discounted at
noted) Undiscounted 5% 8% 10%
-------------------------------------------------------------------------
Total Proved and
Probable
Reserves(2) $ 1,836 $ 1,387 $ 1,188 $ 1,110
Fair Market Value of
Undeveloped Land(3) 143 143 143 143
Net Bank Debt (unaudited) (265) (265) (265) (265)
Convertible Debentures
(unaudited) (231) (231) (231) (231)
Estimate of Additional Future
Abandonment and Reclamation
Costs(4) (101) (61) (47) (40)
Mark to McDaniel's Value of
PET's 53 51 50 49
Forward Hedging(5)
-------------------------------------------------------------------------
Net Asset Value $ 1,435 $ 1,024 $ 838 $ 765
-------------------------------------------------------------------------
Trust Units Outstanding
(million) - basic 126 126 126 126
-------------------------------------------------------------------------
Net Asset Value per Trust
Unit ($/Unit) $ 11.37 $ 8.11 $ 6.64 $ 6.06
-------------------------------------------------------------------------
(1) Financial information is per PET's 2009 unaudited consolidated
financial statements.
(2) Reserve values per McDaniel Report as at December 31, 2009.
(3) Internal estimate.
(4) Amounts are net of salvage value and in addition to amounts in the
McDaniel Report for future well abandonment costs related to
developed reserves. See "ABANDONMENT AND RECLAMATION COSTS".
(5) Value of PET's open hedging transactions at year end 2009 assuming
settlement against the McDaniel price forecast.
In the absence of adding reserves to the Trust, the NAV per Trust Unit will decline as the reserves are produced out. The cash flow generated by the production relates directly to the cash distributions paid to Unitholders. The above evaluation includes future capital expenditure expectations required to bring undeveloped reserves recognized by McDaniel that meet the criteria for booking under NI 51-101 on production.
PET's internal estimate of the fair market value of its undeveloped acreage by region for purposes of the above net asset value calculation is based on recent crown land sale activity adjusted for tenure and other considerations and is as follows:
Fair Market Value of Undeveloped Land
-------------------------------------------------------------------------
Acres (000's) $ (000's) $/Acre
-------------------------------------------------------------------------
Northern Alberta 1,564 $ 49,399 $ 32
Southern Alberta 339 54,197 159
West Central Alberta 130 34,801 267
Severo 60 4,429 74
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Total 2,094 $142,826 $ 68
-------------------------------------------------------------------------
-------------------------------------------------------------------------
ABANDONMENT AND RECLAMATION COSTS
PET engages Prevent Technologies Ltd. ("Prevent"), an independent evaluator, to estimate the Trust's total future asset retirement obligation based on net ownership interest in all wells, facilities and pipelines, including estimated costs to abandon the wells, facilities and pipelines and reclaim the sites, and the estimated timing of the costs to be incurred in future periods. Pursuant to this evaluation, the estimated undiscounted total value of PET's future asset retirement obligations is $335 million as at December 31, 2009. As at December 31, 2009, the undiscounted net salvage value of the Trust's gas plants, compressors and facilities was estimated at $127 million. The McDaniel Report includes an undiscounted amount of $138 million with respect to expected future well abandonment costs related specifically to proved and probable reserves and such amount is included in the values captioned "Total Proved and Probable Reserves" above. Of the total future well abandonment costs included in the McDaniel Report an undiscounted amount of $108 million relates to PET's developed reserves. The following table presents the estimated future asset retirement obligations and estimated net salvage values at various discount rates:
Abandonment and Reclamation Costs
-------------------------------------------------------------------------
Discounted at
($millions net to PET) Undiscounted 5% 8% 10%
-------------------------------------------------------------------------
Well abandonment costs
for developed
reserves included in
McDaniel Report $ 108 $ 75 $ 62 $ 55
Well abandonment costs
for undeveloped
reserves included in
McDaniel Report 30 15 10 8
-------------------------------------------------------------------------
Well abandonment costs
for Total Proved and
Probable reserves
included in McDaniel
Report 138 90 72 63
Estimate of other
abandonment and
reclamation
costs not
included in
McDaniel Report 197 128 102 90
-------------------------------------------------------------------------
Total estimated future
abandonment and
reclamation costs 335 218 174 153
Salvage value (127) (82) (66) (58)
-------------------------------------------------------------------------
Abandonment and
reclamation
costs, net of
salvage 208 136 108 95
Well abandonment costs
for developed
reserves included in
McDaniel Report (108) (75) (62) (55)
-------------------------------------------------------------------------
Estimate of additional
future abandonment
and reclamation costs,
net of salvage(1) $ 101 $ 61 $ 47 $ 40
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) Future abandonment and reclamation costs not included in the McDaniel
Report, net of salvage value.
FINDING, DEVELOPMENT AND ACQUISITION ("FD&A") COSTS
Under NI 51-101, the methodology to be used to calculate FD&A costs includes incorporating changes in future development capital ("FDC") required to bring the proved undeveloped and probable reserves to production. For continuity, PET has presented herein FD&A costs calculated both excluding and including FDC. Changes in forecast FDC occur annually as a result of development activities, acquisitions and disposition activities and capital cost estimates that reflect the independent evaluator's best estimate of what it will cost to bring the proved undeveloped and probable reserves on production.
FD&A Costs - Company Interest Reserves
-------------------------------------------------------------------------
Proved Proved and
Excluding Probable
Shut-in Excluding
($millions (unaudited), Gas over Proved and Gas
except as noted) Proved Bitumen(1) Probable Storage(2)
-------------------------------------------------------------------------
FD&A Costs Excluding
Future Development
Capital
Exploration and
Development
Capital
Expenditures $ 68.2 $ 68.2 $ 68.2 $ 57.4
Net Acquisitions 102.8 102.8 102.8 102.8
-------------------------------------------------------------------------
FD&A Capital
Expenditures
Including
Net
Acquisitions $171.0 $171.0 $171.0 $160.2
Reserve Additions
Including Net
Acquisitions - Bcfe 38.4 50.9 42.1 40.6
Finding Development
and Acquisition
Cost - $/Mcfe $ 4.46 $ 3.36 $ 4.06 $ 3.94
FD&A Costs Including
Future Development
Capital
FD&A Capital
Expenditures
Including
Net
Acquisitions $171.0 $171.0 $171.0 $160.2
Total Change in FDC(3) (15.9) (15.9) (70.5) (70.5)
-------------------------------------------------------------------------
Total FD&A Capital
Including Change
in FDC $155.1 $155.1 $100.5 $ 89.7
Reserve Additions
Including Net
Acquisitions - Bcfe 38.4 50.9 42.1 40.6
Finding Development
and Acquisition
Cost Including
FDC - $/Mcfe $ 4.04 $ 3.04 $ 2.39 $ 2.21
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) 12.6 Bcfe of Proved gas reserves was shut in and transferred to
probable reserves due to ERCB Interim Shut In Order 09-003
(2) Capital expenditures related to the preliminary assessment of a gas
storage project in the Warwick area of east central Alberta in 2009
of $10.8 million have been excluded.
Anticipated cost reductions to drill, complete and tie-in Viking unconventional reserves resulted in a reduction of proved future development capital of $25.5 million and proved and probable future development capital of $77.6 million. These costs were further reduced by $9.0 million proved and $18.3 million proved and probable with the technical reserve reductions to the Viking unconventional reserves. These costs were offset by increases in future development costs of $18.6 million proved and $25.4 million proved and probable. The majority of the increased future development capital costs were related to the undeveloped reserves associated with the Profound acquisition.
Forward-Looking Information
Certain information regarding PET in this news release including the information contained under the heading "Hedging Update", "Year-end 2009 Reserves", "Reserve Life Index", "Net Present Value of Reserves Summary", "Net Asset Value", "Abandonment and Reclamation Costs", and "Finding, Development and Acquisition Costs" above may constitute forward-looking statements under applicable securities laws. The forward-looking information includes, without limitation, statements regarding PET's forecast production, planned development projects, forecast funds flows, forecast commodity prices, prospect inventory value, reserve life index, abandonment and reclamation costs, finding and development costs, and future development capital. 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 PET 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 PET 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. Readers are cautioned that the foregoing list of risk factors is not exhaustive. Forward-looking information is based on the estimates and opinions of PET's management at the time the information is released and PET 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.
PET is a natural gas-focused Canadian energy trust. PET's Trust Units and convertible debentures are listed on the Toronto Stock Exchange under the symbol "PMT.UN" and "PMT.DB.A", "PMT.DB.C" and "PMT.DB.D", respectively. Further information with respect to PET can be found at its website at www.paramountenergy.com.
The Toronto Stock Exchange has neither approved nor disapproved the information contained herein.
SOURCE Paramount Energy Trust
WANT YOUR COMPANY'S NEWS FEATURED ON PRNEWSWIRE.COM?
Newsrooms &
Influencers
Digital Media
Outlets
Journalists
Opted In
Share this article