CALGARY, Canada, March 10, 2010 /PRNewswire/ -- Paramount Energy Trust ("PET" or the "Trust") is pleased
to release its fourth quarter and year end 2009 financial and operating
results. PET's natural gas price hedging program led the Trust to post strong
funds flow for the year ending 2009 despite weak natural gas prices related
to high gas storage levels and concerns about new supply. The full text of
the Trust's audited consolidated financial statements and related
management's discussion and analysis ("MD&A") can be found at
http://www.sedar.com and on PET's website at http://www.paramountenergy.com.
PET is also pleased to confirm that its distribution to be paid on April
15, 2010 in respect of income received by PET for the month of March 2010,
for Unitholders of record on March 22, 2010, will be $0.05 per Trust Unit.
The ex-distribution date is March 18, 2010. The March 2010 distribution
brings cumulative distributions paid since the inception of the Trust in
February 2003 to $13.914 per Trust Unit.
CONVERSION TO CORPORATION
The Board of Directors of Paramount Energy Operating Corp., the
Administrator of PET, unanimously approved the conversion of the Trust to a
corporation which, subject to approval of PET's Unitholders as well as
customary court and regulatory approvals, is anticipated to be completed at
the Annual General and Special Meeting of the Trust scheduled for June 17,
2010. The principal reason for the decision to convert from a trust structure
to a corporation is the change in Canadian tax law whereby the government will
begin imposing taxes on income trusts on January 1, 2011.
Following a thorough analysis of the various strategic alternatives with
respect to PET's structure going forward as well as PET's current Unitholder
base, PET has concluded that the proposed conversion will provide broadened
access to capital markets by putting the constraints of the SIFT structure
imposed by the new tax legislation behind us. In addition, Canadian taxable
PET Unitholders will benefit from a more tax effective treatment of their cash
dividends following the conversion to a corporate structure. PET Unitholders
will also benefit from a simplified and more efficient corporate structure and
under the current legislation the conversion can be structured on a tax
deferred basis for Canadian income tax purposes. The details of the conversion
will be contained in an information circular which is anticipated to be mailed
to unitholders in May 2010.
Following the conversion it is anticipated that a monthly dividend of
$0.05 per Trust Unit per month will be paid, consistent with PET's current
distribution policy. Subject to future fluctuations in commodity prices and
other operational variables, and potential changes to capital requirements as
PET continues to add to and develop the growth-oriented portion of its asset
base, PET intends to continue to maintain for the foreseeable future a $0.05
monthly distribution prior and dividend following conversion to a corporation.
The corporate conversion will be subject to receipt of all required
regulatory, stock exchange and Court of Queen's Bench of Alberta approvals
including approval of at least 66 2/3 percent of the votes by Unitholders
present in person or by proxy at a meeting of the Trust's Unitholders.
ANNUAL 2009 RESULTS
- The Trust acquired Profound Energy Inc. ("Profound") in a two-stage
transaction in the second and third quarters of 2009 for a total of
$27.5 million in cash, 10.0 million PET Trust Units valued at
$32.2 million and $53.3 million in assumed net debt of Profound.
- Daily average production decreased 13 percent to 157.7 MMcfe/d in
2009 as a result of voluntary well shut-ins, non-core asset
dispositions and gas over bitumen shut-ins in the Legend area in
combination with natural production declines. These production
impacts were partially offset by the acquisition of the Profound
properties in the West Central district and successful capital
programs during the year.
- Funds flow decreased 16 percent to $231.3 million or $1.96 per Trust
Unit in 2009 as compared to $275.4 million or $2.47 per Trust Unit
for 2008 due primarily to lower realized natural gas prices and
decreased production levels, partially offset by lower royalties and
operating expenses.
- PET's average gas price including financial hedging and physical
forward sales ("realized" gas price) decreased 11 percent to
$7.27 per Mcfe in 2009 from $8.18 per Mcfe in 2008, as compared to a
50 percent decrease in average AECO gas prices for the year. The
Trust continued to execute on its proactive natural gas price risk
management strategy in 2009, realizing $166 million in gains on
financial instruments and $5.7 million in call option premiums and
providing a measure of stability to realized prices and funds flows
despite significant volatility in natural gas prices.
- In response to low natural gas prices during 2009, the Trust
voluntarily shut in approximately 35 MMcfe/d of natural gas
production in the second and early third quarters, leading to a
reduction in full year production volumes of 14.7 MMcfe/d.
- PET disposed of non-core assets in the Athabasca area and all of its
Saskatchewan assets for net proceeds of $26.6 million, representing
approximately 5.2 MMcf/d of daily production and 12.7 Bcfe of proved
and probable reserves.
- Effective October 31, 2009 the Energy Resources Conservation Board
("ERCB") ordered the shut-in of approximately 8.6 MMcf/d of natural
gas production from the Trust's Legend property due to gas over
bitumen concerns. An additional 1.9 MMcf/d has been shut-in due to
the shut in of facilities in the area. As a result of the ERCB order,
12.6 Bcfe of proved reserves related to the Legend property were
reclassified to probable by PET's reserve evaluators. PET believes it
is eligible to receive the gas over bitumen financial solution in
respect of the production shut-in by the ERCB order, as prescribed by
the royalty regulations enacted by the Alberta government (see "Gas
over bitumen royalty adjustments" in the MD&A).
- Exploration and development capital spending totaled $68.2 million in
2009, including a $40 million winter capital program focused on
activities in the Trust's core areas in the Northern district. The
remaining capital expenditures were directed towards PET's year-round
access asset base in east central Alberta, drilling activity on
Profound lands in the fourth quarter of 2009 and approximately
$10.8 million on the preliminary evaluation of the Trust's gas
storage project in the Warwick area within the Southern district. In
total 52 wells were drilled (42.2 net) with a 100 percent success
rate.
- In 2009, the Trust added 38.3 Bcfe of proved reserves and 3.8 Bcfe of
probable reserves for total reserve additions of 42.1 Bcfe of proved
and probable reserves, excluding production. After production of
57.5 Bcfe in 2009, proved and probable reserves decreased 3 percent
from 487.1 Bcfe at year end 2008 to 471.6 Bcfe and proved reserves
decreased 7 percent to 244.4 Bcfe at year end 2009. Reserve additions
largely offsetting production were due to the successful reinvestment
of $68.2 million in exploration and development spending programs,
representing approximately 29 percent of the Trust's 2009 funds flow,
and acquisitions, net of dispositions, of $103.9 million.
- Including future development capital and the reclassification of
PET's reserves at Legend, PET realized finding, development and
acquisition costs of $4.07 per Mcfe ($24.42 per boe) for proved
reserves and $2.41 per Mcfe ($14.46 per boe) for proved and probable
reserves in 2009. Excluding changes in future development capital
finding, development and acquisition costs for the year totaled
$4.48 per Mcfe ($26.88 per boe) for proved reserves and $4.09 per
Mcfe ($24.54 per boe) for proved and probable reserves.
- As a result of funds flows in excess of distributions and capital
expenditures and minor non-core property dispositions, PET reduced
net bank debt by five percent from $284.8 million at December 31,
2008 to $270.8 million at December 31, 2009. Including PET's
convertible debentures of $230.2 million, total net debt dropped from
$520.9 million at December 31, 2008 to $501.0 million at December 31,
2009.
- PET declared cash distributions of $75.8 million or $0.64 per Trust
Unit in 2009, representing 32.8 percent of funds flow for the year.
Cumulative distributions from the inception of the Trust to year-end
2009 totaled $1.03 billion ($13.764 per Trust Unit).
- Net earnings totaled $14.4 million in 2009 as compared to
$30.8 million in 2008, as lower funds flows were partially offset by
reductions in depletion and future tax expenses compared to prior
year.
FOURTH QUARTER 2009 RESULTS
- Production decreased 16 percent to average 145.9 MMcfe/d as
compared to 173.1 MMcfe/d for the fourth quarter of 2008, as lower
production due to voluntary production shut-ins, the shut-in of 10.5
MMcf/d of gas production at Legend as a result of a gas over bitumen
regulatory shut-in order, non-core asset dispositions in the Northern
district and natural production declines were partially offset by new
production additions from the Trust's 2009 capital programs and the
Profound acquisition.
- PET's realized gas price of $5.87 per Mcfe in the fourth quarter of
2009 was 23 percent lower than the realized gas price for the three
months ended December 31, 2009, in contrast to a 38 percent decrease
in AECO Monthly Index prices from quarter to quarter. PET's realized
gas price for the current period was $1.64 per Mcfe higher than the
AECO Monthly Index price due to the Trust's active natural gas price
management program.
- The Trust's royalty rate of 3.8 percent of revenues was 74 percent
less than 2008 and lower than the Trust's historical royalty rates
due to the decreased royalty rates in the current low gas price
environments and $20.5 million in realized gains on financial
instruments in the fourth quarter of 2009.
- Cash G&A expenses increased $0.9 million from the fourth quarter of
2008, due to lower overhead recoveries as a result of decreased
operating and capital expenditures as compared to the prior period.
- Operating costs decreased $7.3 million due to lower production
volumes and a company focus on the reduction of operating costs.
Fourth quarter 2009 unit-of-production basis operating costs declined
15 percent to $1.41 per Mcfe.
- Funds flow decreased $22.1 million to $39.4 million for the fourth
quarter of 2009 as lower gas prices combined with a decrease in
production and the shut-in of the Trust's Legend asset, resulting in
a 48 percent drop in revenue. The decrease in revenue was somewhat
offset by lower operating costs and royalty expenses.
- Net loss totaled $11.3 million for the three months ended
December 31, 2009, as lower funds flows were offset by gains on
property sales of $8.3 million. The 2008 fourth quarter loss included
$16.1 million in future tax expense, as compared to a recovery of
$0.8 million for the current three-month period.
- Capital spending totaled $10.1 million for the fourth quarter,
including the drilling of 9 wells (8.5 net wells), including two
wells in the Southern district, three wells in the West Central
district and two wells related to PET's gas storage project, with a
100 percent success rate.
- Distributions for the fourth quarter of 2009 totaled $0.15 per Trust
Unit, paid on November 16, 2009, December 15, 2009 and January 15,
2010. PET's payout ratio, which refers to distributions measured as a
percentage of funds flow, was 47.7 percent for the quarter.
- PET finished planning and began the execution of a $32 million 2010
winter exploration and development capital program targeting 15 to
17 MMcfe/d of natural gas production additions through drilling,
completion, tie-in and facility projects primarily in the Trust's
Northern and West Central districts.
SUBSEQUENT EVENTS
- On January 7, 2010 PET closed the acquisition ("Ukalta Acquisition")
of natural gas assets within the Birchwavy West core area for
$17.5 million, including a $1.8 million deposit paid in
December 2009. As of the acquisition date the assets were producing
6.2 MMcfe/d of natural gas.
- PET continued to supplement its gas price risk management program in
2010, including the crystallization of approximately $57 million in
gains in respect of the Trust's March to October 2010 hedging
portfolio in February and March of 2010. The hedge price on the
crystallized volumes for the April to October 2010 period was
immediately reset to $4.55 per GJ.
SUMMARY OF RESULTS
-------------------------------------------------------------------------
FINANCIAL AND
OPERATING HIGHLIGHTS Three months ended Year ended
($CDN thousands, December 31 December 31
except volume
and per Trust % %
Unit amounts) 2009 2008 change 2009 2008 change
-------------------------------------------------------------------------
FINANCIAL
Revenue(1)(2) 78,852 121,163 (35) 418,323 545,701 (23)
Funds flow(2) 39,409 61,513 (36) 231,347 275,434 (16)
Per Trust
Unit(2)(3) 0.32 0.55 (42) 1.96 2.47 (21)
Cash flow provided
by operating
activities 36,446 69,179 (47) 228,352 259,764 (12)
Per Trust
Unit(3) 0.29 0.61 (52) 1.93 2.33 (17)
Net earnings
(loss) (11,287) (8,986) 26 14,393 30,785 (53)
Per Trust
Unit(3) (0.09) (0.08) 13 0.12 0.28 (57)
Cash
distributions 18,810 33,885 (44) 75,838 133,921 (43)
Per Trust
Unit(4) 0.15 0.30 (50) 0.64 1.20 (47)
Payout
ratio (%)(2) 47.7 55.1 (13) 32.8 48.6 (33)
-------------------------------------------------------------------------
Total assets 1,065,305 1,105,689 (4) 1,065,305 1,105,689 (4)
Net bank and
other debt
outstanding
(2)(5) 270,843 284,835 (5) 270,843 284,835 (5)
Convertible
debentures,
measured at
principal
amount 230,168 236,034 (2) 230,168 236,034 (2)
Total net
debt(2)(5) 501,011 520,869 (4) 501,011 520,869 (4)
Unitholders'
equity 253,789 257,426 (1) 253,879 257,426 (1)
-------------------------------------------------------------------------
Capital
expenditures
Exploration and
development 10,107 28,329 (64) 68,171 126,091 (46)
Acquisitions,
net of
dispositions (10,016) (2,143) 367 103,885 (18,514) 661
Other 377 927 (59) 649 1,588 (59)
Net capital
expenditures 468 27,113 (98) 172,705 109,165 58
-------------------------------------------------------------------------
TRUST UNITS
OUTSTANDING
(thousands)
End of period 126,224 112,968 12 126,224 112,968 12
Weighted average 125,064 112,865 11 118,181 111,473 6
Diluted 126,149 112,865 12 119,266 112,823 6
March 1, 2010 127,773 127,773
-------------------------------------------------------------------------
OPERATING
Production
Total (Bcfe)(6) 13.4 15.9 (16) 57.5 66.7 (14)
Average daily
(MMcfe/d)(6) 145.9 173.1 (16) 157.7 182.2 (13)
Per Trust Unit
(cubic feet
equivalent/d/
Unit)(3) 1.17 1.53 (24) 1.33 1.63 (18)
Gas over
bitumen deemed
production
(MMcf/d)(7) 24.6 18.1 36 19.9 19.2 4
Average daily
(actual and
deemed -
MMcfe/d)(6)(7) 170.5 191.2 (11) 177.6 201.4 (12)
Per Trust Unit
(cubic feet
equivalent/d/
Unit)(3) 1.36 1.69 (20) 1.50 1.81 (17)
Average natural gas
prices ($/Mcfe)
Before financial
hedging and
physical forward
sales(8) 4.27 6.84 (38) 4.26 8.19 (48)
Including
financial hedging
and physical
forward sales(8) 5.87 7.61 (23) 7.27 8.18 (11)
-------------------------------------------------------------------------
RESERVES (Bcfe)
Company interest
- proved(9)(10) 244.4 263.6 (7) 244.4 263.6 (7)
Company interest
- proved and
probable
(9)(10)(11) 471.6 487.1 (3) 471.6 487.1 (3)
Per Trust Unit
(Mcfe/Unit)(12) 3.74 4.31 (13) 3.74 4.31 (13)
Estimated present
value before tax
($ millions)(11)
Proved 834.6 1,011.4 (17) 834.6 1,011.4 (17)
Proved and
probable 1,387.3 1,642.2 (16) 1,387.3 1,642.2 (16)
-------------------------------------------------------------------------
LAND (thousands
of net acres)
Total land
holdings 3,759 3,801 (1) 3,759 3,801 (1)
Undeveloped land
holdings 2,093 2,106 (1) 2,093 2,106 (1)
-------------------------------------------------------------------------
DRILLING (wells
drilled gross/net)
(71)/ (45)/
Gas 7/6.5 24/23.6 (72) 50/40.2 91/75.4 (47)
Oil 2/2.0 -/- -/- 2/2.0 -/- -/-
Dry -/- -/- /- -/- 2/1.6 -/-
(71)/ (44)/
Total 9/8.5 24/23.6 (72) 52/42.2 93/77.0 (45)
Success Rate 100/100 100/100 -/- 100/100 98/98 2/2
-------------------------------------------------------------------------
(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 Trust Units outstanding for the period.
(4) Based on Trust Units outstanding at each cash distribution 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 Trust'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 Trust'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.
(8) PET's commodity hedging strategy employs both financial forward
contracts and physical natural gas delivery contracts at fixed
prices or price collars. In calculating the Trust's natural gas
price before financial and physical hedging, PET 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. 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. Royalty interest volumes totaled 2.3 Bcfe on a proved and
probable basis in 2009 (2008 - 3.3 Bcfe).
(11) Discounted at five percent using consultant's forecast pricing.
Reserves at various other discount rates are located in the
"Reserves" section of the MD&A. Includes gas over bitumen royalty
adjustments (2009 - $109.9 million, 2008 - $70.5 million) related to
the financial solution described in Note 7 above and estimated
probable gas over bitumen shut-in reserves (2009 - 45.8 Bcf and
$55.3 million, 2008 - 26.6 Bcf and $78.3 million). Estimated present
value amounts should not be taken to represent an estimate of fair
market value.
(12) Based on Trust Units outstanding at period end.
2010 OUTLOOK AND SENSITIVITIES
Approximately $32 million will have been expended on exploration and
development activities by the end of the first quarter with positive results
thus far, generating approximately 15 to 17 MMcfe/d of production which is
expected to come onstream by early April.
PET was active in the Carrot Creek area during the winter season,
drilling six gross (5.2 net) vertical wells targeting tight gas sands. All six
wells have been cased, for a 100 percent success rate. Three of the wells have
been completed with final test rates of 800 Mcf/d, 2,200 Mcf/d and 4,000 Mcf/d
plus associated liquids of approximately 30 to 40 bbls per MMcf/d. The
remaining three wells are currently undergoing or awaiting completion
operations, and five of the six wells are expected to be on production prior
to breakup.
Also in the Carrot Creek/Pembina area, a non-operated horizontal oil well
(0.5 net) is currently being drilled targeting the Cardium formation, with
completion results expected by the end of March. Warm winter weather and an
early spring break-up may delay the completion to the second quarter of 2010.
PET is also preparing to drill two horizontal Cardium oil wells immediately
after breakup. Should the results of this activity be consistent with the
positive industry results on neighboring acreage, PET will review its 2010
capital budget and may incorporate an extensive multiwell pad development
program at Carrot Creek in the fourth quarter of 2010.
In the Elmworth area, PET and its partner are preparing to drill three
horizontal (1.5 net) Montney gas wells, with the first well expected to spud
in July 2010. PET will be carried for its 50 percent share of the capital
costs for these three wells.
The Trust has increased its focus on growth opportunities in 2010, with
plans in place to exploit several of its opportunities in the Montney
formation at Elmworth, the Cardium formation at Carrot Creek and 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 evolving 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 also closed an acquisition of natural gas assets in the Southern
district in January 2010 for total proceeds of approximately $17.5 million,
including a $1.8 million deposit paid in 2009, which is expected to add 4
MMcfe/d to the Trust's annual average production volumes. In addition, PET has
spent approximately $11 million on further delineation and evaluation of the
Trust's gas storage project at Warwick.
PET continued to supplement its gas price risk management program in
2010, including the crystallization of approximately $57 million in gains in
respect of the Trust's March to October 2010 hedging portfolio in February and
March of 2010. The hedge price on the crystallized volumes for the April to
October 2010 period was immediately reset to $4.55 per GJ. For April through
December 2010 PET has an average of 86 MMcf/d of natural gas production hedged
at an average price of $5.59 per Mcf. For January 2011 through October 2011
PET has an average of 46 MMcf/d of gas production hedged at an average price
of $7.55 per Mcf.
At current AECO average settled and forward prices of $4.64 per GJ for
2010 the Trust estimates 2010 cash flow of $170 to $180 million. PET has a
proactive gas price risk management strategy in place that has resulted in
downside protection to this cash flow with financial instruments in place to
manage gas price risk for over 50 percent of its 2010 forecast sales and gas
over bitumen deemed production volumes. 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 40 to 45 percent for 2010. The
current monthly distribution level and planned $80 million exploration and
development expenditure program can be funded completely through funds flow,
with the additional $10 to $20 million of forecast cash flow directed to
reduce bank debt or to increase capital spending on PET's Cardium tight oil
play in the Pembina area of west central Alberta. In addition, PET anticipates
approximately $40 million in DRIP proceeds for 2010 will further reduce bank
indebtedness by year end 2010, assuming participation in the Trust's DRIP and
Premium DRIP programs continues at the current level of approximately 60
percent.
The following table shows PET's estimate of key measures for 2010 based
on its hedging portfolio, production levels and the Trust's estimated
exploration and development capital expenditures and targeted results for full
year 2010 under several different full year 2010 AECO gas price assumptions.
Average full year AECO monthly
index gas price ($/GJ)(3)
Funds flow outlook $4.00 $5.00 $6.00
-------------------------------------------------------------------------
Oil and natural gas production (MMcfe/d) 151 151 151
Realized gas price ($/Mcfe) 6.32 6.84 7.36
Funds flow(1) ($ millions) 165 185 201
Per Trust Unit(1) ($/Unit/month) 0.109 0.122 0.132
Payout ratio(1)(4) (%) 46 41 38
Ending net debt ($ millions) 469 448 433
Ending net debt to funds flow ratio(2) (times) 2.8 2.4 2.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(1) These are non-GAAP terms; please refer to "Significant accounting
policies and non-GAAP measures" in this MD&A.
(2) Calculated as ending net debt (including convertible debentures)
divided by annualized funds flow.
(3) Average AECO settled and forward price for 2010 as at March 8, 2010
was $4.64 per GJ.
(4) Estimated payout ratio assumes a distribution rate of $0.05 per month
per Trust Unit for January through December 2010.
Below is a table that shows sensitivities of PET's 2010 estimated funds
flow to operational changes and changes in the business environment:
Funds flow sensitivity analysis Impact on funds flow per Trust Unit
($ per Trust Unit) Change Annual Monthly
-------------------------------------------------------------------------
Business Environment
Natural gas price at AECO $0.25 per Mcf 0.033 0.003
Interest rate on debt 1% 0.021 0.002
Operational
Production volume 5 MMcfe/d 0.071 0.006
Operating costs $0.10 per Mcfe 0.043 0.004
Cash general and administrative
expenses $0.10 per Mcfe 0.043 0.004
-------------------------------------------------------------------------
The Trust's outlook and sensitivities assume operating costs of $2.00 per
cfe, cash general and administrative expenses of $0.60 per Mcfe, an interest
ate on bank debt of 3.8 percent and incorporate the Trust's financial and
physical forward sales portfolio at March 8, 2010. Cash general and
administrative expenses are equal to general and administrative expenses
before Trust Unit-based compensation.
Forward Looking Information
Certain information regarding PET in this news release including
management's assessment of future plans and operations and including the
information contained under the headings "Conversion to Corporation" and "2010
Outlook and Sensitivities" above may constitute forward-looking statements
under applicable securities laws. The forward looking information includes,
without limitation, statements regarding the timing of and approvals required
for conversion to a corporation; the anticipated benefits of the proposed
corporate conversion; the anticipated dividend payment and amount thereof
contemplated to be paid upon completion of the proposed corporate conversion;
as well as tax treatment thereof; the anticipated efficiency of operating
under a corporate structure; the timing and delivery of the information
circular proxy statement and holding of the Unitholder meeting and Unitholder,
regulatory and court approval of the proposed corporate conversion; expected
access to capital markets; forecast production, operations, funds flows, and
timing thereof; forecast and realized commodity prices; forecast and funding
of capital expenditures; use of funds flow; use of DRIP proceeds; planned
drilling and development and the results thereof; estimated payout ratios,
estimated ending net debt; 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 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, including without limitation those described
under "Risk Factors" in the Trust's MD&A for the year ended December 31, 2009
and those included in reports on file with Canadian securities regulatory
authorities which may be accessed through the SEDAR website
(http://www.sedar.com) and at PET's website (http://www.paramountenergy.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 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.
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 the Trust's MD&A.
Mcf equivalent (Mcfe) may be misleading, particularly if used in
isolation. In accordance with National Instrument 51-101 ("NI 51-101"), an
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.
Paramount Energy Trust 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", "PMT.DB.A", "PMT.DB.C" and "PMT.DB.D",
respectively. Further information with respect to PET can be found at its
website at http://www.paramountenergy.com.
The Toronto Stock Exchange has neither approved nor disapproved the
information contained herein.
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