Advantage Announces 2nd Quarter Results 2009



    (TSX: AAV, NYSE:   AAV)

    CALGARY, Aug. 13 /CNW/ - Advantage Oil & Gas Ltd. ("Advantage" or the
"Corporation") is pleased to announce the unaudited operating and financial
results of Advantage Energy Income Fund (the "Fund") for the second quarter
ended June 30, 2009. On July 9, 2009, the Fund, Advantage and holders of trust
units of the Fund completed a plan of arrangement (the "Arrangement") which
resulted in the reorganization of the Fund into the Corporation. As a result
of the Arrangement, the Fund was dissolved and ceased to be a reporting
issuer, and the Corporation became a reporting issuer. As at June 30, 2009,
the Fund still existed and was a reporting issuer, and accordingly, prepared
financial statements and accompanying management's discussion and analysis for
the period then ended. All future financial statements and management's
discussion and analysis of the continuing legal entity will be in the name of
Advantage Oil & Gas Ltd.


    
    Financial and Operating Highlights

                                 Three       Three        Six         Six
                                 months      months      months      months
                                 ended       ended       ended       ended
                                June 30,    June 30,    June 30,    June 30,
                                  2009        2008        2009        2008
    -------------------------------------------------------------------------
    Financial ($000, except
     as otherwise indicated)

    Revenue before
     royalties(1)             $  114,659  $  208,868  $  237,609  $  397,373
      per Trust Unit(2)       $     0.79  $     1.51  $     1.65  $     2.88
      per boe                 $    40.59  $    71.69  $    42.59  $    67.03
    Funds from operations     $   51,590  $  103,754  $  107,181  $  198,372
      per Trust Unit(3)       $     0.35  $     0.74  $     0.73  $     1.42
      per boe                 $    18.26  $    35.62  $    19.21  $    33.46
    Distributions declared    $        -  $   50,364  $   17,266  $  100,385
      per Trust Unit(3)       $        -  $     0.36  $     0.12  $     0.72
    Expenditures on
     property and equipment   $   15,719  $   21,632  $   68,362  $   88,535
    Working capital
     deficit(4)               $  131,913  $   42,201  $  131,913  $   42,201
    Bank indebtedness         $  644,100  $  547,946  $  644,100  $  547,946
    Convertible debentures
     (face value)             $  184,489  $  224,587  $  184,489  $  224,587
    Trust Units outstanding
     at end of period (000)      145,198     140,271     145,198     140,271
    Basic weighted average
     Trust Units (000)           144,681     138,612     144,189     138,105

    Operating
    Daily Production
      Natural gas (mcf/d)        124,990     123,104     121,498     124,109
      Crude oil and NGLs
       (bbls/d)                   10,212      11,498      10,575      11,890
      Total boe/d at 6:1          31,044      32,015      30,825      32,575
    Average prices
     (including hedging)
      Natural gas ($/mcf)     $     5.63  $     9.18  $     6.06  $     8.70
      Crude oil and NGLs
       ($/bbl)                $    54.51  $   101.34  $    54.53  $    92.81

    (1) includes realized derivative gains and losses
    (2) based on basic weighted average Trust Units outstanding
    (3) based on Trust Units outstanding at each distribution record date
    (4) working capital deficit includes accounts receivable, prepaid
        expenses and deposits, accounts payable and accrued liabilities,
        distributions payable, and the current portion of capital lease
        obligations and convertible debentures



                           MESSAGE TO SHAREHOLDERS

    Hedging Gains, Operating Cost Reductions and Lower Royalty Rates
    Mitigates Lower Commodity Prices

    -   For the three months ended June 30 2009, our hedging program
        contributed a gain of $22.2 million to funds from operations which
        helped to partially mitigate a significant reduction in commodity
        prices.

    -   Funds from operations for the second quarter of 2009 was
        $51.6 million as compared to $103.7 million for the same period of
        2008. Funds from operations on a per unit basis decreased 53% to
        $0.35 per Trust Unit compared to $0.74 per Trust Unit for the three
        months ended June 30, 2008.

    -   Operating costs for the three months ended June 30, 2009 was $12.40
        per boe which is a decrease of 9% when compared to the same period in
        2008 and a decrease of 5% from the first quarter of 2009. An
        aggressive optimization program initiated in 2008 continues to
        demonstrate positive benefits and we will seek opportunities to
        further improve our operating cost structure.

    -   Royalties during the second quarter of 2009 decreased 6.2% to a
        royalty rate of 13.8% as compared to the same period of 2008. The
        decrease is driven by significantly lower commodity prices.

    -   Average daily production for the three months ended June 30, 2009
        increased 1% to 31,044 boe/d compared to the first quarter of 2009.
        The increase was due to production recoveries from cold weather
        impacts during the first quarter and production from new wells tied-
        in during the latter part of the second quarter. Production decreased
        3% when compared to the same period of 2008 due primarily to the
        shut-in of 1,100 boe/d (73% natural gas) since August 2008 at our
        Lookout Butte property as a result of a third party facility outage.

    -   Natural gas production for the three months ended June 30, 2009
        increased 2% to 125.0 mmcf/d, compared to 123.1 mmcf/d for the same
        period of 2008 and 6% when compared to the first quarter of 2009.
        Crude oil and natural gas liquids production decreased 11% to
        10,212 bbls/d in the second quarter compared to11,498 bbls/d during
        the same period in 2008 and 7% when compared to the first quarter of
        2009.

    -   The Fund's capital program during the second quarter of 2009 amounted
        to $15.7 million. Total capital spending in the quarter included
        $7.8 million at Glacier, $1.3 million at Martin Creek, and
        $1.0 million at Nevis. Activity at Glacier in the second quarter
        included well tie-ins and installation of a new compressor. Capital
        expenditures at Martin Creek represented the final steps to complete
        the tie-in of wells drilled during the first quarter of 2009. At
        Nevis, activity focused on undertaking preparatory work for new
        Wabamun light oil wells which may be drilled during the remainder of
        2009.

    Montney Development Program at Glacier

    -   Phase I of the Glacier development plan was completed during the
        second quarter of 2009 with the commissioning of new wells, an
        expanded natural gas gathering system, new pipelines and additional
        compression facilities. Gross raw production from the new wells
        averaged 20 to 25 mmcf/d during the latter part of the second quarter
        with typical start-up issues encountered such as the intermittent
        flow-back of frac sand and frac fluid from the horizontal multi-frac
        completions. Production at Glacier will decline during the second
        half of 2009 as our Phase II development program, which involves
        additional well drilling and facilities expansions designed to
        increase production capacity to approximately 50 mmcf/d, will not be
        completed until the second quarter of 2010. .

    -   Regulatory applications for a new 50 mmcf/d gas plant have been
        submitted and drilling has resumed in July with the deployment of up
        to four drilling rigs on operated and joint interest lands.

    -   New wells brought on-stream after March 31, 2009 qualified for the
        Alberta royalty incentive program which results in a 5% royalty rate
        for one year or 0.5 bcf of gas production. Production from the new
        wells will be administered in a sequence that will allow each well to
        qualify for the full royalty credit available. In addition, new wells
        drilled and placed on production after March 31, 2009 to March 31,
        2011 will qualify for the 5% royalty rate and an additional drilling
        credit of $200 per meter of drilled depth.

    -   Advantage will continue to employ a drilling strategy that will
        balance production and reserves growth to delineate our extensive 89
        section gross Montney land block (average 90% working interest).
        Advantage will also continue to closely monitor, evaluate and assess
        well completion design and technology that is being developed by our
        technical staff and our peers in the Montney fairway and in other
        resource plays in both Canada and the U.S. that may lead to further
        improvements in cost efficiencies and results.

    Strong Hedging Program

    -   Advantage's hedging program includes 79% of our net natural gas
        production hedged for the second half of 2009 at an average price of
        $8.17 per mcf and 58% hedged for 2010 at an average price of
        $7.46 per mcf. Crude oil hedges include 54% of our net crude oil
        production hedged at an average floor price of $62.40 Cdn per bbl and
        31% hedged for 2010 at an average price of $67.83 Cdn per bbl.
        Details on our hedging program are available on our website.

    -   Our strategy will be to continue to employ a multi-year hedging
        program to reduce the volatility in cash flow in support of capital
        requirements.

    Completion of Corporate Conversion, Asset Dispositions, Equity Financing
    and A Revised Credit Facility

    -   In July 2009, we completed our conversion to a growth oriented
        corporation and significantly improved our financial flexibility by
        closing our asset disposition program and an equity financing which
        generated gross proceeds of $354.6 million.

    -   Approximately 8,100 boe/d of natural gas weighted assets ((greater
than)74%
        natural gas) was sold resulting in a go forward production base that
        is forecasted to average approximately 23,000 boe/d during the second
        half of 2009.

    -   On August 13, 2009, Advantage's lenders completed their review of the
        borrowing base subsequent to the previously announced closing of the
        asset dispositions. Gross proceeds of $252.6 million were received
        from the asset dispositions and Advantage's credit facility was
        revised from $710 million to $525 million. Advantage's current debt
        is approximately $300 million resulting in an unutilized capacity of
        approximately $225 million on our credit facility. As a result,
        Advantage has significantly improved its financial flexibility in
        support of future capital program requirements and general corporate
        purposes.

    -   Advantage's tax pool position is estimated to be $1.5 billion net of
        dispositions and provides a strong position to shield future cash
        flows from corporate tax.

    Looking Forward

    -   On July 8, 2009, Advantage announced an updated corporate capital
        budget for the 12 month period ending June 2010. The capital budget
        has been set at $207 million and will focus on our Montney natural
        gas resource play at Glacier, Alberta where we will continue to
        employ a phased development approach. Phase II of the development
        plan at Glacier will be undertaken during the next 12 month period.

    -   Corporate estimates for the 12 month period ending June 2010 is
        included below:


    Updated Guidance/Estimates

                                 H2                H1              Total
                                2009              2010           12 Months
                               ------            ------          ----------

    Production (boe/d)    22,700-23,300     24,200-25,200     23,450-24,300
    Royalty Rate (%)         15% to 18%        16% to 19%        15% to 19%
    Operating
     Costs ($/boe)     $12.75 to $13.30  $12.50 to $13.20  $12.60 to $13.25
    Capital
     Expenditures
     ($million)            $105 to $110      $100 to $105      $205 to $215


    A full year 2010 capital budget and guidance will be provided at or about
    year-end 2009.

    -   Production is forecasted to increase in the first half of 2010 as new
        wells will be brought on-stream after additional gathering systems
        and new facilities are completed at Glacier. As a result, production
        declines will occur at Glacier during the second half of 2009 due to
        the timing of new production additions. We anticipate that additional
        production impacts may also occur during the second half of 2009 due
        to increased natural gas production curtailments from joint interest
        and operated properties due to the low price of natural gas. The
        magnitude of potential natural gas production curtailments is
        difficult to forecast at this time.

    -   Approximately 79% of the total capital expenditures for the 12 month
        period will be allocated to Phase II of the Glacier development plan.

    -   Funds from operations for the above 12 month period based on the mid-
        range of guidance is estimated at $204 million using an average NYMEX
        natural gas price of $5.19 US/mmbtu (AECO $4.97 Cdn/mcf), WTI oil
        price of $73.87 US/bbl and an $0.86 Cdn/$US exchange rate.
        Advantage's current hedging positions have been included in the funds
        from operations estimate.

    -   The volatility in funds from operations for the 12 month period has
        been significantly reduced due to our strong hedging position.
    

    Advantage is well positioned to pursue future development plans at
Glacier with our strong balance sheet, strong hedging position and conversion
to a growth oriented corporation. With attractive Glacier well economics at
under AECO $5 Cdn per mcf, management believes a disciplined approach will
create long term growth in shareholder value.


    MANAGEMENT'S DISCUSSION & ANALYSIS

    The following Management's Discussion and Analysis ("MD&A"), dated as of
August 13, 2009, provides a detailed explanation of the financial and
operating results of Advantage Energy Income Fund ("Advantage", the "Fund",
"us", "we" or "our") for the three and six months ended June 30, 2009 and
should be read in conjunction with the consolidated financial statements
contained within this interim report and the audited financial statements and
MD&A for the year ended December 31, 2008. The consolidated financial
statements have been prepared in accordance with Canadian generally accepted
accounting principles ("GAAP") and all references are to Canadian dollars
unless otherwise indicated. All per barrel of oil equivalent ("boe") amounts
are stated at a conversion rate of six thousand cubic feet of natural gas
being equal to one barrel of oil or liquids.

    Forward-Looking Information

    This MD&A contains certain forward-looking statements, which are based on
our current internal expectations, estimates, projections, assumptions and
beliefs. These statements relate to future events or our future performance.
All statements other than statements of historical fact may be forward-looking
statements. Forward-looking statements are often, but not always, identified
by the use of words such as "seek", "anticipate", "plan", "continue",
"estimate", "expect", "may", "will", "project", "predict", "potential",
"targeting", "intend", "could", "might", "should", "believe", "would" and
similar or related expressions. These statements are not guarantees of future
performance.
    In particular, forward-looking statements included in this MD&A include,
but are not limited to, statements with respect to average production and
projected exit rates; areas of operations; spending and capital budgets;
availability of funds for our capital program; the size of, and future net
revenues from, reserves; the focus of capital expenditures; expectations
regarding the ability to raise capital and to continually add to reserves
through acquisitions and development; projections of market prices and costs;
the performance characteristics of our properties; our future operating and
financial results; capital expenditure programs; supply and demand for oil and
natural gas; average royalty rates; and amount of general and administrative
expenses. In addition, statements relating to "reserves" or "resources" are
deemed to be forward-looking statements, as they involve the implied
assessment, based on certain estimates and assumptions, that the resources and
reserves described can be profitably produced in the future.
    These forward-looking statements involve substantial known and unknown
risks and uncertainties, many of which are beyond our control, including the
effect of acquisitions; changes in general economic, market and business
conditions; changes or fluctuations in production levels; unexpected drilling
results, changes in commodity prices, currency exchange rates, capital
expenditures, reserves or reserves estimates and debt service requirements;
changes to legislation and regulations and how they are interpreted and
enforced, changes to investment eligibility or investment criteria; our
ability to comply with current and future environmental or other laws; our
success at acquisition, exploitation and development of reserves; actions by
governmental or regulatory authorities including increasing taxes, changes in
investment or other regulations; the occurrence of unexpected events involved
in the exploration for, and the operation and development of, oil and gas
properties; competition from other producers; the lack of availability of
qualified personnel or management; changes in tax laws, royalty regimes and
incentive programs relating to the oil and gas industry and income trusts;
hazards such as fire, explosion, blowouts, cratering, and spills, each of
which could result in substantial damage to wells, production facilities,
other property and the environment or in personal injury; stock market
volatility; and ability to access sufficient capital from internal and
external sources. Many of these risks and uncertainties are described in
Advantage's Annual Information Form which is available at www.sedar.com and
www.advantageog.com. Readers are also referred to risk factors described in
other documents Advantage files with Canadian securities authorities.
    With respect to forward-looking statements contained in this MD&A,
Advantage has made assumptions regarding: current commodity prices and royalty
regimes; availability of skilled labour; timing and amount of capital
expenditures; future exchange rates; the price of oil and natural gas; the
impact of increasing competition; conditions in general economic and financial
markets; availability of drilling and related equipment; effects of regulation
by governmental agencies; royalty rates and future operating costs.
    Management has included the above summary of assumptions and risks
related to forward-looking information provided in this MD&A in order to
provide Unitholders with a more complete perspective on Advantage's future
operations and such information may not be appropriate for other purposes.
Advantage's actual results, performance or achievement could differ materially
from those expressed in, or implied by, these forward-looking statements and,
accordingly, no assurance can be given that any of the events anticipated by
the forward-looking statements will transpire or occur, or if any of them do
so, what benefits that Advantage will derive there from. Readers are cautioned
that the foregoing lists of factors are not exhaustive. These forward-looking
statements are made as of the date of this MD&A and Advantage disclaims any
intent or obligation to update publicly any forward-looking statements,
whether as a result of new information, future events or results or otherwise,
other than as required by applicable securities laws.

    Corporate Conversion and Asset Dispositions

    On March 18, 2009, we announced that our Board of Directors had approved
conversion to a growth oriented corporation and a strategic asset disposition
program to increase financial flexibility.
    On July 9, 2009, Unitholders of the Fund voted 91.64% in favour of the
corporate conversion at the annual general and special meeting of the Fund,
with subsequent approval by the courts. The conversion will enable Advantage
to pursue a business plan that is focused on the development and growth of the
Montney natural gas resource play at Glacier, Alberta.
    The Fund retained Tristone Capital Inc. to assist with the disposition of
light oil and natural gas producing properties located in Northeast British
Columbia, West Central Alberta and Northern Alberta. Proposals were received
and evaluated by Advantage with two purchase and sale agreements signed for
gross proceeds of $252.6 million, subject to customary adjustments, and
representing production of approximately 8,100 boe/d. Both of these sales
successfully closed in July 2009 with the net proceeds used to reduce
outstanding bank debt. Advantage may utilize its credit facilities in the
future to redeem certain of the Fund's convertible debentures as they mature
and to help finance its future capital program.

    Given these business developments, historical operating and financial
performance will not be indicative of future performance.

    Non-GAAP Measures

    The Fund discloses several financial measures in the MD&A that do not
have any standardized meaning prescribed under GAAP. These financial measures
include funds from operations, funds from operations per Trust Unit and cash
netbacks. Management believes that these financial measures are useful
supplemental information to analyze operating performance, leverage and
provide an indication of the results generated by the Fund's principal
business activities prior to the consideration of how those activities are
financed or how the results are taxed. Investors should be cautioned that
these measures should not be construed as an alternative to net income, cash
provided by operating activities or other measures of financial performance as
determined in accordance with GAAP. Advantage's method of calculating these
measures may differ from other companies, and accordingly, they may not be
comparable to similar measures used by other companies.
    Funds from operations, as presented, is based on cash provided by
operating activities before expenditures on asset retirement and changes in
non-cash working capital. Funds from operations per Trust Unit is based on the
number of Trust Units outstanding during each applicable period. Cash netbacks
are dependent on the determination of funds from operations and include the
primary cash revenues and expenses on a per boe basis that comprise funds from
operations. Funds from operations reconciled to cash provided by operating
activities is as follows:


    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Cash provided by
     operating
     activities       $ 38,956  $ 93,882   (59)%  $ 80,835  $175,475   (54)%
    Expenditures on
     asset retirement    1,045       982     6 %     3,622     5,947   (39)%
    Changes in non-cash
     working capital    11,589     8,890    30 %    22,724    16,950    34 %
    -------------------------------------------------------------------------
    Funds from
     operations       $ 51,590  $103,754   (50)%  $107,181  $198,372   (46)%
    -------------------------------------------------------------------------


    Overview

                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Cash provided by
     operating
     activities
     ($000)           $ 38,956  $ 93,882   (59)%  $ 80,835  $175,475   (54)%
    Funds from
     operations
     ($000)           $ 51,590  $103,754   (50)%  $107,181  $198,372   (46)%
      per Trust
       Unit(1)        $   0.35  $   0.74   (53)%  $   0.73  $   1.42   (49)%

    (1) Based on Trust Units outstanding during each applicable period.
    

    Cash provided by operating activities, funds from operations and funds
from operations per Trust Unit have decreased significantly for the three and
six months ended June 30, 2009 as compared to the same periods of 2008 due to
considerably lower revenue. Lower revenue has been primarily caused by
severely depressed commodity prices, partially offset by substantial gains
realized on strong derivative contracts. The current global recession has
resulted in drastic reductions in commodity prices from lower demand and
perceived excess supply. This challenging environment has continued into the
third quarter of 2009 and we expect to see weak commodity prices for the
near-term.
    The primary factor that causes significant variability of Advantage's
cash provided by operating activities, funds from operations, and net income
is commodity prices. Refer to the section "Commodity Prices and Marketing" for
a more detailed discussion of commodity prices and our price risk management.


    Distributions

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Distributions
     declared ($000)  $      -  $ 50,364  (100)%  $ 17,266  $100,385   (83)%
      per Trust
       Unit(1)        $      -  $   0.36  (100)%  $   0.12  $   0.72   (83)%

    (1) Based on Trust Units outstanding during each applicable period.
    

    There were no distributions declared and paid for the three months ended
June 30, 2009. We paid a distribution of $0.08 per Trust Unit for January 2009
and reduced the monthly distribution to $0.04 per Trust Unit for the February
2009 distribution paid in March 2009. On March 18, 2009, we announced the
discontinuance of future distributions, consistent with our strategy to reduce
debt, increase financial flexibility, and convert to a growth oriented
corporation that will focus capital on our Montney natural gas resource play
at Glacier, Alberta. We converted to a corporation pursuant to a plan of
arrangement completed on July 9, 2009. Going forward, Advantage does not
anticipate paying dividends in the immediate future.


    Revenue

    
                      Three months ended           Six months ended
                            June 30                     June 30
    ($000)              2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Natural gas
     excluding
     hedging          $ 40,482  $115,687   (65)%  $ 97,342  $205,681   (53)%
    Realized hedging
     gains (losses)     23,516   (12,861) (283)%    35,902    (9,151) (492)%
    -------------------------------------------------------------------------
    Natural gas
     including
     hedging          $ 63,998  $102,826   (38)%  $133,244  $196,530   (32)%
    -------------------------------------------------------------------------
    Crude oil and NGLs
     excluding
     hedging          $ 51,939  $115,266   (55)%  $ 94,683  $211,370   (55)%
    Realized hedging
     gains (losses)     (1,278)   (9,224)  (86)%     9,682   (10,527) (192)%
    -------------------------------------------------------------------------
    -------------------------------------------------------------------------
    Crude oil and NGLs
     including
     hedging          $ 50,661  $106,042   (52)%  $104,365  $200,843   (48)%
    -------------------------------------------------------------------------
    Total revenue     $114,659  $208,868   (45)%  $237,609  $397,373   (40)%
    -------------------------------------------------------------------------
    

    Natural gas, crude oil and NGLs revenues, excluding hedging, decreased
significantly for the three and six months ended June 30, 2009, as compared to
2008. This is primarily the result of lower commodity prices from the ongoing
global recession that has reduced demand and increased perceived supply. For
the three month period ended June 30, 2009, realized natural gas prices,
excluding hedging, decreased a substantial 66% while realized crude oil and
NGL prices, excluding hedging, decreased 49%. For the six month period ended
June 30, 2009, realized natural gas prices, excluding hedging, decreased 51%
while realized crude oil and NGL prices, excluding hedging, decreased 49%. As
a result of our commodity price risk management program, we recognized natural
gas and crude oil hedging net gains of $22.2 million and $45.6 million for the
three and six months ended June 30, 2009, respectively. The Fund enters
derivative contracts whereby realized hedging gains and losses partially
offset commodity price fluctuations, which can positively or negatively impact
revenues.


    Production

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Natural gas
     (mcf/d)           124,990   123,104     2 %   121,498   124,109    (2)%
    Crude oil (bbls/d)   7,989     9,311   (14)%     8,331     9,581   (13)%
    NGLs (bbls/d)        2,223     2,187     2 %     2,244     2,309    (3)%
    -------------------------------------------------------------------------
    -------------------------------------------------------------------------
    Total (boe/d)       31,044    32,015    (3)%    30,825    32,575    (5)%
    -------------------------------------------------------------------------
    Natural gas (%)        67%       64%               66%       63%
    Crude oil (%)          26%       29%               27%       29%
    NGLs (%)                7%        7%                7%        8%
    

    Average daily production for the second quarter of 2009 was 1% higher as
compared to the first quarter of 2009, mainly due to recovery from cold
weather conditions that caused production outages and new production from a
number of wells drilled during the first quarter of 2009. Additional new well
production in Alberta was delayed into the second quarter of 2009 such that
benefits from the new royalty incentive program which includes a 5% royalty
rate would be realized. The Fund's total daily production averaged 31,044
boe/d for the three months and 30,825 boe/d for the six months ended June 30,
2009, a decrease of 3% and 5%, respectively compared to the same periods in
2008. Production of 1,100 boe/d at our Lookout Butte property in Southern
Alberta remained shut-in since August 2008 due to an extended third party
outage at the Waterton gas plant where a significant modification project is
underway. The modification project is nearing completion and we will continue
to monitor the development and consider the appropriate timing for bringing
this production on-stream given the current commodity price environment.
    On March 18, 2009, we announced the intention to dispose of light oil and
natural gas producing properties located in Northeast British Columbia, West
Central Alberta and Northern Alberta. Proposals were received and evaluated by
Advantage with two purchase and sale agreements signed for gross proceeds of
$252.6 million, subject to customary adjustments, and representing production
of approximately 8,100 boe/d. Both of these sales closed successfully in July
2009 with the net proceeds used to reduce outstanding bank debt.

    
    Commodity Prices and Marketing


    Natural Gas

                      Three months ended           Six months ended
                            June 30                     June 30
    ($/mcf)             2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Realized natural
     gas prices
      Excluding
       hedging        $   3.56  $  10.33   (66)%  $   4.43  $   9.11   (51)%
      Including
       hedging        $   5.63  $   9.18   (39)%  $   6.06  $   8.70   (30)%
    AECO monthly
     index            $   3.66  $   9.35   (61)%  $   4.64  $   8.24   (44)%
    

    Realized natural gas prices, excluding hedging, were significantly lower
for the three and six months ended June 30, 2009 than the same periods of 2008
and decreased 34% from the first quarter of 2009. The 2007/2008 winter season
in North America caused inventory levels to decline to approximately the
five-year average resulting in stronger prices during early 2008. However, the
second half of 2008 and the first half of 2009 experienced significant
softening of natural gas prices from higher US domestic natural gas
production, mild weather conditions and forecasts, and the ongoing global
recession that has impacted demand. These factors have resulted in much higher
inventory levels that continue to place considerable downward pressure on
natural gas prices. Unfortunately, these conditions have also continued beyond
the second quarter of 2009 with AECO gas presently trading at approximately
$2.90/GJ. Although we continue to believe in the longer-term pricing
fundamentals for natural gas, we are concerned about the current pricing and
economic environment that has the potential to extend for a considerable
period of time. The global recession could delay the recovery of natural gas
pricing longer than anticipated. While the current pricing situation is quite
weak, some of the factors that we believe will support stronger future natural
gas prices include: (i) significantly less natural gas drilling in Canada and
the US projected for 2009, which will reduce productivity to offset declines,
(ii) the increasing focus on resource style natural gas wells, which have high
initial declines, and which are becoming a larger proportion of the total
natural gas supply based in Canada and the US, (iii) the potential demand for
natural gas for the Canadian oil sands projects, and (iv) fuel switching to
natural gas.


    Crude Oil and NGLs

    
                      Three months ended           Six months ended
                            June 30                     June 30
    ($/bbl)             2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Realized crude
     oil prices
      Excluding
       hedging        $  61.13  $ 113.71   (46)%  $  52.74  $ 100.57   (48)%
      Including
       hedging        $  59.37  $ 102.83   (42)%  $  59.17  $  94.53   (37)%
    Realized NGLs
     prices
      Excluding
       hedging        $  37.06  $  95.02   (61)%  $  37.30  $  85.67   (56)%
    Realized crude
     oil and NGL
     prices
      Excluding
       hedging        $  55.89  $ 110.15   (49)%  $  49.47  $  97.68   (49)%
      Including
       hedging        $  54.51  $ 101.34   (46)%  $  54.53  $  92.81   (41)%
    WTI ($US/bbl)     $  59.62  $ 124.00   (52)%  $  51.46  $ 110.98   (54)%
    $US/$Canadian
     exchange rate    $   0.86  $   0.99   (13)%  $   0.83  $   0.99   (16)%
    

    Realized crude oil and NGLs prices, excluding hedging, decreased notably
for the three and six month ended June 30, 2009, as compared to the same
periods of 2008 but increased 29% from the first quarter of 2009. Advantage's
realized crude oil price may not change to the same extent as WTI, due to
changes in the $US/$Canadian exchange rate, and changes in Canadian crude oil
differentials relative to WTI. The price of WTI fluctuates based on worldwide
supply and demand fundamentals. There has been significant price volatility
experienced over the last several years whereby WTI reached historic high
levels in the first half of 2008, followed by a record decline in the latter
half of the year and into 2009, the result of demand destruction brought on by
the current global recession. There has been a respectable improvement during
the second quarter of 2009, and WTI is currently trading at approximately
US$70/bbl. We continue to believe that the long-term pricing fundamentals for
crude oil remain strong with many factors affecting the continued strength
including (i) supply management and supply restrictions by the OPEC cartel,
(ii) frequent civil unrest in various crude oil producing countries and
regions, (iii) strong relative demand in developing countries, particularly in
China and India, and (iv) production declines and reduced drilling.

    Commodity Price Risk

    The Fund's operational results and financial condition will be dependent
on the prices received for oil and natural gas production. Oil and natural gas
prices have fluctuated widely during recent years and are determined by
economic and, in the case of oil prices, political factors. Supply and demand
factors, including weather and general economic conditions as well as
conditions in other oil and natural gas regions, impact prices. Any movement
in oil and natural gas prices could have an effect on the Fund's financial
condition and performance. As current and future practice, Advantage has
established a financial hedging strategy and may manage the risk associated
with changes in commodity prices by entering into derivatives. Although these
commodity price risk management activities could expose Advantage to losses or
gains, entering derivative contracts helps us to stabilize cash flows and
ensures that our capital expenditure program is substantially funded by such
cash flows. To the extent that Advantage engages in risk management activities
related to commodity prices, it will be subject to credit risk associated with
counterparties with which it contracts. Credit risk is mitigated by entering
into contracts with only stable, creditworthy parties and through frequent
reviews of exposures to individual entities.
    We have been active in entering new financial contracts to protect future
cash flows and currently the Fund has fixed commodity prices on anticipated
production as follows:


    
                                  Approximate
                                   Production
                                Hedged, Net of     Average         Average
    Commodity                     Royalties(1)   Floor Price   Ceiling Price
    -------------------------------------------------------------------------
    Natural gas - AECO
      July to September 2009          76%       Cdn$8.17/mcf    Cdn$8.17/mcf
      October to December 2009        81%       Cdn$8.17/mcf    Cdn$8.17/mcf
      -----------------------------------------------------------------------
      July to December 2009           79%       Cdn$8.17/mcf    Cdn$8.17/mcf
      -----------------------------------------------------------------------
      January to March 2010           81%       Cdn$7.64/mcf    Cdn$7.64/mcf
      April to June 2010              59%       Cdn$7.53/mcf    Cdn$7.53/mcf
      July to September 2010          45%       Cdn$7.27/mcf    Cdn$7.27/mcf
      October to December 2010        46%       Cdn$7.27/mcf    Cdn$7.27/mcf
      -----------------------------------------------------------------------
      Total 2010                      58%       Cdn$7.46/mcf    Cdn$7.46/mcf
      -----------------------------------------------------------------------

      January to March 2011            8%       Cdn$7.25/mcf    Cdn$7.25/mcf
      -----------------------------------------------------------------------

    Crude Oil - WTI
      July to September 2009          54%      Cdn$62.40/bbl   Cdn$69.40/bbl
      October to December 2009        53%      Cdn$62.40/bbl   Cdn$69.40/bbl
      -----------------------------------------------------------------------
      July to December 2009           54%      Cdn$62.40/bbl   Cdn$69.40/bbl
      -----------------------------------------------------------------------
      January to March 2010           28%      Cdn$62.80/bbl   Cdn$62.80/bbl
      April to June 2010              30%      Cdn$69.50/bbl   Cdn$69.50/bbl
      July to September 2010          32%      Cdn$69.50/bbl   Cdn$69.50/bbl
      October to December 2010        34%      Cdn$69.50/bbl   Cdn$69.50/bbl
      -----------------------------------------------------------------------
      Total 2010                      31%      Cdn$67.83/bbl   Cdn$67.83/bbl
      -----------------------------------------------------------------------

      January to March 2011           12%      Cdn$69.50/bbl   Cdn$69.50/bbl
      -----------------------------------------------------------------------
    (1) Approximate production hedged is based on our assumed average
        production by quarter, net of royalty payments, and takes into
        consideration our asset dispositions that closed in July 2009.
    

    For the six month period ended June 30, 2009, we recognized in income a
net realized derivative gain of $45.6 million (June 30, 2008 - $19.7 million
net realized derivative loss) on settled derivative contracts. As at June 30,
2009, the fair value of the derivatives outstanding and to be settled was a
net asset of approximately $40.8 million (December 31, 2008 - $41.0 million
net asset). For the six months ended June 30, 2009, $0.2 million was
recognized in income as an unrealized derivative loss (June 30, 2008 - $123.9
million unrealized derivative loss) due to changes in the fair values of these
contracts since December 31, 2008. The valuation of the derivatives is the
estimated fair value to settle the contracts as at June 30, 2009 and is based
on pricing models, estimates, assumptions and market data available at that
time. As such, the recognized amounts are not cash and the actual gains or
losses realized on eventual cash settlement can vary materially due to
subsequent fluctuations in commodity prices as compared to the valuation
assumptions. The Fund does not apply hedge accounting and current accounting
standards require changes in the fair value to be included in the consolidated
statement of loss and comprehensive loss as an unrealized derivative gain or
loss with a corresponding derivative asset and liability recorded on the
balance sheet. These derivative contracts will settle from July 2009 to
January 2011 corresponding to when Advantage will receive revenues from
production.


    Royalties

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Royalties ($000)  $ 12,791  $ 46,173   (72)%  $ 28,871  $ 80,054   (64)%
      per boe         $   4.53  $  15.85   (71)%  $   5.17  $  13.50   (62)%
    As a percentage
     of revenue,
     excluding hedging   13.8%     20.0%  (6.2)%     15.0%     19.2%  (4.2)%
    

    Advantage pays royalties to the owners of mineral rights from which we
have leases. The Fund currently has mineral leases with provincial
governments, individuals and other companies. Royalties have decreased in
total for the three and six months ended June 30, 2009 compared to the same
periods of 2008 due to the decrease in revenue from significantly lower
commodity prices. Royalties as a percentage of revenue, excluding hedging,
have decreased as compared to 2008. Effective January 1, 2009, the Alberta
Provincial Government implemented a new royalty framework for conventional
oil, natural gas and oil sands and Alberta royalties are now affected by
depths and productivity of wells and commodity prices. Given our production
profile and the current commodity price environment, our royalty rate has
decreased as compared to prior periods. We expect the royalty rate to be in
the range of 13% to 16% for 2009 given the current commodity price
environment.


    Operating Costs

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Operating costs
     ($000)           $ 35,030  $ 39,917   (12)%  $ 71,061  $ 80,189   (11)%
      per boe         $  12.40  $  13.70    (9)%  $  12.74  $  13.53    (6)%
    

    Total operating costs decreased 12% and 11% for the three and six months
ended June 30, 2009 as compared to the 2008 respective periods, which resulted
in a reduction in operating costs per boe by 9% and 6%. When compared to the
first quarter of 2009, total operating costs decreased 3% and operating costs
per boe decreased by 5%. An aggressive optimization program through 2008 and
into 2009 is continuing to demonstrate positive benefits and we will seek
further opportunities to improve our operating cost structure.


    General and Administrative

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    General and
     administrative
      expense ($000)  $  7,848  $  5,763    36 %  $ 15,228  $ 12,995    17 %
      per boe         $   2.78  $   1.98    40 %  $   2.73  $   2.19    25 %
    Employees at
     June 30                                           158       174    (9)%
    

    General and administrative ("G&A") expense for the three and six months
ended June 30, 2009 has increased compared to the same periods of 2008 due to
costs of approximately $1.8 million incurred for the conversion of the Fund to
a corporation that was completed in July 2009. We expect to see additional
residual costs related to the corporate conversion in the third quarter of
2009. As well, total G&A for 2009 includes the recognition of $1.7 million of
unit-based compensation expense related to Restricted Trust Units ("RTUs")
granted to employees by the Board of Directors in January 2009. A total of
171,093 Trust Units were issued to employees for the first one-third of the
grant that vested. The remaining two-thirds of the RTUs granted will vest over
the subsequent two yearly anniversary dates with corresponding compensation
expense recognized over the service period.


    Management Internalization

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Management
     internalization
     ($000)           $    760  $  2,439   (69)%  $  1,724  $  4,930   (65)%
      per boe         $   0.27  $   0.84   (68)%  $   0.31  $   0.83   (63)%
    

    In 2006, the Fund and Advantage Investment Management Ltd. (the
"Manager") reached an agreement to internalize the pre-existing management
contract arrangement. As part of the agreement, Advantage agreed to purchase
all of the outstanding shares of the Manager pursuant to the terms of the
arrangement, thereby eliminating the management fee and performance incentive
effective April 1, 2006. The Trust Unit consideration issued in exchange for
the outstanding shares of the Manager was placed in escrow for a 3-year period
and was deferred and amortized into income as management internalization
expense over the specific vesting periods during which employee services were
provided. Management internalization is lower for the three and six months
ended June 30, 2009 compared to the same periods of 2008 as the Trust Units
held in escrow continue to vest during the service period. As of June 23,
2009, the final Trust Units held in escrow vested and there will be no
subsequent management internalization expense recognized.


    Interest on Bank Indebtedness

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Interest expense
     ($000)           $  3,439  $  7,118   (52)%  $  8,355  $ 14,884   (44)%
      per boe         $   1.22  $   2.44   (50)%  $   1.50  $   2.51   (40)%
    Average effective
     interest rate        2.2%      5.1%  (2.9)%      2.8%      5.4%  (2.6)%
    Bank indebtedness
     at June 30 ($000)                            $644,100  $547,946    18 %
    

    Total interest expense decreased 52% and 44% for the three and six months
ended June 30, 2009 as compared to 2008, respectively. The interest expense
decrease is the result of lower interest rates as bank lending rates have
declined significantly in response to rate reductions enacted by central banks
to stimulate the economy. We monitor the debt level to ensure an optimal mix
of financing and cost of capital that will provide a maximum return to our
Unitholders. Our current credit facilities have been a favorable financing
alternative with an effective interest rate of only 2.2% for the three months
ended June 30, 2009. The Fund's interest rates are primarily based on short
term Bankers Acceptance rates plus a stamping fee. In June 2009 our credit
facility was renewed and is subject to higher basis point and stamping fee
adjustments ranging from 1.5% to 5.5%, depending on the Fund's debt to cash
flow ratio. Therefore, we expect that our average effective interest rate will
increase from current levels during the following quarters; however, this will
be somewhat offset by lower interest expense on the reduced debt level that
has resulted from the July 2009 asset dispositions and equity financing.


    Interest and Accretion on Convertible Debentures

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Interest on
     convertible
     debentures
     ($000)           $  4,009  $  4,204    (5)%  $  7,978  $  8,391    (5)%
      per boe         $   1.42  $   1.44    (1)%  $   1.43  $   1.42     1 %
    Accretion on
     convertible
     debentures
     ($000)           $    681  $    720    (5)%  $  1,363  $  1,440    (5)%
      per boe         $   0.24  $   0.25    (4)%  $   0.24  $   0.24     - %
    Convertible
     debentures
     maturity value
     at June 30 ($000)                            $184,489  $224,587   (18)%
    

    Interest and accretion on convertible debentures for the three and six
months ended June 30, 2009 has decreased compared to 2008 due to the maturity
of the 9.00% debentures on August 1, 2008 and the 8.25% debentures on February
1, 2009. On June 30, 2009, our 8.75% debentures matured and will result in
lower interest and accretion in subsequent periods.


    Depletion, Depreciation and Accretion

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Depletion,
     depreciation and
     accretion ($000) $ 72,177  $ 74,704    (3)%  $142,099  $151,584    (6)%
      per boe         $  25.55  $  25.64     - %  $  25.47  $  25.57     - %
    

    Depletion and depreciation of fixed assets is provided on the
"unit-of-production" method based on total proved reserves. Accretion
represents the increase in the asset retirement obligation liability each
reporting period due to the passage of time. The depletion, depreciation and
accretion ("DD&A") provision has decreased modestly for the three and six
months ended June 30, 2009 compared to 2008 due to the slightly lower
production. On a per boe basis, DD&A has remained constant.

    Taxes

    Current taxes paid or payable for the six months ended June 30, 2009
amounted to $0.6 million, compared to $1.6 million expensed for the same
period of 2008. Current taxes primarily represent Saskatchewan resource
surcharge, which is based on the petroleum and natural gas revenues within the
province of Saskatchewan. The reduction from 2008 is primarily due to the
corresponding decrease in commodity prices during 2009.
    Under the Fund's current structure, payments are made between the
operating company and the Fund transferring income tax obligations to
Unitholders and as a result no cash income taxes would be paid by the
operating company or the Fund prior to 2011. However, the Specified Investment
Flow-Through Entity ("SIFT") tax legislation was enacted on June 22, 2007
altering the tax treatment by subjecting income trusts to a two-tier tax
structure, similar to that of corporations, whereby the taxable portion of
distributions paid by trusts will be subject to tax at the trust level and at
the Unitholder level. The rules are effective for tax years beginning in 2011
for existing publicly-traded trusts. Canadian generally accepted accounting
principles require that a future income tax liability be recorded when the
book value of assets exceeds the balance of tax pools.
    On March 12, 2009, the Government of Canada enacted legislation reducing
the provincial component of the SIFT tax from 13% to 10%, resulting in a
future income tax reduction of approximately $8.9 million during the first
quarter of 2009.
    Under Canadian GAAP, the future income tax impact of the planned
corporate conversion, which was completed on July 9, 2009, is to be recorded
in the fiscal period that the conversion occurs.
    For the six months ended June 30, 2009, the Fund recognized a total
future income tax reduction of $20.9 million compared to $44.0 million for the
same period of 2008. As at June 30, 2009, the Fund had a future income tax
liability balance of $35.0 million, compared to $55.9 million at December 31,
2008.


    Net Loss

    
                      Three months ended           Six months ended
                            June 30                     June 30
                        2009      2008  % change    2009      2008  % change
    -------------------------------------------------------------------------
    Net loss ($000)   $(37,810) $(14,369)  163 %  $(18,920) $(38,491)  (51)%
      per Trust Unit
       - Basic and
       Diluted        $  (0.26) $  (0.10)  160 %  $  (0.13) $  (0.28)  (54)%
    

    Net loss for the three months ended June 30, 2009 was $37.8 million, as
compared to a net loss of $14.4 million for the same period of 2008. For the
six months ended June 30, 2009, we experienced a net loss of $18.9 million, as
opposed to the $38.5 million net loss for the first six months of 2008. The
first half of 2009 has presented major challenges relating to the commodity
price environment that has adversely impacted revenues, partially offset from
a corresponding reduction in royalties and lower Alberta royalty rates. The
lower revenues have resulted in a larger net loss for the three months ended
June 30, 2009 as compared to the same period of 2008. Regardless of these
industry challenges, we were able to deliver significant results that
contributed to reduce our net loss for the first six months of 2009. Advantage
implemented a very successful commodity price risk management program that
resulted in $45.6 million of realized derivative gains. Through our ongoing
optimization efforts, we were also able to reduce operating costs and plan to
continue these positive efforts in 2009. We also recognized significant
benefits from reduced interest rates on bank indebtedness, and a future income
tax reduction from a lower provincial component of the SIFT tax.


    Cash Netbacks

    
                                            Three months ended
                                                  June 30
                                        2009                    2008
                                  $000       per boe      $000       per boe
    -------------------------------------------------------------------------
    Revenue                   $   92,421  $    32.72  $  230,953  $    79.27
    Realized gain (loss)
     on derivatives               22,238        7.87     (22,085)      (7.58)
    Royalties                    (12,791)      (4.53)    (46,173)     (15.85)
    Operating costs              (35,030)     (12.40)    (39,917)     (13.70)
    -------------------------------------------------------------------------
    Operating                 $   66,838  $    23.66  $  122,778  $    42.14
    General and
     administrative(1)            (7,456)      (2.64)     (6,831)      (2.34)
    Interest                      (3,439)      (1.22)     (7,118)      (2.44)
    Interest on convertible
     debentures(1)                (4,009)      (1.42)     (4,204)      (1.44)
    Income and capital taxes        (344)      (0.12)       (871)      (0.30)
    -------------------------------------------------------------------------
    Funds from operations     $   51,590  $    18.26  $  103,754  $    35.62
    -------------------------------------------------------------------------


                                             Six months ended
                                                  June 30
                                        2009                    2008
                                  $000       per boe      $000       per boe
    -------------------------------------------------------------------------
    Revenue                   $  192,025  $    34.42  $  417,051  $    70.35
    Realized gain (loss)
     on derivatives               45,584        8.17     (19,678)      (3.32)
    Royalties                    (28,871)      (5.17)    (80,054)     (13.50)
    Operating costs              (71,061)     (12.74)    (80,189)     (13.53)
    -------------------------------------------------------------------------
    Operating                 $  137,677  $    24.68  $  237,130  $    40.00
    General and
     administrative(1)           (13,539)      (2.43)    (13,924)      (2.35)
    Interest                      (8,355)      (1.50)    (14,884)      (2.51)
    Interest on convertible
     debentures(1)                (7,978)      (1.43)     (8,391)      (1.42)
    Income and capital taxes        (624)      (0.11)     (1,559)      (0.26)
    -------------------------------------------------------------------------
    Funds from operations     $  107,181  $    19.21  $  198,372  $    33.46
    -------------------------------------------------------------------------
    (1) General and administrative expense excludes non-cash unit-based
        compensation expense. Interest on convertible debentures excludes
        non-cash accretion expense.
    

    Funds from operations and cash netbacks decreased in total and per boe
for the three and six months ended June 30, 2009 compared to the same periods
of 2008. As compared to the first quarter of 2009, cash netbacks decreased 10%
from $20.19 per boe for that period. The lower cash netback in total and per
boe is primarily due to much weaker commodity prices, particularly natural
gas, which adversely impacted revenue. However, as a result of our successful
commodity price risk management program, we were able to recognize significant
gains on derivatives. Royalties also decreased during the periods as would be
expected since they are significantly influenced by commodity prices.
Operating costs, which had increased steadily over the 2008 year, have started
to decrease as we begin to realize benefits from our ongoing optimization
efforts. We have also realized modest benefits from lower interest expense.

    Contractual Obligations and Commitments

    The Fund has contractual obligations in the normal course of operations
including purchases of assets and services, operating agreements,
transportation commitments, sales contracts and convertible debentures. These
obligations are of a recurring and consistent nature and impact cash flow in
an ongoing manner. The following table is a summary of the Fund's remaining
contractual obligations and commitments. Advantage has no guarantees or
off-balance sheet arrangements other than as disclosed.


    
                                            Payments due by period
    ($ millions)                   Total     2009     2010     2011     2012
    -------------------------------------------------------------------------
    Building leases              $   8.4  $   1.9  $   3.9  $   1.5  $   1.1
    Capital leases                   5.3      1.2      2.2      1.9        -
    Pipeline/transportation          3.9      1.4      2.0      0.5        -
    Convertible debentures(1)      184.4     52.2     69.9     62.3        -
    -------------------------------------------------------------------------
    Total contractual
     obligations                 $ 202.0  $  56.7  $  78.0  $  66.2  $   1.1
    -------------------------------------------------------------------------
    -------------------------------------------------------------------------
    (1) As at June 30, 2009, Advantage had $184.4 million convertible
        debentures outstanding (excluding interest payable during the various
        debenture terms). Each series of convertible debentures are
        convertible to Trust Units based on an established conversion price.
        All remaining obligations related to convertible debentures can be
        settled through the payment of cash or issuance of Trust Units at
        Advantage's option.
    (2) Bank indebtedness of $644.1 million has been excluded from the
        contractual obligations table as the credit facilities constitute a
        revolving facility for a 364 day term which is extendible annually
        for a further 364 day revolving period at the option of the
        syndicate. If not extended, the revolving credit facility is
        converted to a one year term facility with repayment due one year
        after commencement of the term.

    Liquidity and Capital Resources

    The following table is a summary of the Fund's capitalization structure.


    ($000, except as otherwise indicated)                      June 30, 2009
    -------------------------------------------------------------------------
    Bank indebtedness (long-term)                                $   644,100
    Working capital deficit(1)                                       131,913
    -------------------------------------------------------------------------
    Net debt                                                     $   776,013
    -------------------------------------------------------------------------
    Trust Units outstanding (000)                                    145,198
    Trust Units closing market price ($/Trust Unit)              $      4.90
    -------------------------------------------------------------------------
    Market value                                                 $   711,470
    -------------------------------------------------------------------------
    Convertible debentures maturity value (long-term)            $    62,294
    Capital lease obligation (long term)                         $     2,970
    -------------------------------------------------------------------------
    Total capitalization                                         $ 1,552,747
    -------------------------------------------------------------------------
    (1) Working capital deficit includes accounts receivable, prepaid
        expenses and deposits, accounts payable and accrued liabilities, and
        the current portion of capital lease obligations and convertible
        debentures.
    

    Advantage monitors its capital structure and makes adjustments according
to market conditions in an effort to meet its objectives given the current
outlook of the business and industry in general. The capital structure of the
Fund is composed of working capital (excluding derivative assets and
liabilities), bank indebtedness, convertible debentures, capital lease
obligations and Unitholders' equity. Advantage may manage its capital
structure by issuing new Trust Units, obtaining additional financing either
through bank indebtedness or convertible debenture issuances, refinancing
current debt, issuing other financial or equity-based instruments, adjusting
or discontinuing the amount of monthly distributions, suspending or renewing
its distribution reinvestment plan, adjusting capital spending, or disposing
of assets. The capital structure is reviewed by Management and the Board of
Directors on an ongoing basis.
    Management of the Fund's capital structure is facilitated through its
financial and operational forecasting processes. The forecast of the Fund's
future cash flows is based on estimates of production, commodity prices,
forecast capital and operating expenditures, and other investing and financing
activities. The forecast is regularly updated based on new commodity prices
and other changes, which the Fund views as critical in the current
environment. Selected forecast information is frequently provided to the Board
of Directors. This continual financial assessment process further enables the
Fund to mitigate risks. The Fund continues to satisfy all liabilities and
commitments as they come due. We had an established $710 million credit
facility agreement with a syndicate of financial institutions; the balance of
which utilized at June 30, 2009 was $644.1 million. This facility was renewed
in June 2009 and was comprised of a $20 million revolving operating loan
facility, a $630 million extendible revolving credit facility and a $60
million liquidity facility. Subsequent to our asset dispositions that closed
in July 2009, we have renegotiated and finalized our new credit facility for
the corporation, that will be $525 million, consisting of a $20 million
revolving operating loan facility and a $505 million extendible revolving
credit facility. The Fund additionally has convertible debentures that will
mature in 2009, whereby we have the option to settle such obligations by cash
or though the issuance of Trust Units. The current economic situation has
placed additional pressure on commodity prices. Crude oil has dropped from a
historic high in 2008 to approximately US$70/bbl. The impact from the decrease
in WTI will be somewhat mitigated for Advantage due to the strengthening US
dollar relative to the Canadian dollar. Natural gas prices that had been
improving early in 2008, have now declined due to the ailing economy as well
as increased inventory levels from strong injections and mild weather. Natural
gas has dropped with AECO gas presently trading at approximately $2.90/GJ. The
outlook for the Fund from prolonged weak commodity prices would be reductions
in operating netbacks and funds from operations. Management has partially
mitigated this risk through our commodity hedging program but the lower
commodity price environment has still had a significant negative impact. In
order to strengthen our financial position and balance our cash flows, the
monthly distribution was discontinued to repay debt and focus capital spending
on our Montney natural gas resource play.
    In summary, we have implemented a strategy to balance funds from
operations and capital program expenditure requirements. A successful hedging
program was also executed to help reduce the volatility of our funds from
operations. As a result, we feel that Advantage has implemented adequate
strategies to protect our business as much as possible in this environment.
However, as with all companies, we are still exposed to risks as a result of
the current economic situation and the potential duration. We continue to
closely monitor the possible impact on our business and strategy, and will
make adjustments as necessary with prudent management.

    Unitholders' Equity and Convertible Debentures

    Advantage has utilized a combination of Trust Units, convertible
debentures and bank debt to finance acquisitions and development activities.
    As at June 30, 2009, the Fund had 145.2 million Trust Units outstanding.
During the six months ended June 30, 2009, 1,263,158 Trust Units were issued
as a result of the Premium Distribution(TM), Distribution Reinvestment and
Optional Trust Unit Purchase Plan (the "Plan"), generating $5.2 million
reinvested in the Fund (June 30, 2008 - 1,854,776 Trust Units were issued
under the Plan, generating $19.5 million reinvested in the Fund). As at August
13, 2009, Trust Units outstanding increased to 162.2 million due to 17 million
Trust Units issued on July 7, 2009, through a bought deal financing that
raised gross proceeds of $102 million. The proceeds were utilized to reduce
bank indebtedness.
    At June 30, 2009, the Fund had $184.4 million convertible debentures
outstanding that were immediately convertible to 8.4 million Trust Units based
on the applicable conversion prices (December 31, 2008 - $219.2 million
outstanding and convertible to 9.5 million Trust Units). During the six months
ended June 30, 2009, there were no conversions of debentures (June 30, 2008 -
$25,000 converted resulting in the issuance of 1,001 Trust Units). The
principal amount of 8.25% convertible debentures matured on February 1, 2009
and was settled by issuing 946,887 Trust Units while the 8.75% convertible
debentures that matured on June 30, 2009 was settled with $29.8 million in
cash. As at August 13, 2009, the convertible debentures outstanding have not
changed from June 30, 2009. We have $52.2 million of 7.50% debentures that
mature on October 1, 2009. These obligations can be settled through the
payment of cash or issuance of Trust Units at Advantage's option.

    Bank Indebtedness, Credit Facility and Other Obligations

    At June 30, 2009, Advantage had bank indebtedness outstanding of $644.1
million. Bank indebtedness increased $56.7 million since December 31, 2008 as
a significant portion of our 2009 capital expenditure program was incurred
during the first half of 2009 and $29.8 million principal amount of debentures
matured and was settled with cash on June 30, 2009. The Fund renewed its
credit facility in June 2009 which was a $710 million credit facility as at
June 30, 2009. However, given our asset dispositions that closed in July 2009,
we have renegotiated and finalized a new credit facility of $525 million,
comprised of a $20 million revolving operating loan facility and a $505
million extendible revolving credit facility. The net proceeds from the asset
dispositions were used to reduce our outstanding bank debt to improve
Advantage's financial flexibility. The credit facilities are secured by a $1
billion floating charge demand debenture, a general security agreement and a
subordination agreement from the Fund covering all assets and cash flows. As
well, the borrowing base for the Fund's credit facilities is determined
through utilizing our regular reserve estimates. The banking syndicate
thoroughly evaluates the reserve estimates based upon their own commodity
price expectations to determine the amount of the borrowing base. Revision or
changes in the reserve estimates and commodity prices can have either a
positive or a negative impact on the borrowing base of the Fund. The next
annual review is scheduled to occur in June 2010. There can be no assurances
that the $525 million credit facility will be renewed at the current borrowing
base level at that time. As at August 13, 2009, our bank indebtedness was
approximately $300 million with unutilized room of $225 million.
    Advantage had a working capital deficiency of $131.9 million as at June
30, 2009. Our working capital includes items expected for normal operations
such as trade receivables, prepaids, deposits, trade payables and accruals as
well as the current portion of capital lease obligations. Working capital
varies primarily due to the timing of such items, the current level of
business activity including our capital program, commodity price volatility,
and seasonal fluctuations. We do not anticipate any problems in meeting future
obligations as they become due given our funds from operations. It is also
important to note that working capital is effectively integrated with
Advantage's operating credit facility, which assists with the timing of cash
flows as required. The increase in our working capital deficiency is due to
the additional inclusion in current liabilities of $121.2 million of
convertible debentures that mature during the next twelve months. We have
$52.2 million of 7.50% debentures that mature on October 1, 2009 and $69.9
million of 6.50% debentures that mature on June 30, 2010. Advantage has
capital lease obligations on various pieces of equipment used in its
operations. The total amount of principal obligation outstanding at June 30,
2009 is $5.0 million, bearing interest at effective rates ranging from 5.5% to
6.7%, and is collateralized by the related equipment. The leases expire at
dates ranging from December 2009 to August 2010.


    Capital Expenditures

    
                                 Three months ended       Six months ended
                                       June 30                 June 30
    ($000)                        2009        2008        2009        2008
    -------------------------------------------------------------------------
    Land and seismic          $       40  $       11  $    1,707  $    4,181
    Drilling, completions
     and workovers                 4,526       9,425      42,138      46,169
    Well equipping and
     facilities                   11,082      11,978      24,379      37,576
    Other                             71         218         138         609
    -------------------------------------------------------------------------
                              $   15,719  $   21,632  $   68,362  $   88,535
    Property dispositions           (860)          -      (1,619)        (91)
    -------------------------------------------------------------------------
    Total capital
     expenditures             $   14,859  $   21,632  $   66,743  $   88,444
    -------------------------------------------------------------------------
    -------------------------------------------------------------------------
    

    Advantage's exploitation and development program focuses on areas where
past activity has yielded long-life reserves with high cash netbacks. We are
very well positioned to selectively exploit the highest value-generating
drilling opportunities given the size, strength and diversity of our asset
base as evidenced by our success at Glacier, Nevis and several other key
properties. As a result, the Fund has a high level of flexibility to allocate
its capital program and ensure a risk-balanced platform of projects. Our
preference is to operate a high percentage of our properties such that we can
maintain control of capital expenditures, operations and cash flows.
Advantage's acquisition strategy has been to acquire long-life properties with
strong drilling opportunities while retaining a balance of year round access
and risk.
    For the six month period ended June 30, 2009, the Fund spent a net $68.4
million and drilled a total of 9.6 net (11 gross) wells at a 100% success
rate. Total capital spending included $48.4 million at Glacier, $6.3 million
at Martin Creek, and the remaining balance at other miscellaneous areas.
Glacier capital spending included 3 net (3 gross) horizontal wells and 2 net
(2 gross) vertical wells. Two new Montney horizontal wells were brought
on-stream at combined rates of 8 to 10 mmcf/d at the end of January 2009.
Facilities work involving the expansion of compression facilities and our
pipeline gathering system was completed at the end of the quarter and has
taken our overall facility capacity to 25 mmcf/d after commissioning the
expansion in the second quarter of 2009. With the facilities work completed,
our Montney wells drilled in the fourth quarter of 2008 and the first quarter
of 2009 were brought on-stream during the latter portion of the second quarter
of 2009 at total well rates of between 20 and 25 mmcf/d. The new wells brought
on-stream will qualify for the Alberta royalty incentive program which results
in a 5% royalty rate for one year or 0.5 bcf of gas production. Activity is
now underway at Glacier to increase production capacity to 50 mmcf/d by mid
2010. At Nevis, activity focused on increasing battery capacity and
preparatory work for new Wabamun light oil wells which may be drilled during
the remainder of 2009.
    On July 8, 2009, the Board of Directors approved a new capital budget for
the twelve month period beginning July 2009 and ending June 2010. Management
will review the capital program on a regular basis in the context of
prevailing economic conditions and make adjustments as deemed necessary to the
program, subject to review by the Board of Directors.
    Advantage's corporate capital budget for the 12 month period ending June
2010 has been set at $207 million, with $105 to $110 million for the remainder
of 2009. The budget will focus on development of our Montney natural gas
resource play at Glacier, Alberta where Advantage will continue to employ a
phased development approach. Phase I of the development plan was achieved
during the second quarter of 2009 where production capacity was increased to
approximately 25 mmcf/d and included wells, compression facilities and
additional pipelines. Phase II of the development plan will be undertaken
during the next 12 months and will result in production capacity increasing to
approximately 50 mmcf/d by mid 2010. Phase III of the development plan will
result in the attainment of 100 mmcf/d by mid 2011. Approximately 79% of the
total capital expenditures for the 12 month period will be allocated to
Glacier.

    Sources and Uses of Funds

    The following table summarizes the various funding requirements during
the six months ended June 30, 2009 and 2008 and the sources of funding to meet
those requirements:


    
                                                          Six months ended
                                                               June 30
    ($000)                                                2009        2008
    -------------------------------------------------------------------------
    Sources of funds
      Funds from operations                           $  107,181  $  198,372
      Increase in bank indebtedness                       58,393         520
      Property dispositions                                1,619          91
      Units issued, net of costs                               -         925
    -------------------------------------------------------------------------
                                                      $  167,193  $  199,908
    -------------------------------------------------------------------------
    Uses of funds
      Expenditures on property and equipment          $   68,362  $   88,535
      Increase in working capital                         41,123      23,882
      Convertible debenture repayment                     29,839           -
      Distributions to Unitholders                        23,481      80,632
      Expenditures on asset retirement                     3,622       5,947
      Reduction of capital lease obligations                 645         912
      Trust Unit issue costs                                 121           -
    -------------------------------------------------------------------------
                                                      $  167,193  $  199,908
    -------------------------------------------------------------------------
    

    The Fund generated lower funds from operations during the six months
ended June 30, 2009 compared to the same period of 2008, due to a sharp
decrease in commodity prices. Consequently, our bank indebtedness increased as
a result to assist with the timing of cash flow requirements. The major use of
funds during this period was expenditures on property and equipment, which was
reduced from the 2008 levels, given the lower commodity price environment.
Distributions were suspended indefinitely in the first quarter of 2009 in
order to maintain our budgeted capital program including significant
investment at our Glacier Montney natural gas property and to repay bank
indebtedness. Additionally, our 8.75% convertible debentures matured on June
30, 2009 and were settled with $29.8 million of cash.


    Quarterly Performance

    
                                        2009                    2008
    ($000, except as
     otherwise indicated)           Q2          Q1          Q4          Q3
    -------------------------------------------------------------------------
    Daily production
      Natural gas (mcf/d)        124,990     117,968     120,694     122,627
      Crude oil and NGLs
       (bbls/d)                   10,212      10,942      11,413      11,980
      Total (boe/d)               31,044      30,603      31,529      32,418
    Average prices
      Natural gas ($/mcf)
        Excluding hedging     $     3.56  $     5.36  $     7.15  $     8.65
        Including hedging     $     5.63  $     6.52  $     7.61  $     7.55
        AECO monthly index    $     3.66  $     5.64  $     6.79  $     9.27
      Crude oil and NGLs
       ($/bbl)
        Excluding hedging     $    55.89  $    43.41  $    53.65  $   107.96
        Including hedging     $    54.51  $    54.54  $    61.67  $   100.02
        WTI ($US/bbl)         $    59.62  $    43.21  $    58.75  $   118.13
    Total revenues
     (before royalties)       $  114,659  $  122,950  $  149,205  $  195,384
    Net income (loss)         $  (37,810) $   18,890  $  (95,477) $  113,391
      per Trust Unit
       - basic                $    (0.26) $     0.13  $    (0.67) $     0.81
       - diluted              $    (0.26) $     0.13  $    (0.67) $     0.79
    Funds from operations     $   51,590  $   55,591  $   69,370  $   93,345
    Distributions declared    $        -  $   17,266  $   45,514  $   50,743


                                        2008                    2007
    ($000, except as
     otherwise indicated)           Q2          Q1          Q4          Q3
    -------------------------------------------------------------------------
    Daily production
      Natural gas (mcf/d)        123,104     125,113     128,556     115,991
      Crude oil and NGLs
       (bbls/d)                   11,498      12,281      12,895      10,014
      Total (boe/d)               32,015      33,133      34,321      29,346
    Average prices
      Natural gas ($/mcf)
        Excluding hedging     $    10.33  $     7.90  $     6.23  $     5.62
        Including hedging     $     9.18  $     8.23  $     6.97  $     6.35
        AECO monthly index    $     9.35  $     7.13  $     6.00  $     5.62
      Crude oil and NGLs
       ($/bbl)
        Excluding hedging     $   110.15  $    85.99  $    73.40  $    69.03
        Including hedging     $   101.34  $    84.83  $    70.40  $    68.51
        WTI ($US/bbl)         $   124.00  $    97.96  $    90.63  $    75.33
    Total revenues
     (before royalties)       $  208,868  $  188,505  $  165,951  $  130,830
    Net income (loss)         $  (14,369) $  (24,122) $   13,795  $  (26,202)
      per Trust Unit
       - basic                $    (0.10) $    (0.18) $     0.10  $    (0.22)
       - diluted              $    (0.10) $    (0.18) $     0.10  $    (0.22)
    Funds from operations     $  103,754  $   94,618  $   80,519  $   62,345
    Distributions declared    $   50,364  $   50,021  $   57,875  $   55,017
    

    The table above highlights the Fund's performance for the second quarter
of 2009 and also for the preceding seven quarters. The Sound acquisition
closed on September 5, 2007, and significantly increased production for the
third and fourth quarters of 2007. Production has gradually decreased through
the first half of 2008 due to natural declines, wet and cold weather delays,
and facility turnarounds. Production increased modestly in the third quarter
of 2008 as new wells were brought on production and most facility turnarounds
were completed. During the fourth quarter of 2008 and the first quarter of
2009, production again decreased as we experienced freezing conditions from
early cold weather in December and a slow recovery from such cold weather
conditions. An extended third party facility outage began in August 2008 and
has continued well into 2009 and it is expected that production may come
on-stream near the end of the third quarter 2009. Production increased in the
second quarter of 2009 due to recovery from cold weather conditions that
caused brief production outages and additional production from a number of
wells drilled during the first quarter of 2009 but delayed until after March
31 such that we could benefit from the new 5% Alberta royalty rate available
on such wells for the next twelve month period. Financial results,
particularly revenues and funds from operations, increased through to the
second quarter of 2008, as both commodity prices and production steadily
increased over that timeframe. However, revenues and funds from operations
slightly declined in the third quarter of 2008, as commodity prices began to
decline in response to the financial crisis that materialized in the fall of
2008. This trend worsened in the fourth quarter, as a full global recession
set in, and commodity prices continued on a downward trend through to the
second quarter of 2009. We experienced a net loss in the third quarter of 2007
due to a significant drop in natural gas prices realized at that time,
amortization of the management internalization consideration and increased
depletion and depreciation expense. Net income increased in the fourth quarter
of 2007 due to the full integration of the Sound acquisition and moderately
improved commodity prices. Net losses were realized in the first and second
quarters of 2008, primarily as a result of significant unrealized losses on
commodity derivative contracts for future periods. Commodity price declines in
the third quarter of 2008 gave rise to significant unrealized gains on these
same derivative contracts, and in turn the Fund reported record high net
income. We recognized a considerable net loss in the fourth quarter of 2008, a
combined result of falling commodity prices and an impairment of our entire
balance of goodwill. In the first quarter of 2009, the global economy showed
no clear sign of recovery and commodity prices, particularly natural gas, were
weak in comparison to prior quarters. However, Advantage was still able to
recognize net income as we recognized both realized and unrealized gains on
our derivative contracts and moderately lower expenses, including operating
costs. Natural gas prices continued to worsen during the second quarter of
2009 resulting in the recognition of a net loss.

    Critical Accounting Estimates

    The preparation of financial statements in accordance with GAAP requires
Management to make certain judgments and estimates. Changes in these judgments
and estimates could have a material impact on the Fund's financial results and
financial condition.
    Management relies on the estimate of reserves as prepared by the Fund's
independent qualified reserves evaluator. The process of estimating reserves
is critical to several accounting estimates. The process of estimating
reserves is complex and requires significant judgments and decisions based on
available geological, geophysical, engineering and economic data. These
estimates may change substantially as additional data from ongoing development
and production activities becomes available and as economic conditions impact
crude oil and natural gas prices, operating costs, royalty burden changes, and
future development costs. Reserve estimates impact net income through
depletion and depreciation of fixed assets, the provision for asset retirement
costs and related accretion expense, and impairment calculations for fixed
assets and goodwill. The reserve estimates are also used to assess the
borrowing base for the Fund's credit facilities. Revision or changes in the
reserve estimates can have either a positive or a negative impact on net
income and the borrowing base of the Fund.
    Management's process of determining the provision for future income
taxes, the provision for asset retirement obligation costs and related
accretion expense, and the fair values assigned to any acquired company's
assets and liabilities in a business combination is based on estimates. These
estimates are significant and can include reserves, future production rates,
future crude oil and natural gas prices, future costs, future interest rates,
future tax rates and other relevant assumptions. Revisions or changes in any
of these estimates can have either a positive or a negative impact on asset
and liability values and net income.
    In accordance with GAAP, derivative assets and liabilities are recorded
at their fair values at the reporting date, with unrealized gains and losses
recognized directly into net income and comprehensive income in the same
period. The fair value of derivatives outstanding is an estimate based on
pricing models, estimates, assumptions and market data available at that time.
As such, the recognized amounts are not cash and the actual gains or losses
realized on eventual cash settlement can vary materially due to subsequent
fluctuations in commodity prices as compared to the valuation assumptions.

    International Financial Reporting Standards ("IFRS")

    In February 2008, the Accounting Standards Board of the Canadian
Institute of Chartered Accountants confirmed that publicly accountable
entities will be required to adopt IFRS effective January 1, 2011, including
preparation of comparative financial information. Management has engaged its
key personnel responsible for financial reporting and developed an overall
plan to address IFRS implementation. The initial stage of the plan involved
staff training and ongoing education. Key personnel received professional
education on IFRS accounting principles and standards, both in general and for
the oil and gas industry in particular. Review of changes to IFRS has been
incorporated into existing processes of internal control over financial
reporting. A preliminary project plan for IFRS implementation has been drafted
and will be subject to ongoing revision as there are developments. As well,
appropriate operating personnel have been engaged, as necessary, to determine
how to implement the requirements of IFRS into the Fund's manual and
information systems that collect and process financial data. We expect to have
continual discussion with our external and internal auditors throughout the
process regarding IFRS and implementation.
    The most significant change identified will be accounting for property,
plant and equipment. The Fund, like many Canadian oil and gas reporting
issuers, applies the "full cost" concept in accounting for its oil and gas
assets. Under full cost, capital expenditures are maintained in a single cost
centre for each country, and the cost centre is subject to a single depletion
calculation and impairment test. IFRS will require the Fund to make a much
more detailed assessment of its oil and gas property, plant and equipment. For
depletion and depreciation, the Fund must identify asset components, and
determine an appropriate depreciation or depletion method for each component.
With regard to impairment test calculations, we must identify "Cash Generating
Units", which are defined as the smallest group of assets that produce
independent cash flows. An impairment test must be performed individually for
all cash generating units. The recognition of impairments in a prior year can
be reversed subsequently depending on such calculations. It is also important
to note that the International Accounting Standards Board ("IASB") is
currently undertaking an extractive industries project, to develop accounting
standards specifically for businesses like that of the Fund. However, the
project will not be complete prior to IFRS adoption in Canada. We have also
identified a number of other areas whereby differences between Canadian GAAP
and IFRS are likely to exist for Advantage. However, currently we are
concentrating on the accounting for property, plant and equipment and will
evaluate these other areas in due course and develop more detailed plans to
address the identified issues.

    Disclosure Controls and Internal Controls over Financial Reporting

    Disclosure controls and procedures have been designed to provide
reasonable assurance that information required to be disclosed by the Fund is
recorded, processed, summarized and reported within the time periods specified
under the Canadian securities law. Advantage's Chief Executive Officer and
Chief Financial Officer have concluded, based on their evaluation, that the
disclosure controls and procedures as of the end of June 30, 2009, are
effective and provide reasonable assurance that material information related
to the Fund is made known to them by others within Advantage.
    Advantage's Chief Executive Officer and Chief Financial Officer are
responsible for establishing and maintaining internal controls over financial
reporting ("ICFR"). They have, as at the quarter ended June 30, 2009, designed
ICFR or caused it to be designed under their supervision, to provide
reasonable assurance regarding the reliability of financial reporting and the
preparation of financial statements for external purposes in accordance with
Canadian GAAP. The control framework Advantage's officers used to design the
ICFR is the Internal Control - Integrated Framework issued by the Committee of
Sponsoring Organizations.
    Advantage's Chief Executive Officer and Chief Financial Officer are
required to disclose any change in the internal controls over financial
reporting that occurred during our most recent interim period that has
materially affected, or is reasonably likely to affect, the Fund's internal
controls over financial reporting. No material changes in the internal
controls were identified during the period ended June 30, 2009 that have
materially affected, or are reasonably likely to materially affect, our
internal controls over financial reporting.
    It should be noted that a control system, including Advantage's
disclosure and internal controls and procedures, no matter how well conceived
or operated, can provide only reasonable, not absolute, assurance that the
objectives of the control system will be met and it should be not be expected
that the disclosure and internal controls and procedures will prevent all
errors or fraud.

    Outlook

    On March 18, 2009, we announced the intention to dispose of light oil and
natural gas producing properties located in Northeast British Columbia, West
Central Alberta and Northern Alberta. Proposals were received and evaluated by
Advantage with two purchase and sale agreements signed for gross proceeds of
$252.6 million, subject to customary adjustments, and representing production
of approximately 8,100 boe/d. Both of these sales closed successfully in July
2009 with the net proceeds used to reduce outstanding bank debt. We expect
production to average approximately 23,000 boe/d for the period July to
December 2009 from a more focused asset base.
    Additionally, we also announced that we entered into an agreement with a
syndicate of underwriters for the purchase of 17 million trust units by the
underwriters on a bought deal basis, at a price of $6.00 per Trust Unit for
total gross proceeds of $102 million, which closed on July 7, 2009. The net
proceeds of this offering were also used to repay indebtedness under
Advantage's credit facility.
    These transactions have enabled Advantage to repay a significant portion
of outstanding bank indebtedness while increasing the balance of unutilized
credit facility. This improves our financial flexibility as we convert to a
growth oriented corporation to pursue the significant potential of our Montney
natural gas resource play. Our credit facility may be subsequently redrawn to
fund capital expenditures and for general corporate purposes but it is our
long-term intention to balance funds from operations and our capital
expenditure program. Although our funds from operations will continue to be
impacted by the volatility of crude oil and natural gas prices, we have a
substantial hedging portfolio that improves cash flow stability for our
capital program. Approximately 79% of our natural gas production, net of
royalties, is now hedged for the remainder of 2009 at an average fixed price
of $8.17/mcf. We have also hedged approximately 54% of our remaining 2009
crude oil production, net of royalties, at an average floor price of
$62.40/bbl. For 2010, we have hedged 58% of our natural gas production, net of
royalties, at an average fixed price of $7.46/mcf and 31% of our crude oil
production, net of royalties, at an average fixed price of $67.83/bbl. Our
strategy will be to continue to employ a multi-year hedging program to reduce
the volatility in cash flow in support of capital requirements.
    In conjunction with our corporate conversion, we announced on July 8,
2009 that the Board of Directors had approved a new capital budget for the
twelve month period beginning July 2009 and ending June 2010. Management will
review the capital program on a regular basis in the context of prevailing
economic conditions and make adjustments as deemed necessary to the program,
subject to review by the Board of Directors.
    Advantage's corporate capital budget for the 12 month period ending June
2010 has been set at $207 million, with approximately $105 to $110 million for
the remainder of 2009. Guidance for the 12 month period is as follows:


    
                         July to December   January to June        Total
                               2009              2010           12 Months
                               ----              ----           ---------
    Production (boe/d)   22,700 to 23,300  24,200 to 25,200  23,450 to 24,300
    Royalty rate (%)        15% to 18%        16% to 19%        15% to 19%
    Operating costs
     ($/boe)             $12.75 to $13.30  $12.50 to $13.20  $12.60 to $13.25
    Capital expenditures
     ($ millions)          $105 to $110      $100 to $105      $205 to $215
    Funds from operations
     ($ millions)                                                 $204(1)

    (1) Based on NYMEX US$5.19/mmbtu, AECO $4.97/mcf, WTI US$73.87/bbl,
        $US/$Canadian exchange rate $0.86 and current hedging positions.
    

    Funds from operations are forecasted to be approximately within the range
of capital expenditures required for the next 12 month period. The volatility
in funds from operations is significantly reduced due to our hedging positions
through to the end of 2010. Production is forecasted to increase during the
first half of 2010 as new wells are brought on stream after additional
gathering systems and new facilities are constructed at Glacier during the
fourth quarter of 2009. Production declines will occur at Glacier during the
second half of 2009 and at our remaining properties. We also expect natural
gas production curtailments to occur during the second half of 2009 as several
joint operators have announced their intention to shut-in production due to
the low price of natural gas. The budget will focus on development of our
Montney natural gas resource play at Glacier, Alberta where Advantage will
continue to employ a phased development approach. Phase II of the development
plan will be undertaken during the next 12 months and will result in
production capacity increasing to 50 mmcf/d by mid 2010. A continued focus on
optimizing well completions at Glacier will involve production logging of
several wells in order to further evaluate the effectiveness of frac designs
and new technology applications. Phase II of the Glacier development plan
includes the drilling and completion of 16 gross (16.0 net) horizontal
operated wells, up to 16 gross (6.1 net) joint interest horizontal wells, and
1 gross (1.0 net) vertical well during the next twelve months. Drilling plans
will continue to balance production and reserve growth and delineation of our
extensive 89 section gross (average 90% working interest) Montney land block.
Drilling resumed in early July at Glacier with the deployment of four drilling
rigs on operated and joint interest lands. Phase II also includes the
expansion of the existing gas gathering system, additional compression and a
new Advantage operated gas plant to complement the existing infrastructure and
provide total processing and production capacity of 50 mmcf/d. The majority of
the wells drilled during the last half of 2009 will be tied-in during the
second quarter of 2010 when the facilities expansions are expected to be
completed. Glacier capital expenditures are estimated to be approximately $84
million net for the remainder of 2009 and $81 million net for the first half
of 2010. Approximately $116 million will be allocated to drilling and
completions with $29 million for well equipping and tie-ins and $20 million
for facilities and plant expansion. Phase III of the development plan will
result in the attainment of 100 mmcf/d by mid 2011.
    The Alberta Government's recently announced extension of the energy
incentive programs to March 31, 2011 will provide substantial benefits to all
three phases of our Glacier development plan. The energy incentive programs
will allow Advantage to capitalize on lower drilling costs (through a drilling
royalty credit of up to $200 per meter of drilled depth subject to a corporate
ceiling) and an initial 5% royalty rate on the first 500 mmcf of production
for new wells based on our go-forward drilling plans for each of the three
phases of development at Glacier.
    With regards to field operating costs, we will continue with our
optimization programs which has already delivered cost reductions. We expect
to see some further easing of operating costs as the lower commodity price
environment is expected to remain for a sustained period.
    Looking forward, Advantage's high quality assets combined with a
significant unconventional and conventional inventory, strong hedging program
and improved balance sheet enables us to create value growth for our
Unitholders.

    Additional Information

    Additional information relating to Advantage can be found on SEDAR at
www.sedar.com and the Fund's website at www.advantageog.com. Such other
information includes the annual information form, the annual information
circular - proxy statement, press releases, material contracts and agreements,
and other financial reports. The annual information form will be of particular
interest for current and potential Unitholders as it discusses a variety of
subject matter including the nature of the business, structure of the Fund,
description of our operations, general and recent business developments, risk
factors, reserves data and other oil and gas information.

    
    August 13, 2009



                      CONSOLIDATED FINANCIAL STATEMENTS

    Consolidated Balance Sheets
                                                          June      December
    (thousands of dollars)                              30, 2009    31, 2008
    -------------------------------------------------------------------------
                                                      (unaudited)
    Assets
    Current assets
      Accounts receivable                             $   56,524  $   84,689
      Prepaid expenses and deposits                       12,879      11,571
      Derivative asset (note 10)                          60,156      41,472
    -------------------------------------------------------------------------
                                                         129,559     137,732

    Derivative asset (note 10)                             6,008       1,148
    Fixed assets (note 3)                              2,103,233   2,163,866
    -------------------------------------------------------------------------
                                                      $2,238,800  $2,302,746
    -------------------------------------------------------------------------
    Liabilities
    Current liabilities
      Accounts payable and accrued liabilities        $   78,066  $  146,046
      Distributions payable to Unitholders                     -      11,426
      Current portion of capital lease
       obligations (note 4)                                2,038       1,747
      Current portion of convertible debentures
       (note 5)                                          121,212      86,125
      Derivative liability (note 10)                      17,376         611
      Future income taxes                                 12,377      11,939
    -------------------------------------------------------------------------
                                                         231,069     257,894
    Derivative liability (note 10)                         7,996       1,039
    Capital lease obligations (note 4)                     2,970       3,906
    Bank indebtedness (note 6)                           643,110     584,717
    Convertible debentures (note 5)                       60,419     128,849
    Asset retirement obligations (note 7)                 84,953      73,852
    Future income taxes                                   22,586      43,976
    -------------------------------------------------------------------------
                                                       1,053,103   1,094,233
    -------------------------------------------------------------------------

    Unitholders' Equity Unitholders' capital
     (note 8)                                          2,088,497   2,075,877
    Convertible debentures equity component
     (note 5)                                              8,303       9,403
    Contributed surplus (note 8)                           2,137         287
    Accumulated deficit (note 9)                        (913,240)   (877,054)
    -------------------------------------------------------------------------
                                                       1,185,697   1,208,513
    -------------------------------------------------------------------------
                                                      $2,238,800  $2,302,746
    -------------------------------------------------------------------------
    Commitments (note 12)
    Subsequent events (note 13)

    See accompanying Notes to Consolidated Financial Statements



    Consolidated Statements of Loss,
    Comprehensive Loss and Accumulated Deficit

    (thousands of dollars,       Three months ended       Six months ended
     except for per Trust        June 30,    June 30,    June 30,    June 30,
     Unit amounts) (unaudited)     2009        2008        2009        2008
    -------------------------------------------------------------------------
    Revenue
      Petroleum and natural
       gas                    $   92,421  $  230,953  $  192,025  $  417,051
      Realized gain (loss) on
       derivatives (note 10)      22,238     (22,085)     45,584     (19,678)
      Unrealized loss on
       derivatives (note 10)     (24,575)    (62,696)       (178)   (123,882)
      Royalties                  (12,791)    (46,173)    (28,871)    (80,054)
    -------------------------------------------------------------------------
                                  77,293      99,999     208,560     193,437
    -------------------------------------------------------------------------

    Expenses
      Operating                   35,030      39,917      71,061      80,189
      General and administrative   7,848       5,763      15,228      12,995
      Management internalization
       (note 8)                      760       2,439       1,724       4,930
      Interest                     3,439       7,118       8,355      14,884
      Interest and accretion on
       convertible debentures      4,690       4,924       9,341       9,831
      Depletion, depreciation
       and accretion              72,177      74,704     142,099     151,584
    -------------------------------------------------------------------------
                                 123,944     134,865     247,808     274,413
    -------------------------------------------------------------------------

    Loss before taxes            (46,651)    (34,866)    (39,248)    (80,976)
    Future income tax reduction   (9,185)    (21,368)    (20,952)    (44,044)
    Income and capital taxes         344         871         624       1,559
    -------------------------------------------------------------------------
                                  (8,841)    (20,497)    (20,328)    (42,485)
    -------------------------------------------------------------------------

    Net loss and comprehensive
     loss                        (37,810)    (14,369)    (18,920)    (38,491)
    Accumulated deficit,
     beginning of period        (875,430)   (733,978)   (877,054)   (659,835)
    Distributions declared             -     (50,364)    (17,266)   (100,385)
    -------------------------------------------------------------------------
    Accumulated deficit,
     end of period             $(913,240)  $(798,711)  $(913,240)  $(798,711)
    -------------------------------------------------------------------------
    Net loss per
     Trust Unit (note 8)
      Basic and diluted        $   (0.26)  $   (0.10)  $   (0.13)  $   (0.28)
    -------------------------------------------------------------------------
    See accompanying Notes to Consolidated Financial Statements



    Consolidated Statements of Cash Flows

                                 Three months ended       Six months ended
    (thousands of dollars)       June 30,    June 30,    June 30,    June 30,
    (unaudited)                    2009        2008        2009        2008
    -------------------------------------------------------------------------
    Operating Activities
    Net loss                  $  (37,810) $  (14,369) $  (18,920) $  (38,491)
    Add (deduct) items not
     requiring cash:
      Unrealized loss on
       derivatives                24,575      62,696         178     123,882
      Unit-based compensation        392      (1,068)      1,689        (929)
      Management internalization     760       2,439       1,724       4,930
      Accretion on convertible
       debentures                    681         720       1,363       1,440
      Depletion, depreciation
       and accretion              72,177      74,704     142,099     151,584
      Future income tax
       reduction                  (9,185)    (21,368)    (20,952)    (44,044)
    Expenditures on asset
     retirement                   (1,045)       (982)     (3,622)     (5,947)
    Changes in non-cash
     working capital             (11,589)     (8,890)    (22,724)    (16,950)
    -------------------------------------------------------------------------
    Cash provided by
     operating activities         38,956      93,882      80,835     175,475
    -------------------------------------------------------------------------

    Financing Activities
    Units issued, net of costs      (121)        967        (121)        925
    Increase (decrease) in
     bank indebtedness            31,102     (15,554)     58,393         520
    Convertible debenture
     repayment (note 5)          (29,839)          -     (29,839)          -
    Reduction of capital
     lease obligations              (325)       (306)       (645)       (912)
    Distributions to Unitholders       -     (40,330)    (23,481)    (80,632)
    -------------------------------------------------------------------------
    Cash provided by (used in)
     financing activities            817     (55,223)      4,307     (80,099)
    -------------------------------------------------------------------------
    Investing Activities
    Expenditures on property
     and equipment               (15,719)    (21,632)    (68,362)    (88,535)
    Property dispositions            860           -       1,619          91
    Changes in non-cash
     working capital             (24,914)    (17,027)    (18,399)     (6,932)
    -------------------------------------------------------------------------
    Cash used in investing
     activities                  (39,773)    (38,659)    (85,142)    (95,376)
    -------------------------------------------------------------------------
    Net change in cash                 -           -           -           -
    Cash, beginning of period          -           -           -           -
    -------------------------------------------------------------------------
    Cash, end of period       $        -  $        -  $        -  $        -
    -------------------------------------------------------------------------
    Supplementary Cash Flow
     Information
      Interest paid                6,793      10,013      15,040      18,579
      Taxes paid                     235         638         610         792

    See accompanying Notes to Consolidated Financial Statements



                 NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

    June 30, 2009 (unaudited)

    All tabular amounts in thousands except as otherwise indicated.

    The interim consolidated financial statements of Advantage Energy Income
    Fund ("Advantage" or the "Fund") have been prepared by management in
    accordance with Canadian generally accepted accounting principles
    ("GAAP") using the same accounting policies as those set out in note 2 to
    the consolidated financial statements for the year ended December 31,
    2008, except as described below. These interim financial statement note
    disclosures do not include all of those required by Canadian GAAP
    applicable for annual financial statements. The interim consolidated
    financial statements should be read in conjunction with the audited
    consolidated financial statements of Advantage for the year ended
    December 31, 2008 as set out in Advantage's Annual Report.

    1.  Business and Structure of the Fund

        Advantage was formed on May 23, 2001 as a result of a plan of
        arrangement. For Canadian tax purposes, Advantage is an open-ended
        unincorporated mutual fund trust created under the laws of the
        Province of Alberta pursuant to a Trust Indenture originally dated
        April 17, 2001, and as occasionally amended, between Advantage Oil &
        Gas Ltd. ("AOG") and Computershare Trust Company of Canada, as
        trustee. The Fund commenced operations on May 24, 2001. The
        beneficiaries of the Fund are the holders of the Trust Units (the
        "Unitholders").

        The principal undertaking of the Fund is to indirectly acquire and
        hold interests in petroleum and natural gas properties and assets
        related thereto. The business of the Fund is carried on by its
        wholly-owned subsidiary, AOG. The Fund's primary assets are currently
        the common shares of AOG, a royalty in the producing properties of
        AOG (the "AOG Royalty") and notes of AOG (the "AOG Notes"). The
        Fund's strategy, through AOG, is to minimize exposure to exploration
        risk while focusing on growth through acquisitions and development of
        producing crude oil and natural gas properties.

        The original purpose of the Fund was to distribute available cash
        flow to Unitholders on a monthly basis in accordance with the terms
        of the Trust Indenture. The Fund's available cash flow include
        principal repayments and interest income earned from the AOG Notes,
        royalty income earned from the AOG Royalty, and any dividends
        declared on the common shares of AOG less any expenses of the Fund
        including interest on convertible debentures. Cash received on the
        AOG Notes, AOG Royalty and common shares of AOG result in the
        effective transfer of the economic interest in the properties of AOG
        to the Fund. However, while the royalty is a contractual interest in
        the properties owned by AOG, it does not confer ownership in the
        underlying resource properties. Any distributions from the Fund to
        Unitholders were entirely discretionary and determined by Management
        and the Board of Directors. Management closely monitored the
        distribution policy considering forecasted cash flows, optimal debt
        levels, capital spending activity, taxability to Unitholders, working
        capital requirements, and other potential cash expenditures.
        Distributions were based on the cash available after retaining a
        portion to meet such spending requirements. The level of
        distributions were primarily determined by cash flows received from
        the production of oil and natural gas from existing Canadian resource
        properties and were dependent upon our success in exploiting the
        current reserve base and acquiring additional reserves. Furthermore,
        monthly distributions that were paid to Unitholders were dependent
        upon the prices received for such oil and natural gas production.

        On March 18, 2009, Advantage announced the Board of Directors had
        approved conversion to a growth oriented corporation and suspension
        of the monthly distribution.  The corporate conversion was approved
        by the Fund's Unitholders at the Annual General and Special Meeting
        on July 9, 2009, and received customary court and regulatory
        approvals. The conversion will enable the new corporation, Advantage
        Oil & Gas Ltd., to pursue a business plan that is focused on the
        development and growth of the Montney natural gas resource play at
        Glacier, Alberta. Going forward, Advantage does not anticipate paying
        dividends in the immediate future and will instead direct cash flow
        to capital expenditures and debt repayment.

    2.  Changes in Accounting Policies

        (a) Goodwill and intangible assets

        In February 2008, the Canadian Institute of Chartered Accountants
        ("CICA") issued Section 3064, Goodwill and Intangible Assets,
        replacing Section 3062, Goodwill and Other Intangible Assets and
        Section 3450, Research and Development Costs.  The new Section became
        effective January 1, 2009.  Management has implemented the new
        Section and there was no impact for the financial statements of the
        Fund.

        (b) Recent accounting pronouncements issued but not implemented

            (i)  International Financial Reporting Standards ("IFRS")

             In February 2008, the CICA Accounting Standards Board confirmed
             that IFRS will replace Canadian GAAP effective January 1, 2011
             for publicly accountable enterprises.  Management is currently
             evaluating the effects of all current and pending pronouncements
             of the International Accounting Standards Board on the financial
             statements of the Fund, and has developed a plan for
             implementation.

        (c)  Comparative figures

        Certain comparative figures have been reclassified to conform to the
        current period presentation.

    3.  Fixed Assets

                                                   Accumulated
                                                 Depletion and     Net Book
        June 30, 2009                    Cost     Depreciation       Value
        ---------------------------------------------------------------------
        Petroleum and natural gas
         properties                  $ 3,378,370   $ 1,279,452   $ 2,098,918
        Furniture and equipment           11,710         7,395         4,315
        ---------------------------------------------------------------------
                                     $ 3,390,080   $ 1,286,847   $ 2,103,233
        ---------------------------------------------------------------------

                                                   Accumulated
                                                 Depletion and     Net Book
        December 31, 2008                Cost     Depreciation       Value
        ---------------------------------------------------------------------
        Value Petroleum and natural
         gas properties              $ 3,299,657   $ 1,140,710   $ 2,158,947
        Furniture and equipment           11,572         6,653         4,919
        ---------------------------------------------------------------------
                                     $ 3,311,229   $ 1,147,363   $ 2,163,866
        ---------------------------------------------------------------------

    4.  Capital Lease Obligations

        The Fund has capital leases on a variety of fixed assets. Future
        minimum lease payments at June 30, 2009 consist of the following:

        2009                                   1,239
        2010                                   2,200
        2011                                   1,925
        ---------------------------------------------
                                               5,364
        Less amounts representing interest      (356)
        ---------------------------------------------
                                               5,008
        Current portion                       (2,038)
        ---------------------------------------------
                                           $   2,970
        ---------------------------------------------

    5.  Convertible Debentures

        The balance of debentures outstanding at June 30, 2009 and changes in
        the liability and equity components during the six months ended June
        30, 2009 are as follows:

                                   8.25%       8.75%       7.50%
        ---------------------------------------------------------
        Trading symbol           AAV.DBB     AAV.DBF     AAV.DBC
        Debentures outstanding $       -   $       -   $  52,268
        ---------------------------------------------------------
        Liability component:
          Balance at December
           31, 2008            $   4,859   $  29,687  $   51,579
          Accretion of discount        8         152         457
          Matured                 (4,867)    (29,839)          -
        ---------------------------------------------------------
          Balance at
           June 30, 2009       $       -   $       -  $   52,036
        ---------------------------------------------------------
        Equity component:
          Balance at December
           31, 2008            $      248  $      852  $    2,248
          Expired                    (248)       (852)          -
        -------------------------------------------------------------
          Balance at
           June 30, 2009       $        -  $        -  $    2,248
        -------------------------------------------------------------

                                    6.50%       7.75%       8.00%      Total
        ---------------------------------------------------------------------
        Trading symbol            AAV.DBE     AAV.DBD     AAV.DBG
        Debentures outstanding $   69,927  $   46,766  $   15,528  $ 184,489
        ---------------------------------------------------------------------
        Liability component:
          Balance at
           December 31, 2008   $   68,807  $   44,964  $   15,078  $ 214,974
          Accretion of discount       369         303          74      1,363
          Matured                       -           -           -    (34,706)
        ---------------------------------------------------------------------
          Balance at June 30,
          2009                 $   69,176  $   45,267  $   15,152  $ 181,631
        ---------------------------------------------------------------------
        Equity component:
          Balance at
           December 31, 2008   $    2,971  $    2,286  $      798  $   9,403
          Expired                       -           -           -     (1,100)
        ---------------------------------------------------------------------
          Balance at
           June 30, 2009       $    2,971  $    2,286  $      798  $   8,303
        ---------------------------------------------------------------------

        During the six months ended June 30, 2009, there were no convertible
        debenture conversions (June 30, 2008 - $25,000 converted resulting in
        the issuance of 1,001 Trust Units).

        The principal amount of 8.25% convertible debentures matured on
        February 1, 2009 and was settled by issuing 946,887 Trust Units,
        while the 8.75% convertible debentures that matured on June 30, 2009
        were settled with $29.8 million in cash.

    6.  Bank Indebtedness

                                                          June      December
                                                        30, 2009    31, 2008
        ---------------------------------------------------------------------
        Revolving credit facility                     $  644,100  $  587,404
        Discount on Bankers Acceptances                     (990)     (2,687)
        ---------------------------------------------------------------------
        Balance, end of period                        $  643,110  $  584,717
        ---------------------------------------------------------------------

        Advantage has a credit facility agreement with a syndicate of
        financial institutions which provides for a $630 million extendible
        revolving loan facility, a $20 million operating loan facility, and a
        $60 million liquidity facility. The liquidity facility will, subject
        to renewal, expire on October 31, 2010. The loan's interest rate is
        based on either prime, US base rate, LIBOR or bankers' acceptance
        rates, at the Fund's option, subject to certain basis point or
        stamping fee adjustments ranging from 1.50% to 5.50% depending on the
        Fund's debt to cash flow ratio. The credit facilities are
        collateralized by a $1 billion floating charge demand debenture, a
        general security agreement and a subordination agreement from the
        Fund covering all assets and cash flows. The amounts available to
        Advantage from time to time under the credit facilities are based
        upon the borrowing base determined by the lenders and which is re-
        determined on a semi-annual basis by those lenders. The credit
        facilities are subject to review on an annual basis with the next
        renewal due in June 2010. Various borrowing options are available
        under the credit facilities, including prime rate-based advances, US
        base rate advances, US dollar LIBOR advances and bankers' acceptances
        loans. The credit facilities constitute a revolving facility for a
        364 day term which is extendible annually for a further 364 day
        revolving period at the option of the syndicate. If not extended, the
        revolving credit facility is converted to a one year term facility
        with the principal payable at the end of such one year term. The
        credit facilities contain standard commercial covenants for
        facilities of this nature. The only financial covenant is a
        requirement for AOG to maintain a minimum cash flow to interest
        expense ratio of 3.5:1, determined on a rolling four quarter basis.
        The credit facilities also prohibit the Fund from entering into any
        derivative contract where the term of such contract exceeds two years
        and the aggregate of such contracts hedge greater than 60% of total
        estimated oil and gas production, except for the initial period ended
        December 31, 2009 whereby the Fund shall not hedge greater than 80%
        of total estimated oil and gas production.  Breach of any covenant
        will result in an event of default in which case AOG has 20 days to
        remedy such default. If the default is not remedied or waived, and if
        required by the lenders, the administrative agent of the lenders has
        the option to declare all obligations of AOG under the credit
        facilities to be immediately due and payable without further demand,
        presentation, protest, days of grace, or notice of any kind.
        Distributions by AOG to the Fund (and effectively by the Fund to
        Unitholders) are subordinated to the repayment of any amounts owing
        under the credit facilities. Distributions to Unitholders are not
        permitted if the Fund is in default of such credit facilities or if
        the amount of the Fund's outstanding indebtedness under such
        facilities exceeds the then existing current borrowing base. Interest
        payments under the debentures are also subordinated to indebtedness
        under the credit facilities and payments under the debentures are
        similarly restricted. For the six months ended June 30, 2009, the
        average effective interest rate on the outstanding amounts under the
        facility was approximately 2.8% (June 30, 2008 - 5.4%). As a result
        of the asset dispositions completed in July 2009, the borrowing base
        was subsequently re-determinded and established at $525 million
        (note 13).

    7.  Asset Retirement Obligations

        A reconciliation of the asset retirement obligations is provided
        below:

                                                    Six months
                                                      ended      Year ended
                                                     June 30,   December 31,
                                                       2009         2008
        ---------------------------------------------------------------------
        Balance, beginning of period               $    73,852   $    60,835
        Accretion expense                                2,615         4,186
        Liabilities incurred                               379         1,526
        Change in estimates                             11,729        16,564
        Liabilities settled                             (3,622)       (9,259)
        ---------------------------------------------------------------------
        Balance, end of period                     $    84,953   $    73,852
        ---------------------------------------------------------------------

    8.  Unitholders' Equity

        (a) Unitholders' capital

            (i)  Authorized

                 Unlimited number of voting Trust Units

            (ii) Issued

                                               Number of Units        Amount
        ---------------------------------------------------------------------
        Balance at December 31, 2008               142,824,854   $ 2,077,760
        Distribution reinvestment plan               1,263,158         5,211
        Issued on maturity of debentures               946,887         4,867
        Issued pursuant to Restricted
         Trust Unit Plan                               171,093           939
        Management internalization forfeitures          (7,862)         (159)
        Issuance costs                                       -          (121)
        ---------------------------------------------------------------------
        Balance at June 30, 2009                   145,198,130   $ 2,088,497
        ---------------------------------------------------------------------

        On June 23, 2006, Advantage internalized the external management
        contract structure and eliminated all related fees for total original
        consideration of 1,933,208 Advantage Trust Units initially valued at
        $39.1 million and subject to escrow provisions over a 3-year period,
        vesting one-third each year beginning June 23, 2007.  For the six
        months ended June 30, 2009, a total of 7,862 Trust Units issued for
        the management internalization were forfeited (June 30, 2008 - 4,193
        Trust Units) and $1.7 million has been recognized as management
        internalization expense (June 30, 2008 - $4.9 million). As at June
        30, 2009, all Trust Units in respect of management internalization
        were issued and none remain held in escrow (December 31, 2008 -
        564,612 Trust Units remained in escrow).

        During the six months ended June 30, 2009, 1,263,158 Trust Units
        (June 30, 2008 - 1,854,776 Trust Units) were issued under the Premium
        Distribution(TM), Distribution Reinvestment and Optional Trust Unit
        Purchase Plan, generating $5.2 million (June 30, 2008 - $19.5
        million) reinvested in the Fund.

        The principal amount of 8.25% convertible debentures matured on
        February 1, 2009 and was settled by issuing 946,887 Trust Units.

        (b) Contributed surplus

                                                    Six months
                                                      ended      Year ended
                                                     June 30,   December 31,
                                                       2009         2008
        ---------------------------------------------------------------------
        Balance, beginning of period               $       287   $     2,005
        Unit-based compensation                            750        (1,256)
        Expiration of convertible debentures
         equity component                                1,100           229
        Exercise of Trust Unit Rights                        -          (691)
        ---------------------------------------------------------------------
        Balance, end of period                     $     2,137   $       287
        ---------------------------------------------------------------------

    (c) Unit-based compensation

        Advantage's current employee compensation includes a Restricted Trust
        Unit Plan, as approved by the Unitholders on June 23, 2006. The
        purpose of the long-term compensation plan is to retain and attract
        employees, to reward and encourage performance, and to focus
        employees on operating and financial performance that results in
        lasting Unitholder return.

        Although Advantage experienced a negative return for the 2008 year,
        the approved peer group also experienced likewise negative returns.
        As a result, Advantage's 2008 annual return was within the top two-
        thirds of the approved peer group and the Board of Directors granted
        Restricted Trust Units ("RTUs") at their discretion.  The RTUs were
        deemed to be granted at January 15, 2009 and was valued at $3.8
        million to be issued in Trust Units at $5.49 per Trust Unit. Unit-
        based compensation expense of $1.7 million has been included in
        general and administration expense for the six month period ended
        June 30, 2009 and 171,093 Trust Units were issued to employees in
        January 2009 for the first one-third of the grant that vested.  The
        remaining two-thirds of the RTUs granted will vest over the
        subsequent two yearly anniversary dates with corresponding
        compensation expense recognized over the service period. Since
        implementing the Plan in 2006, the grant thresholds have not been
        previously met, and there have been no RTU grants made during prior
        years and no related compensation expense has been recognized.

    (d) Net loss per Trust Unit

        The calculations of basic and diluted net loss per Trust Unit are
        derived from both loss available to Unitholders and weighted average
        Trust Units outstanding, calculated as follows:


                            Three months ended            Six months ended
                           June 30,      June 30,      June 30,      June 30,
                             2009          2008          2009          2008
        ---------------------------------------------------------------------
        Loss available
         to Unitholders
          Basic and
           diluted         (37,810)      (14,369)      (18,920)      (38,491)
        ---------------------------------------------------------------------
        Weighted average
         Trust Units
         outstanding
          Basic and
           diluted     144,681,321   138,611,924   144,189,031   138,105,497
        ---------------------------------------------------------------------

        The calculation of diluted net loss per Trust Unit excludes all
        series of convertible debentures for both the three and six months
        ended June 30, 2009 and 2008 as the impact on these periods would be
        anti-dilutive.  Total weighted average Trust Units issuable in
        exchange for the convertible debentures and excluded from the diluted
        net loss per Trust Unit calculation for the three and six months
        ended June 30, 2009 were 9,224,648 and 9,279,871 Trust Units,
        respectively.  Total weighted average Trust Units issuable in
        exchange for the convertible debentures and excluded from the diluted
        net loss per Trust Unit calculation for the three and six months
        ended June 30, 2008 were 9,846,252 and 9,846,610 Trust Units,
        respectively.  As at June 30, 2009, the total convertible debentures
        outstanding were immediately convertible to 8,373,448 Trust Units
        (June 30, 2008 - 9,846,252 Trust Units).

        Escrowed RTUs granted in January 2009 have been excluded from the
        calculation of diluted net loss per Trust Unit for the three and six
        months ended June 30, 2009, as the impact would have been anti-
        dilutive. Total weighted average Trust Units issuable in exchange for
        the RTUs and excluded from the diluted net loss per Trust Unit
        calculation for the three and six months ended June 30, 2009 were
        89,475 and 52,645, respectively.

        Management Internalization escrowed Trust Units have been excluded
        from the calculation of diluted net loss per Trust Unit for the three
        and six months ended June 30, 2009 and 2008, as the impact would have
        been anti-dilutive. Total weighted average Trust Units issuable in
        exchange for the Management Internalization escrowed Trust Units and
        excluded from the diluted net loss per Trust Unit calculation for the
        three and six months ended June 30, 2009 were 401,473 and 312,719,
        respectively. Total weighted average Trust Units issuable in exchange
        for the Management Internalization escrowed Trust Units and excluded
        from the diluted net loss per Trust Unit calculation for the three
        and six months ended June 30, 2008 were 528,068 and 484,869,
        respectively.

    9.  Accumulated Deficit

        Accumulated deficit consists of accumulated income and accumulated
        distributions for the Fund since inception as follows:

                                                      June 30,   December 31,
                                                        2009         2008
        ---------------------------------------------------------------------
        Accumulated Income                         $   180,491   $   199,411
        Accumulated Distributions                   (1,093,731)   (1,076,465)
        ---------------------------------------------------------------------
        Accumulated Deficit                        $  (913,240)  $  (877,054)
        ---------------------------------------------------------------------

        For the six months ended June 30, 2009, the Fund declared $17.3
        million in distributions, representing $0.12 per distributable Trust
        Unit (June 30, 2008 - $100.4 million in distributions representing
        $0.72 per Trust Unit).

    10. Financial Instruments

        Financial instruments of the Fund include accounts receivable,
        deposits, accounts payable and accrued liabilities, distributions
        payable to Unitholders, bank indebtedness, convertible debentures and
        derivative assets and liabilities.

        Accounts receivable and deposits are classified as loans and
        receivables and measured at amortized cost. Accounts payable and
        accrued liabilities, distributions payable to Unitholders and bank
        indebtedness are all classified as other liabilities and similarly
        measured at amortized cost.  As at June 30, 2009, there were no
        significant differences between the carrying amounts reported on the
        balance sheet and the estimated fair values of these financial
        instruments due to the short terms to maturity and the floating
        interest rate on the bank indebtedness.

        The Fund has convertible debenture obligations outstanding, of which
        the liability component has been classified as other liabilities and
        measured at amortized cost. The convertible debentures have different
        fixed terms and interest rates (note 5) resulting in fair values that
        will vary over time as market conditions change. As at June 30, 2009,
        the estimated fair value of the total outstanding convertible
        debenture obligation was $178.0 million (December 31, 2008 - $191.2
        million). The fair value of convertible debentures was determined
        based on the public trading activity of such debentures.

        Advantage has an established strategy to manage the risk associated
        with changes in commodity prices by entering into derivatives, which
        are recorded at fair value as derivative assets and liabilities with
        gains and losses recognized through earnings. As the fair value of
        the contracts varies with commodity prices, they give rise to
        financial assets and liabilities. The fair values of the derivatives
        are determined through valuation models completed internally and by
        third parties. Various assumptions based on current market
        information were used in these valuations, including settled forward
        commodity prices, interest rates, foreign exchange rates, volatility
        and other relevant factors. The actual gains and losses realized on
        eventual cash settlement can vary materially due to subsequent
        fluctuations in commodity prices as compared to the valuation
        assumptions.

        Credit Risk

        Accounts receivable, deposits, and derivative assets are subject to
        credit risk exposure and the carrying values reflect Management's
        assessment of the associated maximum exposure to such credit risk.
        Advantage mitigates such credit risk by closely monitoring
        significant counterparties and dealing with a broad selection of
        partners that diversify risk within the sector. The Fund's deposits
        are primarily due from the Alberta Provincial government and are
        viewed by Management as having minimal associated credit risk. To the
        extent that Advantage enters derivatives to manage commodity price
        risk, it may be subject to credit risk associated with counterparties
        with which it contracts. Credit risk is mitigated by entering into
        contracts with only stable, creditworthy parties and through frequent
        reviews of exposures to individual entities. In addition, the Fund
        only enters into derivative contracts with major national banks and
        international energy firms to further mitigate associated credit
        risk.

        Substantially all of the Fund's accounts receivable are due from
        customers and joint operation partners concentrated in the Canadian
        oil and gas industry. As such, accounts receivable are subject to
        normal industry credit risks.  As at June 30, 2009, $9.9 million or
        18% of accounts receivable are outstanding for 90 days or more
        (December 31, 2008 - $14.2 million or 17% of accounts receivable).
        The Fund believes that the entire balance is collectible, and in some
        instances we have the ability to mitigate risk through withholding
        production or offsetting payables with the same parties. Accordingly,
        management has not provided for an allowance for doubtful accounts at
        June 30, 2009.

        Liquidity Risk

        The Fund is subject to liquidity risk attributed from accounts
        payable and accrued liabilities, distributions payable to
        Unitholders, bank indebtedness, convertible debentures, and
        derivative liabilities. Accounts payable and accrued liabilities,
        distributions payable to Unitholders and derivative liabilities are
        primarily due within one year of the balance sheet date and Advantage
        does not anticipate any problems in satisfying the obligations
        from cash provided by operating activities and the existing credit
        facility. The Fund's bank indebtedness is subject to
        a $710 million credit facility agreement.  Although the credit
        facility is a source of liquidity risk, the facility also mitigates
        liquidity risk by enabling Advantage to manage interim cash flow
        fluctuations. The credit facility constitutes a revolving facility
        for a 364 day term which is extendible annually for a further 364 day
        revolving period at the option of the syndicate. If not extended, the
        revolving credit facility is converted to a one year term facility
        with the principal payable at the end of such one year term. The
        terms of the credit facility are such that it provides Advantage
        adequate flexibility to evaluate and assess liquidity issues if and
        when they arise. Additionally, the Fund regularly monitors liquidity
        related to obligations by evaluating forecasted cash flows, optimal
        debt levels, capital spending activity, working capital requirements,
        and other potential cash expenditures. This continual financial
        assessment process further enables the Fund to mitigate liquidity
        risk.

        Advantage has several series of convertible debentures outstanding
        that mature from 2009 to 2011 (note 5). Interest payments are made
        semi-annually with excess cash provided by operating activities. As
        the debentures become due, the Fund can satisfy the obligations in
        cash or issue Trust Units at a price determined in the applicable
        debenture agreements. This settlement alternative allows the Fund to
        adequately manage liquidity, plan available cash resources and
        implement an optimal capital structure.

        To the extent that Advantage enters derivatives to manage commodity
        price risk, it may be subject to liquidity risk as derivative
        liabilities become due. While the Fund has elected not to follow
        hedge accounting, derivative instruments are not entered for
        speculative purposes and Management closely monitors existing
        commodity risk exposures. As such, liquidity risk is mitigated since
        any losses actually realized are subsidized by increased cash flows
        realized from the higher commodity price environment.

        The timing of cash outflows relating to financial liabilities are as
        follows:


                               Less than    One to      Four to
                                one year three years  five years  Thereafter
        ---------------------------------------------------------------------
        Accounts payable and
         accrued liabilities   $  78,066   $       -   $        -  $       -
        Derivative liabilities    17,376       7,996            -          -
        Bank indebtedness
          - principal                  -     644,100            -          -
          - interest              14,091      14,091            -          -
        Convertible debentures
          - principal            122,195      62,294            -          -
          - interest              16,256       7,920            -          -
        ---------------------------------------------------------------------
                               $ 247,984   $ 736,401   $        -  $       -
        ---------------------------------------------------------------------

        The Fund's bank indebtedness does not have specific maturity dates.
        It is governed by a credit facility agreement with a syndicate of
        financial institutions (note 6).  Under the terms of the agreement,
        the facility is reviewed annually, with the next review scheduled in
        June 2010. The facility is revolving, and is extendible at each
        annual review for a further 364 day period at the option of the
        syndicate. If not extended, the credit facility is converted at that
        time into a one year term facility, with the principal payable at the
        end of such one year term.  Management fully expects that the
        facility will be extended at each annual review.

        Interest Rate Risk

        The Fund is exposed to interest rate risk to the extent that bank
        indebtedness is at a floating rate of interest and the Fund's maximum
        exposure to interest rate risk is based on the effective interest
        rate and the current carrying value of the bank indebtedness. The
        Fund monitors the interest rate markets to ensure that appropriate
        steps can be taken if interest rate volatility compromises the Fund's
        cash flows. A 1% increase in interest rates for the six months ended
        June 30, 2009 could have decreased net income by approximately $2.3
        million for that period.

        Price and Currency Risk

        Advantage's derivative assets and liabilities are subject to both
        price and currency risks as their fair values are based on
        assumptions including forward commodity prices and foreign exchange
        rates. The Fund enters derivative financial instruments to manage
        commodity price risk exposure relative to actual commodity production
        and does not utilize derivative instruments for speculative purposes.
        Changes in the price assumptions can have a significant effect on the
        fair value of the derivative assets and liabilities and thereby
        impact net loss. It is estimated that a 10% increase in the forward
        natural gas prices used to calculate the fair value of the natural
        gas derivatives at June 30, 2009 could increase net loss by
        approximately $10.6 million for the six months ended June 30, 2009.
        As well, an increase of 10% in the forward crude oil prices used to
        calculate the fair value of the crude oil derivatives at June 30,
        2009 could increase net loss by $8.8 million for the six months ended
        June 30, 2009. An increase of 10% in the forward power prices used to
        calculate the fair value of the power derivatives at June 30, 2009
        would not materially increase net loss for the six months ended
        June 30, 2009. A similar increase in the currency rate assumption
        underlying the derivatives fair value does not materially increase
        net loss.

        As at June 30, 2009 the Fund had the following derivatives in place:

    Description of
     Derivative         Term            Volume                 Average Price
    -------------------------------------------------------------------------

    Natural gas - AECO

      Fixed price  April 2009 to      9,478 mcf/d              Cdn $8.66/mcf
                    December 2009
      Fixed price  April 2009 to      9,478 mcf/d              Cdn $8.67/mcf
                    December 2009
      Fixed price  April 2009 to      9,478 mcf/d              Cdn $8.94/mcf
                    December 2009
      Fixed price  April 2009 to     14,217 mcf/d              Cdn $7.59/mcf
                    March 2010
      Fixed price  April 2009 to     14,217 mcf/d              Cdn $7.56/mcf
                    March 2010
      Fixed price  January 2010 to   14,217 mcf/d              Cdn $8.23/mcf
                    June 2010
      Fixed price  January 2010 to   18,956 mcf/d              Cdn $7.29/mcf
                    December 2010
      Fixed price  April 2010 to     18,956 mcf/d              Cdn $7.25/mcf
                    January 2011

    Crude oil - WTI

      Collar       April 2009 to      2,000 bbl/d  Bought put Cdn $62.00/bbl
                    December 2009                   Sold call Cdn $76.00/bbl

      Fixed price  April 2009 to      2,000 bbls/d            Cdn $62.80/bbl
                    March 2010
      Fixed price  April 2010 to      2,000 bbls/d            Cdn $69.50/bbl
                    January 2011

    Electricity - Alberta Pool Price

      Fixed price  March 2009 to            2.0 MW             Cdn$75.43/MWh
                    December 2009


        As at June 30, 2009, the fair value of the derivatives outstanding
        resulted in an asset of approximately $66.2 million (December 31,
        2008 - $42.6 million) and a liability of approximately $25.4 million
        (December 31, 2008 - $1.7 million). For the six months ended June 30,
        2009, $0.2 million was recognized in income as an unrealized
        derivative loss (June 30, 2008 - $123.9 million unrealized derivative
        loss) and $45.6 million was recognized in income as a realized
        derivative gain (June 30, 2008 - $19.7 million realized derivative
        loss).

    11. Capital Management

        The Fund manages its capital with the following objectives:

        -  To ensure sufficient financial flexibility to achieve the ongoing
           business objectives including replacement of production, funding
           of future growth opportunities, and pursuit of accretive
           acquisitions; and

        -  To maximize Unitholder return through enhancing the Trust Unit
           value.

        Advantage monitors its capital structure and makes adjustments
        according to market conditions in an effort to meet its objectives
        given the current outlook of the business and industry in general.
        The capital structure of the Fund is composed of working capital
        (excluding derivative assets and liabilities), bank indebtedness,
        convertible debentures, capital lease obligations and Unitholders'
        equity.  Advantage may manage its capital structure by issuing new
        Trust Units, obtaining additional financing either through bank
        indebtedness or convertible debenture issuances, refinancing current
        debt, issuing other financial or equity-based instruments, adjusting
        or discontinuing the amount of monthly distributions, suspending or
        renewing its distribution reinvestment plan, adjusting capital
        spending, or disposing of assets.  The capital structure is reviewed
        by Management and the Board of Directors on an ongoing basis.
        Advantage's capital structure as at June 30, 2009 is as follows:

                                                               June 30, 2009
        ---------------------------------------------------------------------
        Bank indebtedness (long-term)                            $   644,100
        Working capital deficit(1)                                   131,913
        ---------------------------------------------------------------------
        Net debt                                                     776,013
        Trust Units outstanding market value                         711,470
        Convertible debentures maturity value (long-term)             62,294
        Capital lease obligations (long-term)                          2,970
        ---------------------------------------------------------------------
        Total capitalization                                     $ 1,552,747
        ---------------------------------------------------------------------
        (1) Working capital deficit includes accounts receivable, prepaid
            expenses and deposits, accounts payable and accrued liabilities,
            and the current portion of capital lease obligations and
            convertible debentures.

        The Fund's bank indebtedness is governed by a $710 million credit
        facility agreement (note 6) that contains standard commercial
        covenants for facilities of this nature.  The only financial covenant
        is a requirement for AOG to maintain a minimum cash flow to interest
        expense ratio of 3.5:1, determined on a rolling four quarter basis.
        The Fund is in compliance with all credit facility covenants.  As
        well, the borrowing base for the Fund's credit facilities is
        determined through utilizing Advantage's regular reserve estimates.
        The banking syndicate thoroughly evaluates the reserve estimates
        based upon their own commodity price expectations to determine the
        amount of the borrowing base. Revision or changes in the reserve
        estimates and commodity prices can have either a positive or a
        negative impact on the borrowing base of the Fund. On March 18,
        2009, we announced our intention to dispose of certain assets with
        the net proceeds from these sales utilized to reduce outstanding bank
        debt and improve Advantage's financial flexibility. Further to this
        end, asset sales were completed in July 2009 and the amount of the
        borrowing base was subsequently revised to $525 million for the new
        corporation (note 13). Advantage's issuance of convertible debentures
        is limited by its Trust Indenture which currently restricts the
        issuance of additional convertible debentures to 25% of market
        capitalization subsequent to issuance. Advantage's Trust Indenture
        also provides for the issuance of an unlimited number of Trust Units.
        However, through tax legislation, an income trust is restricted to
        doubling its market capitalization as it stands on October 31, 2006
        by growing a maximum of 40% in 2007 and 20% for the years 2008 to
        2010.  In addition, an income trust may replace debt that was
        outstanding as of October 31, 2006 with new equity or issue new, non-
        convertible debt without affecting the normal growth percentage. As
        a result of the "normal growth" guidelines as at June 30, 2009, the
        Fund is permitted to issue approximately $2.3 billion of new equity
        to January 1, 2011. If an income trust exceeds the established limits
        on the issuance of new trust units and convertible debt that
        constitute normal growth, the income trust will be immediately
        subject to the Specified Investment Flow-Through Entity tax
        legislation whereby the taxable portion of any distributions paid
        will be subject to tax at the trust level.

        Management of the Fund's capital structure is facilitated through its
        financial and operational forecasting processes.  The forecast of the
        Fund's future cash flows is based on estimates of production,
        commodity prices, forecast capital and operating expenditures, and
        other investing and financing activities. The forecast is regularly
        updated based on new commodity prices and other changes, which the
        Fund views as critical in the current environment.  Selected forecast
        information is frequently provided to the Board of Directors.

        The Fund's capital management objectives, policies and processes have
        remained unchanged during the six month period ended June 30, 2009.

    12. Commitments

        Advantage has several lease commitments relating to office buildings.
        The estimated remaining annual minimum operating lease rental
        payments for the buildings are as follows:

        2009                                                           1,931
        2010                                                           3,878
        2011                                                           1,471
        2012                                                           1,072
        ---------------------------------------------------------------------
                                                                 $     8,352
        ---------------------------------------------------------------------

    13. Subsequent events

        On July 7, 2009, the Fund successfully closed a bought deal financing
        with 17 million Trust Units issued at $6.00 each, for gross proceeds
        of $102 million.  The proceeds were used to reduce bank indebtedness.

        On July 9, 2009, the Fund successfully completed the Plan of
        Arrangement (the "Arrangement") pursuant to the Information Circular
        dated June 5, 2009.  Under the Arrangement, the Fund was dissolved
        and converted into a corporation, Advantage Oil and Gas Ltd. (the
        "Corporation"), with each Trust Unit of the Fund converted into one
        Common Share of the Corporation.

        On July 15 and 27, 2009, the Corporation successfully closed two
        dispositions of oil and natural gas properties for gross proceeds of
        $252.6 million, subject to customary adjustments.  The proceeds were
        used to reduce bank indebtedness.

        On August 13, 2009, the borrowing base of the credit facility was
        revised from $710 million to $525 million, pursuant to completion of
        the asset dispositions, with terms and conditions substantially
        unchanged.
    

    Advisory

    The information in this release contains certain forward-looking
statements. These statements relate to future events or our future
performance. All statements other than statements of historical fact may be
forward-looking statements. Forward-looking statements are often, but not
always, identified by the use of words such as "seek", "anticipate", "plan",
"continue", "estimate", "estimates", "expect", "designed", "may", "will",
"project", "predict", "potential", "targeting", "target", "targets" "intend",
"could", "might", "should", "believe", "would" and similar expressions. These
statements involve substantial known and unknown risks and uncertainties,
certain of which are beyond Advantage's control, including: the impact of
general economic conditions; industry conditions; changes in laws and
regulations including the adoption of new environmental laws and regulations
and changes in how they are interpreted and enforced; fluctuations in
commodity prices and foreign exchange and interest rates; stock market
volatility and market valuations; volatility in market prices for oil and
natural gas; liabilities inherent in oil and natural gas operations;
uncertainties associated with estimating oil and natural gas reserves;
competition for, among other things, capital, acquisitions, of reserves,
undeveloped lands and skilled personnel; incorrect assessments of the value of
acquisitions; changes in income tax laws or changes in tax laws and incentive
programs relating to the oil and gas industry and income trusts; geological,
technical, drilling and processing problems and other difficulties in
producing petroleum reserves; and obtaining required approvals of regulatory
authorities. Advantage's actual results, performance or achievement could
differ materially from those expressed in, or implied by, such forward-looking
statements and, accordingly, no assurances can be given that any of the events
anticipated by the forward-looking statements will transpire or occur or, if
any of them do, what benefits that Advantage will derive from them. Except as
required by law, Advantage undertakes no obligation to publicly update or
revise any forward-looking statements.

    %CIK: 0001468079




For further information:

For further information: Investor Relations, Toll free: 1-866-393-0393,
ADVANTAGE OIL & GAS LTD., 700, 400 - 3rd Avenue SW, Calgary, Alberta, T2P 4H2,
Phone: (403) 718-8000, Fax: (403) 718-8300, Web Site: www.advantageog.com,
E-mail: advantage@advantageog.com


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