(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
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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
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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 %
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Funds from
operations $ 51,590 $103,754 (50)% $107,181 $198,372 (46)%
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Overview
Three months ended Six months ended
June 30 June 30
2009 2008 % change 2009 2008 % change
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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
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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
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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)%
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Natural gas
including
hedging $ 63,998 $102,826 (38)% $133,244 $196,530 (32)%
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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)%
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Crude oil and NGLs
including
hedging $ 50,661 $106,042 (52)% $104,365 $200,843 (48)%
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Total revenue $114,659 $208,868 (45)% $237,609 $397,373 (40)%
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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
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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)%
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Total (boe/d) 31,044 32,015 (3)% 30,825 32,575 (5)%
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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
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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
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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