CALGARY, Nov. 7, 2013 /CNW/ - Vermilion Energy Inc. ("Vermilion", "We",
"Our", "Us" or the "Company") (TSX, NYSE: VET) is pleased to report
interim operating and unaudited financial results for the three and
nine months ended September 30, 2013.
HIGHLIGHTS
-
Recorded average production of 41,510 boe/d during the third quarter of
2013, compared to 42,813 boe/d in the prior quarter and 36,546 boe/d in
the third quarter of 2012. The modest decrease in quarter-over-quarter
production was attributable to seasonal changes in Canadian drilling
and tie-in activity, turnaround activity in the Netherlands and
management of available well deliverability in Australia, Canada and
the Netherlands to achieve corporate production growth targets.
Year-over-year production growth of 14% was achieved through continued
development of the Cardium and Mannville in Canada, and strong
production additions from the 2013 drilling programs in France and
Australia.
-
Generated fund flows from operations of $165.6 million ($1.63/share) in
the third quarter of 2013, as compared to $174.6 million ($1.73/share)
in the prior quarter and $137.1 million ($1.39/share) in the third
quarter of 2012. Fund flows from operations decreased 5% as compared
to the prior quarter due to increased taxes in France and foreign
exchange impacts, but increased 21% on a year-over-year basis.
-
We continue to benefit from our exposure to Brent-based crude oil,
WTI-based crude oil, and European natural gas pricing. Our Brent-based
crude production represents approximately 45% of total production and
65% of total crude oil and liquids production. Our Brent-based
production continues to attract a consolidated premium of more than
$4.00/bbl to the quoted Dated Brent reference price, which increased to
US$110.37/bbl during the third quarter. Our Canadian-based crude
production also benefited as it is indirectly priced off the WTI
reference price, which increased by US$11.60/bbl to US$105.82/bbl
during the quarter. Vermilion's natural gas production in the
Netherlands received an average price of $10.18/mcf during the third
quarter, compared to $2.43/mcf for AECO.
-
Strong operational performance across all of our operating regions
continues to provide us with flexibility to manage the composition of
produced volumes while exceeding our annual production targets. With
the contribution of production associated with our Netherlands
acquisition, which closed October 10, 2013, we now expect to achieve
average annual production volumes at the upper end of our current
guidance range of 40,500 to 41,000 boe/d. Our original 2013 guidance
of 39,000 to 40,500 boe/d was previously increased following both the
first and second quarters due to better-than-expected results from our
capital program. We expect to achieve organic production growth in all
four of our business units in 2013 as compared to 2012.
-
Continued development of our extensive position in the high-quality West
Pembina region of the Cardium light oil play. During the third
quarter, we drilled 16 (14.1 net) Cardium wells and brought 11 (10.6
net) Cardium wells on production. The third quarter drilling program
included five 1.5-mile and two 2-mile wells. Based on strong results
year-to-date, the remainder of the 2013 Cardium drilling program will
comprise a higher percentage of 1.5-mile, 1.75-mile and 2-mile wells.
-
Drilled and completed our fifth operated Mannville well in 2013 and
brought one well on production during the third quarter. Average rate
from the five operated wells to date is currently 2.3 mmcf/d sales gas
and 340 bbls/d of condensate and NGLs (77% condensate), with the
average well in its third month of production.
-
We continued to appraise our significant position in the Duvernay
liquids-rich natural gas resource play where we have amassed a total
land position of 321 net sections as of the end of the third quarter.
Our land position, which spans the liquids-rich gas fairway in three
contiguous blocks, has been assembled for approximately $76 million
dollars ($375/acre). We currently anticipate spud of our first
horizontal Duvernay well prior to year-end 2013, with completion
planned for early 2014.
-
In Ireland, tunneling operations re-started on November 3, 2013.
Tunneling operations had been suspended following an industrial
accident, which resulted in a fatality at the project worksite on
September 8, 2013. Onshore pipelining, offshore umbilical-laying,
seismic acquisition and workover activities for our Corrib project were
not impacted by the suspension. The effective impact of the delay in
tunneling operations is not fully determinable at this time, as a
portion of the tunneling delay may be recouped through accelerated
completion of other project activities. However, based on an early
review of our deterministic schedule for remaining construction and
commissioning activities, we believe it is prudent to revise our
expectations for timing of first gas to mid-2015 from earlier
expectations for start-up at the end of 2014 or early 2015. Following
successful subsea well operations conducted on one of the production
wells during the third quarter of 2013, we are increasing our peak
production estimate at Corrib from 54 mmcf/d (9,000 boe/d) to
approximately 58 mmcf/d (approximately 9,700 boe/d) net to Vermilion.
-
Subsequent to the third quarter, we announced the acquisition of
interests in nine concessions in the Netherlands from Northern
Petroleum PLC. The acquisition closed on October 10, 2013, and is
expected to add average production of approximately 400 boe/d in 2014
(taking into account working interest adjustments expected to occur
upon reaching anticipated payout of certain license agreements). The
acquisition also adds 2.3 million boe of proved plus probable reserves(1) and 298,500 net acres of land, of which approximately 98% is currently
undeveloped.
-
On November 6, 2013, we announced an agreement to acquire a 25%
contractual participation interest in a four partner consortium in
Germany from GDF Suez S.A. ("GDF"). The acquisition will enable us to
participate in the exploration and development, production and
transportation of natural gas from the assets which include four gas
producing fields across eleven production licenses. The assets are
estimated to produce at a company-interest average rate of
approximately 18 mmcf/d (3,000 boe/d) in 2013 and have estimated proved
plus probable reserves of 10.1 mmboe(2) net as of year-end 2013. The assets are characterized by a low
effective decline rate of approximately 16% annually and have an
estimated reserve life index of approximately 9.2 years. In addition to
the production licenses, a surrounding exploration license will also be
acquired pursuant to the acquisition. The exploration and production
licenses comprise 204,000 gross acres, of which 85% is in the
exploration license. The acquisition is well aligned with our European
focus, and will increase our exposure to the strong fundamentals and
pricing of European natural gas markets. We believe that our
experience with conventional and unconventional oil and gas
development, coupled with new access to proprietary technical data,
positions us for future development and expansion opportunities in both
Germany and the greater European region.
(1)
|
Estimated proved plus probable reserves attributable to the assets as
evaluated by GLJ Petroleum Consultants Ltd ("GLJ") in a report dated
September 16, 2013, with an effective date of December 31, 2012.
|
(2)
|
Estimated proved plus probable reserves attributable to the assets as
evaluated by GLJ in a report dated November 5, 2013, with an effective
date of December 31, 2013, using the GLJ (2013-10) price forecast.
|
Conference Call and Audio Webcast Details
Vermilion will discuss these results in a conference call to be held on
Thursday, November 7, 2013 at 9:00 AM MST (11:00 AM EST). To
participate, you may call 1-888-231-8191 (Canada and US Toll Free) or
1-647-427-7450 (International and Toronto Area). The conference call
will also be available on replay by calling 1-855-859-2056 using
conference ID number 68315493. The replay will be available until
midnight eastern time on November 14, 2013.
You may also listen to the audio webcast by clicking http://event.on24.com/r.htm?e=688125&s=1&k=E3FCF72FABA97FDA33D6CABBBE208AFF or visit Vermilion's website at www.vermilionenergy.com/ir/eventspresentations.cfm.
ABBREVIATIONS
bbl(s)
|
barrel(s)
|
mbbls
|
thousand barrels
|
bbls/d
|
barrels per day
|
mcf
|
thousand cubic feet
|
mmcf
|
million cubic feet
|
bcf
|
billion cubic feet
|
mcf/d
|
thousand cubic feet per day
|
mmcf/d
|
million cubic feet per day
|
GJ
|
gigajoules
|
MWh
|
megawatt hour
|
boe
|
barrel of oil equivalent, including: crude oil, natural gas liquids and
natural gas (converted on the basis of one boe for
six mcf of natural gas)
|
mboe
|
thousand barrel of oil equivalent
|
mmboe
|
million barrel of oil equivalent
|
boe/d
|
barrel of oil equivalent per day
|
NGLs
|
natural gas liquids
|
WTI
|
West Texas Intermediate, the reference price paid for crude oil of
standard grade in U.S. dollars at Cushing, Oklahoma
|
AECO
|
the daily average benchmark price for natural gas at the AECO 'C' hub in
southeast Alberta
|
TTF
|
the price for natural gas in the Netherlands, quoted in MWh of natural
gas per hour per day, at the Title Transfer
Facility Virtual Trading Point operated by Dutch TSO Gas Transport
Services
|
$M
|
thousand dollars
|
$MM
|
million dollars
|
PRRT
|
Petroleum Resource Rent Tax, a profit based tax levied on petroleum
projects in Australia
|
DISCLAIMER
Certain statements included or incorporated by reference in this
document may constitute forward looking statements or financial
outlooks under applicable securities legislation. Such forward looking
statements or information typically contain statements with words such
as "anticipate", "believe", "expect", "plan", "intend", "estimate",
"propose", or similar words suggesting future outcomes or statements
regarding an outlook. Forward looking statements or information in
this document may include, but are not limited to:
-
capital expenditures;
-
business strategies and objectives;
-
reserve quantities and the discounted present value of future net cash
flows from such reserves;
-
petroleum and natural gas sales;
-
future production levels (including the timing thereof) and rates of
average annual production growth;
-
exploration and development plans;
-
acquisition and disposition plans and the timing thereof;
-
operating and other expenses, including the payment of future dividends;
-
royalty and income tax rates;
-
the timing of regulatory proceedings and approvals; and
-
the timing of first commercial natural gas; and the estimate of
Vermilion's share of the expected natural gas production from the
Corrib field.
Such forward looking statements or information are based on a number of
assumptions all or any of which may prove to be incorrect. In addition
to any other assumptions identified in this document, assumptions have
been made regarding, among other things:
-
the ability of Vermilion to obtain equipment, services and supplies in a
timely manner to carry out its activities in Canada and
internationally;
-
the ability of Vermilion to market crude oil, natural gas liquids and
natural gas successfully to current and new customers;
-
the timing and costs of pipeline and storage facility construction and
expansion and the ability to secure adequate product transportation;
-
the timely receipt of required regulatory approvals;
-
the ability of Vermilion to obtain financing on acceptable terms;
-
foreign currency exchange rates and interest rates;
-
future crude oil, natural gas liquids and natural gas prices; and
-
Management's expectations relating to the timing and results of
exploration and development activities.
Although Vermilion believes that the expectations reflected in such
forward looking statements or information are reasonable, undue
reliance should not be placed on forward looking statements because
Vermilion can give no assurance that such expectations will prove to be
correct. Financial outlooks are provided for the purpose of
understanding Vermilion's financial strength and business objectives
and the information may not be appropriate for other purposes. Forward
looking statements or information are based on current expectations,
estimates and projections that involve a number of risks and
uncertainties which could cause actual results to differ materially
from those anticipated by Vermilion and described in the forward
looking statements or information. These risks and uncertainties
include but are not limited to:
-
the ability of management to execute its business plan;
-
the risks of the oil and gas industry, both domestically and
internationally, such as operational risks in exploring for, developing
and producing crude oil, natural gas liquids and natural gas;
-
risks and uncertainties involving geology of crude oil, natural gas
liquids and natural gas deposits;
-
risks inherent in Vermilion's marketing operations, including credit
risk;
-
the uncertainty of reserves estimates and reserves life;
-
the uncertainty of estimates and projections relating to production and
associated expenditures;
-
potential delays or changes in plans with respect to exploration or
development projects
-
Vermilion's ability to enter into or renew leases on acceptable terms;
-
fluctuations in crude oil, natural gas liquids and natural gas prices,
foreign currency exchange rates and interest rates;
-
health, safety and environmental risks;
-
uncertainties as to the availability and cost of financing;
-
the ability of Vermilion to add production and reserves through
exploration and development activities;
-
the possibility that government policies or laws may change or
governmental approvals may be delayed or withheld;
-
uncertainty in amounts and timing of royalty payments;
-
risks associated with existing and potential future law suits and
regulatory actions against Vermilion; and
-
other risks and uncertainties described elsewhere in this document or in
Vermilion's other filings with Canadian securities regulatory
authorities.
The forward looking statements or information contained in this document
are made as of the date hereof and Vermilion undertakes no obligation
to update publicly or revise any forward looking statements or
information, whether as a result of new information, future events or
otherwise, unless required by applicable securities laws.
In accordance with National Instruments 51-101, natural gas volumes have
been converted on the basis of six thousand cubic feet of natural gas
to one barrel of oil equivalent. Barrels of oil equivalent (boe) may
be misleading, particularly if used in isolation. A boe conversion
ratio of six thousand cubic feet to one barrel of oil is based on an
energy equivalency conversion method primarily applicable at the burner
tip and does not represent a value equivalency at the wellhead.
Financial data contained within this document are reported in Canadian
dollars, unless otherwise stated.
HIGHLIGHTS
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
($M except as indicated)
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
Financial
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Petroleum and natural gas sales
|
327,185
|
311,966
|
284,838
|
|
|
948,727
|
841,870
|
Fund flows from operations 1
|
165,645
|
174,592
|
137,094
|
|
|
503,866
|
415,991
|
|
Fund flows from operations ($/basic share)
|
1.63
|
1.73
|
1.39
|
|
|
5.01
|
4.26
|
|
Fund flows from operations ($/diluted share)
|
1.61
|
1.71
|
1.37
|
|
|
4.94
|
4.21
|
Net earnings
|
67,796
|
106,198
|
30,798
|
|
|
226,131
|
133,708
|
|
Net earnings per share ($/basic share)
|
0.67
|
1.05
|
0.31
|
|
|
2.25
|
1.37
|
Capital expenditures
|
135,661
|
78,118
|
106,255
|
|
|
394,248
|
295,503
|
Acquisitions
|
7,586
|
-
|
-
|
|
|
7,586
|
106,184
|
Asset retirement obligations settled
|
2,738
|
2,370
|
1,968
|
|
|
6,496
|
5,315
|
Cash dividends ($/share)
|
0.60
|
0.60
|
0.57
|
|
|
1.80
|
1.71
|
Dividends declared
|
61,003
|
60,776
|
56,196
|
|
|
181,391
|
167,282
|
Net dividends 1
|
41,649
|
42,146
|
38,945
|
|
|
127,875
|
113,692
|
|
% of fund flows from operations, gross
|
37%
|
35%
|
41%
|
|
|
36%
|
40%
|
|
% of fund flows from operations, net
|
25%
|
24%
|
28%
|
|
|
25%
|
27%
|
Total net dividends, capital expenditures and asset retirement
obligations
|
|
|
|
|
|
|
|
|
settled
|
180,048
|
122,634
|
147,168
|
|
|
528,619
|
414,510
|
|
% of fund flows from operations
|
109%
|
70%
|
107%
|
|
|
105%
|
100%
|
|
% of fund flows from operations (excluding the Corrib project)
|
87%
|
55%
|
93%
|
|
|
89%
|
88%
|
Net debt 1
|
700,286
|
674,368
|
549,491
|
|
|
700,286
|
549,491
|
Operational
|
Production
|
|
|
|
|
|
|
|
|
Crude oil (bbls/d)
|
26,664
|
26,638
|
23,047
|
|
|
25,640
|
24,062
|
|
NGLs (bbls/d)
|
1,945
|
1,775
|
1,245
|
|
|
1,719
|
1,341
|
|
Natural gas (mmcf/d)
|
77.41
|
86.40
|
73.52
|
|
|
81.97
|
77.50
|
|
Total (boe/d)
|
41,510
|
42,813
|
36,546
|
|
|
41,020
|
38,320
|
Average realized prices
|
|
|
|
|
|
|
|
|
Crude oil and NGLs ($/bbl)
|
108.87
|
98.95
|
100.70
|
|
|
103.95
|
102.32
|
|
Natural gas ($/mcf)
|
6.00
|
7.22
|
6.12
|
|
|
6.68
|
5.89
|
Production mix (% of production)
|
|
|
|
|
|
|
|
|
% priced with reference to WTI
|
24%
|
25%
|
23%
|
|
|
24%
|
23%
|
|
% priced with reference to AECO
|
17%
|
17%
|
16%
|
|
|
17%
|
17%
|
|
% priced with reference to European gas
|
14%
|
17%
|
17%
|
|
|
16%
|
17%
|
|
% priced with reference to Dated Brent
|
45%
|
41%
|
44%
|
|
|
43%
|
43%
|
Netbacks ($/boe) 1
|
|
|
|
|
|
|
|
|
Operating netback
|
61.91
|
59.30
|
55.02
|
|
|
60.12
|
54.87
|
|
Fund flows netback
|
43.60
|
44.90
|
38.66
|
|
|
44.13
|
39.44
|
|
Operating expenses
|
12.17
|
12.36
|
13.27
|
|
|
12.87
|
12.78
|
Average reference prices
|
|
|
|
|
|
|
|
|
WTI (US $/bbl)
|
105.82
|
94.22
|
92.22
|
|
|
98.14
|
96.21
|
|
Edmonton Sweet index (US $/bbl)
|
101.10
|
90.56
|
85.01
|
|
|
93.03
|
86.94
|
|
Dated Brent (US $/bbl)
|
110.37
|
102.44
|
109.61
|
|
|
108.45
|
112.10
|
|
AECO ($/GJ)
|
2.31
|
3.35
|
2.17
|
|
|
2.89
|
2.00
|
|
Netherlands gas price ($/GJ)
|
9.94
|
10.14
|
9.06
|
|
|
10.17
|
9.38
|
Share information ('000s)
|
Shares outstanding - basic
|
101,787
|
101,418
|
98,729
|
|
|
101,787
|
98,729
|
Shares outstanding - diluted 1
|
104,195
|
103,735
|
101,149
|
|
|
104,195
|
101,149
|
Weighted average shares outstanding - basic
|
101,613
|
100,964
|
98,523
|
|
|
100,634
|
97,704
|
Weighted average shares outstanding - diluted
|
102,763
|
102,223
|
99,748
|
|
|
102,083
|
98,848
|
|
|
1
|
The above table includes non-GAAP measures which may not be comparable
to other companies. Please see the "Non-GAAP Measures" section of
Management's Discussion and Analysis.
|
OPERATIONAL REVIEW AND OUTLOOK
Vermilion's strong performance year-to-date illustrates our consistent
operational execution and the advantages of our global diversification
strategy. To the end of the third quarter of 2013, we have achieved
organic growth across all four of our operating regions. In addition,
subsequent to the third quarter of 2013, we announced two strategic
acquisitions that further expand our European presence.
On October 1, 2013, we announced our agreement to acquire additional
operating interests in nine operated onshore concessions (six in
production or development and three exploration) and a non-operated
interest in one offshore concession in the Netherlands for $27.5
million. Four of the onshore concessions are located in the
northeastern part of the Netherlands, in close proximity to our
existing concessions. The remaining onshore licenses provide new
opportunity for Vermilion in the central region of the Netherlands. We
closed the acquisition on October 10, 2013. Production from the
acquired assets is expected to average approximately 400 boe/d in 2014
(after working interest adjustments expected to occur upon reaching
anticipated payout of certain license agreements). The production is
comprised of 99% natural gas that is expected to produce an operating
netback in-line with our current operating netback for natural gas in
the Netherlands. The acquisition also adds 2.3 mmboe of proved plus
probable reserves(1) and 298,500 net acres of land, of which approximately 98% is currently
undeveloped. The acquisition increases our undeveloped land base in
the Netherlands to more than 780,000 net acres. We have identified
several development opportunities on the assets that increase our
already significant inventory of investment projects on our existing
Netherlands land base. The acquisition enhances our position as the
second largest onshore natural gas producer in the Netherlands, and
offers a strong fit with our current operations.
On November 6, 2013, we announced an agreement to acquire a 25%
contractual participation interest in a four-partner consortium in
Germany from GDF Suez S.A. ("GDF"), for a cash cost of approximately
$170 million. The consortium was formed in 1956 between industry
leaders ExxonMobil Corporation ("ExxonMobil"), Wintershall Holding GmbH
("Wintershall"), BEB Erdgas und Erdöl GmbH ("BEB", a joint venture
between ExxonMobil and Deutsche Shell AG.) and GDF. The acquisition,
which is expected to be completed prior to the end of January, 2014,
will enable us to participate in the exploration and development,
production and transportation of natural gas from the assets held by
the consortium. The assets are comprised of four gas producing fields
across eleven production licenses. Vermilion will also receive a 0.4%
equity interest in Ergas Munster GmbH ("EGM"), a joint venture created
in 1959 to jointly transport, process, and market gas in northwest
Germany. EGM partners include ExxonMobil, Wintershall, BEB, RWE Dea
AG., and GDF. The transportation interest will allow for our
proportionate share of produced volumes to be processed, blended, and
transported to designated gas consumers through the EGM network of
approximately 2,000 kilometres of pipeline. The assets are estimated
to produce at a company-interest average rate of approximately 18
mmcf/d (3,000 boe/d) in 2013, and have net estimated year-end 2013
proved plus probable reserves of 10.1 mmboe(2). The assets are further characterized by a low effective decline rate
of approximately 16% annually and an estimated reserve life index of
9.2 years. In addition to the production licenses, a surrounding
exploration license will also be acquired pursuant to the acquisition.
The exploration and production licenses comprise 204,000 gross acres,
of which 85% is in the exploration license. Realized pricing for
production from the assets is expected to be derived from the TTF
price, less certain gas quality adjustments and marketing fees. The
Germany acquisition is also expected to be highly accretive for all
pertinent metrics. Assuming estimated 2013 net average daily
production of 18 mmcf/d (3,000 boe/d) and a cash cost of $170 million,
the acquisition metrics reflect a cash cost of approximately $57,000
per boe/d and $18.70/boe of estimated year-end 2013 proved plus
probable reserves, including future development capital. The
acquisition represents Vermilion's entry into the German exploration
and production business, a producing region with a long history of oil
and gas development activity, low political risk, and strong marketing
fundamentals. Germany currently produces approximately 165 thousand
barrels per day of oil and natural gas liquids(3) and 1.1 bcf per day of natural gas(3). The acquisition represents a key entry opportunity into this sizable
market, in the form of free cash flow(4) generating, low-decline assets with near-term development inventory in
addition to longer-term, low-permeability gas prospectivity. The
acquisition is well aligned with our European focus, and will increase
our exposure to the strong fundamentals and pricing of European natural
gas markets. The assets are located 300 kilometres to the east of our
Netherlands assets, and share similar subsurface characteristics. We
believe that our experience with conventional and unconventional oil
and gas development, coupled with new access to proprietary technical
data, positions us for future development and expansion opportunities
in both Germany and the greater European region.
We continue to benefit from our diversified product mix and growing
exposure to European gas markets. In the third quarter, 2013, our
natural gas production in the Netherlands received an average price of
$10.18/mcf. This compares to $2.43/mcf for AECO, and US$3.56/mcf for
NYMEX, affording us a significant competitive pricing advantage
compared to North American natural gas producers. We also continue to
benefit from our strong exposure to Brent-based crude oil. Brent-based
crude production currently represents approximately 45% of our total
production and 65% of our total crude oil and liquids production and
continues to attract a consolidated premium of more than $4.00/bbl to
the quoted Dated Brent reference price, which increased to
US$110.37/bbl during the third quarter. Our strong exposure to
Brent-based crude production provides us a further pricing advantage
compared to North American-focused producers. While our relative
pricing advantage remains a strong differentiator, the diversified
nature of our production mix means we were also able to participate in,
and benefit from, the strengthening of North American crude prices
during the third quarter. Our Canadian-based crude production,
approximately 24% of our total production, receives pricing based on
the Edmonton Sweet Index ("ESI"). The ESI averaged US$101.10/bbl
during the third quarter, an increase of US$10.54/bbl versus the prior
quarter. Year-over-year, the ESI has increased more than
US$16.00/bbl. On balance, our exposure to diversified commodity
markets reduces the volatility of our cash flows and lowers our risk
profile.
The majority of our Canadian development activities during the third
quarter continued to focus on our Cardium light oil play. Well
performance remains consistently strong, reflective of the high quality
nature of the reservoir underlying our land position in the West
Pembina region. Since entering the play in 2009, we have drilled or
participated in 219 (155.3 net) wells in the Cardium and increased
production to over 9,000 boe/d. We continue to optimize completion
technology and well design, and remain a leader in the utilization of
long reach wells (greater than one mile in length) in development of
the Cardium in West Pembina. We have been able to demonstrate
consistent production improvement and a significant reduction in
per-section development costs through the use of long-reach 1.5-mile
horizontal wells. During the third quarter, we drilled five 1.5-mile,
1.75-mile and two 2-mile wells. The remainder of the 2013 Cardium
drilling program is expected to comprise an even higher percentage of
1.5-mile and 2-mile pilot wells. The optimization of frac design and
fluids, multi-well pads and drilling longer horizontal wells has
enabled us to reduce well costs from more than $5 million per section
at the outset of development in 2009 to approximately $3 million per
section today. Furthermore, in pursuit of ongoing well cost reduction
and enhanced environmental stewardship, we have been testing several
alternative processes for the recycling of frac flowback water. During
the third quarter we successfully treated frac flowback water, using a
chemical treatment process, at rates equivalent to the highest frac
flowback rate we typically experience. Results to date indicate the
potential for significant savings while also decreasing the
environmental impact of our operations. We have also initiated a water
injection pilot to test applicability of water-flooding to this
reservoir. Our per unit operating costs remain less than $6/boe for our
operated Cardium production, resulting in strong operating netbacks of
approximately $65/boe during the third quarter.
In addition to the Cardium, we have also begun development of our
significant inventory of Mannville condensate-rich natural gas targets
in the Drayton Valley area. Year-to-date, we have drilled or
participated in a total of eight (4.2 net) Mannville wells targeting
the Ellerslie formation, with one (0.5 net) additional operated well
and two (0.8 net) non-operated wells planned during the fourth quarter
of 2013. The average per well rate from our five-well operated program
to-date in 2013 is currently 2.3 mmcf/d sales gas and 340 bbls/d of
condensate and NGLs (77% condensate), with the average well in its
third month of production. We have achieved 100% success on the
placement of the frac stages on all five wells.
We continue to appraise our position in the Duvernay liquids-rich
natural gas resource play, where we have amassed 321 net sections at a
cost of approximately $76 million ($375/acre). Our position spans the
breadth of the liquids-rich natural gas fairway, and comprises three
largely contiguous blocks in the Edson, Drayton Valley and Niton
areas. To date, we have drilled three vertical stratigraphic test
wells, and plan to spud our first horizontal well prior to the end of
2013, with completion anticipated to occur in 2014. Our Duvernay
rights generally underlie our Cardium and Mannville liquids-rich gas
positions, allowing for potential infrastructure, operational, and
timing advantages in full field development of the Duvernay. Combined,
our Cardium, Mannville, and Duvernay positions provide us with
exploration and development opportunities in our core Canadian
operating region that have the potential to deliver strong production
and reserve growth into the latter half of the decade.
Capital expenditures in Australia during the third quarter of 2013 were
mainly for repairs and maintenance activity. During the first half of
2013, we drilled two sidetracks off existing wells in Australia. The
program included the drilling of a 3,400 metre horizontal leg, the
longest horizontal section drilled to-date at Wandoo. The 2013 drilling
program has been our most successful effort yet in Australia. Both
sidetracks were brought on production at restricted rates in April,
demonstrating productive capacities in excess of 6,000 bbls/d and 3,000
bbls/d, respectively. To meet current marketing agreements and provide
long-term certainty to our customers, our current plan is to maintain
production levels within our prior guidance of between 6,000 bbls/d and
8,000 bbls/d. We anticipate maintaining these production levels in
Australia for the foreseeable future with drilling programs
approximately every two years. Wandoo's oil garners a premium of
approximately US$7.00 to the Dated Brent index and incurs no
transportation cost as production is sold directly at the platform,
leading to very high netbacks.
Also during the first half of 2013, we concluded a five-well drilling
program in the Champotran field in France. All five of the wells were
successful, with on-stream production rates in excess of 300 bbls/d per
well and low water cuts. In 2012, we completed two acquisitions that
were natural additions to our asset base in France and further secured
our position as the leading oil producer in the country. We continue
to integrate these assets and to identify further opportunities to
increase production through seismic data acquisition, workovers,
optimized water-flood management and development drilling. Our French
business is now an organic growth asset, featuring low base decline
rates, high netbacks from Brent-indexed production, strong cash flow
generation and high capital efficiencies on development projects. We
are increasing our France-based technical staffing to identify and
execute additional investment opportunities in these large, complex,
conventional light oil fields in both the Paris and Aquitaine Basins.
In the Netherlands, in addition to activities related to our acquisition
of additional interests completed in October, 2013, we continued
drilling preparations for a three-well drilling campaign to be
initiated in December 2013. Our Garijp debottlenecking project was
completed in the first quarter of 2013, enabling incremental production
from two wells previously drilled at Vinkega. Surface facilities for
the multi-zone Langezwaag-1 well (42% working interest) were completed
and commissioned mid-way through the second quarter. Netherlands
production during the third quarter was curtailed to facilitate a
turnaround at the Garijp Treatment Centre and the retrofitting of our
Middenmeer Treatment Centre. We intend to increase activity in the
Netherlands each year to maintain a rolling inventory of projects so
that each year's capital program will involve a combination of drilling
new wells and the tie-in of previous successes. Like our French
Business Unit, we now consider our Netherlands Business Unit to be an
organic growth business, and we are increasing our technical staffing
in the Netherlands to turn our substantial inventory of prospect leads
into drillable projects.
In Ireland, tunneling operations re-started effective November 3, 2013.
Tunneling operations had been suspended following an industrial
accident, which resulted in a fatality at the project worksite, on
September 8, 2013. Onshore pipelining, offshore umbilical-laying,
seismic acquisition and workover activities for our Corrib project were
not impacted by the suspension. The effective impact of the delay in
tunneling operations is not fully determinable at this time, as a
portion of the tunneling delay may be recouped through accelerated
completion of other project activities. However, based on an early
review of our deterministic schedule for remaining construction and
commissioning activities, we believe it is prudent to revise our
expectations for timing of first gas to mid-2015 from earlier
expectations for start-up at the end of 2014 or early 2015. Following
successful subsea well operations conducted during the third quarter of
2013, we are increasing our peak production estimate at Corrib from 54
mmcf/d (9,000 boe/d) to approximately 58 mmcf/d (approximately 9,700
boe/d) net to Vermilion.
Strong operational performance across all of our operating regions
continues to provide us with flexibility to manage the composition of
produced volumes while exceeding our initial annual production
targets. With the contribution of production associated with our
Netherlands acquisition, completed in October 2013, we now expect to
achieve average annual production volumes at the upper end of our
guidance range of 40,500 to 41,000 boe/d. Our original 2013 guidance
of 39,000 to 40,500 boe/d was previously increased following both the
first and second quarters due to better-than-expected results from our
capital program.
Development capital for 2013 is currently estimated at $530 million, an
increase of approximately $45 million from our original guidance of
$485 million. The increase is attributable primarily to the impact of
a weaker Canadian dollar as compared to foreign exchange rates at the
time of our original guidance, a delay in the timing of rig arrival for
our Australian drill program (originally anticipated to occur in late
2012) which shifted expenditures into 2013, and minor additions to our
capital work scope during 2013 (such as the addition of the Champotran
southern extension well in France). The Australian drilling program
occurred in the first half of 2013, a period during which the Canadian
dollar weakened significantly against the Australian dollar, reaching
near all-time lows in March and April 2013. The Canadian dollar has
also experienced significant weakness versus the Euro, particularly
during the second half of 2013, translating into higher Canadian
dollar-denominated capital expenditures than originally planned.
Conversely, though the weaker Canadian dollar has driven up capital
spending, it has also resulted in higher Canadian dollar-denominated
fund flows from operations(4) from our foreign jurisdictions, through the translation of foreign
currency-denominated revenues into Canadian dollars. Our operations
continue to perform strongly, generating organic production growth
across all four operating regions in a capital-efficient manner.
Assuming commodity prices remain near current levels for the remainder
of this year, we anticipate that we will fully fund our net dividends(4) and development capital expenditures (excluding capital investment at
Corrib) with fund flows from operations(4) during 2013.
In the first quarter of 2013 Vermilion shares began trading on the New
York Stock Exchange under the ticker symbol "VET". As an international
oil and gas producer, we believe the secondary listing will assist in
broadening our investor base and increasing trading liquidity.
We believe we remain positioned to deliver strong operational and
financial performance over the next several years. We continue to
target annual organic production growth of approximately 5% along with
providing reliable and growing dividends. Near term growth and cash
flow are expected to be driven by continued Cardium and Mannville
development in Canada, oil development activities in France, and
high-netback natural gas drilling in the Netherlands. A significant
increment of production growth and free cash flow growth is expected
from Corrib beginning mid- 2015 with the first full year of production
from the project in 2016. Our Australian Business Unit is expected to
provide steady production as well as significant free cash flow.
We increased our monthly dividend by 5.3% in the first quarter of 2013,
from $0.19 to $0.20 per share. The increase became effective for the
January 2013 dividend paid February 15, 2013. With the anticipated
growth of fund flows from operations, the continued strength of our
operations, and our expansive opportunity base (including our recently
announced acquisition in the Netherlands and our proposed acquisition
in Germany), we are confident we can achieve our future growth
objectives and continue to provide a reliable and growing dividend
stream to investors. We believe our balance sheet remains well
positioned to execute its capital-efficient growth-and-income model and
fund Corrib development through to first gas while remaining within an
acceptable net debt-to-fund flows from operations(4) ratio. Corrib is expected to provide a further significant increase to
our projected free cash flow upon first gas production.
Our conservative fiscal management and capital discipline leaves us well
positioned to execute our growth-and-income model and provide growth to
investors on a per share basis. The management and directors of
Vermilion continue to hold approximately 8% of the outstanding shares
and remain committed to delivering superior rewards to all
stakeholders. Continuing to be acknowledged for excellence in our
business practices, Vermilion was recognized for the fourth consecutive
year by the Great Place to Work® Institute in both Canada and France.
We ranked as the 22nd Best Workplace in Canada among more than 315
companies. Our French unit ranked as the 27th Best Workplace in the
country.
(1)
|
Estimated proved plus probable reserves attributable to the assets as
evaluated by GLJ Petroleum Consultants Ltd ("GLJ") in a report dated
September 16, 2013, with an effective date of December 31, 2012.
|
(2)
|
Estimated proved plus probable reserves attributable to the assets as
evaluated by GLJ in a report dated November 5, 2013, with an effective
date of December 31, 2013, using the GLJ (2013-10) price forecast.
|
(3)
|
U.S. Energy Information Administration website (www.eia.gov); quoted 2012 total oil supply and 2012 dry natural gas production.
|
(4)
|
See non-GAAP measures disclosures in the Management's Discussion and
Analysis for the three and nine months ended September 30, 2013.
|
MANAGEMENT'S DISCUSSION AND ANALYSIS
The following is Management's Discussion and Analysis ("MD&A"), dated
November 6, 2013, of Vermilion Energy Inc.'s ("Vermilion", "We", "Our",
"Us" or the "Company") operating and financial results as at and for
the three and nine months ended September 30, 2013 as compared with the
corresponding periods in the prior year.
This discussion should be read in conjunction with the unaudited
condensed consolidated interim financial statements for the three and
nine months ended September 30, 2013 and the audited consolidated
financial statements for the year ended December 31, 2012 and 2011,
together with accompanying notes. Additional information relating to
Vermilion, including its Annual Information Form, is available on SEDAR
at www.sedar.com or on Vermilion's website at www.vermilionenergy.com.
The unaudited condensed consolidated interim financial statements for
the three and nine months ended September 30, 2013 and comparative
information have been prepared in Canadian dollars, except where
another currency has been indicated, and in accordance with IAS 34,
"Interim financial reporting", as issued by the International
Accounting Standards Board.
NON-GAAP MEASURES
This report includes non-GAAP measures as further described herein.
These non-GAAP measures do not have standardized meanings prescribed by
International Financial Reporting Standards ("IFRS" or, alternatively,
"GAAP") and therefore may not be comparable with the calculations of
similar measures for other entities.
"Fund flows from operations" represents cash flows from operating activities before changes in
non-cash operating working capital and asset retirement obligations
settled. Management considers fund flows from operations and fund
flows from operations per share to be key measures as they demonstrate
Vermilion's ability to generate the cash necessary to pay dividends,
repay debt, fund asset retirement obligations and make capital
investments. Management believes that by excluding the temporary
impact of changes in non-cash operating working capital, fund flows
from operations provides a useful measure of Vermilion's ability to
generate cash that is not subject to short-term movements in non-cash
operating working capital.
"Fund flows from operations (excluding the Corrib project)" represents fund flows from operations excluding expenses related to the
Corrib project. Management believes that by excluding expenses related
to the Corrib project, fund flows from operations (excluding the Corrib
project) provides a useful measure of Vermilion's ability to generate
cash from its current producing assets.
The most directly comparable GAAP measure to fund flows from operations
and fund flows from operations (excluding the Corrib project) is cash
flows from operating activities.
Cash flows from operating activities as presented in Vermilion's
consolidated statements of cash flows are reconciled to fund flows from
operations and fund flows from operations (excluding the Corrib
project) as follows:
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Cash flows from operating activities
|
158,236
|
179,074
|
148,301
|
|
|
528,022
|
396,673
|
Changes in non-cash operating working capital
|
4,671
|
(6,852)
|
(13,175)
|
|
|
(30,652)
|
14,003
|
Asset retirement obligations settled
|
2,738
|
2,370
|
1,968
|
|
|
6,496
|
5,315
|
Fund flows from operations
|
165,645
|
174,592
|
137,094
|
|
|
503,866
|
415,991
|
Expenses related to the Corrib project
|
876
|
2,036
|
2,171
|
|
|
4,767
|
6,879
|
Fund flows from operations (excluding the Corrib project)
|
166,521
|
176,628
|
139,265
|
|
|
508,633
|
422,870
|
"Free cash flow" represents fund flows from operations in excess of capital
expenditures. Management considers free cash flow to be a key measure
as it is used to determine the funding available for investing and
financing activities, including payment of dividends, repayment of
long-term debt, reallocation to existing business units, and deployment
into new ventures.
"Cash dividends per share" represents cash dividends declared per share by Vermilion.
"Net dividends" are dividends declared less proceeds received by Vermilion for the
issuance of shares pursuant to the dividend reinvestment plan, both as
presented in Vermilion's consolidated statements of changes in
shareholders' equity. Dividends both before and after the dividend
reinvestment plan are reviewed by management and are assessed as a
percentage of fund flows from operations to analyze the amount of cash
that is generated by Vermilion which is being used to fund dividends.
Dividends declared is the most directly comparable GAAP measure to net
dividends.
"Total net dividends, capital expenditures and asset retirement
obligations settled" are net dividends plus the following amounts from Vermilion's
consolidated statements of cash flows: drilling and development,
exploration and evaluation, dispositions and asset retirement
obligations settled.
"Total net dividends, capital expenditures and asset retirement
obligations settled (excluding the Corrib project)" are total net dividends, capital expenditures and asset retirement
obligations settled excluding drilling and development and asset
retirement obligations settled relating to the Corrib project.
Total net dividends, capital expenditures and asset retirement
obligations settled and total net dividends, capital expenditures and
asset retirement obligations settled (excluding the Corrib project) are
reviewed by management and are assessed as a percentage of fund flows
from operations and fund flows from operations (excluding the Corrib
project) to analyze the amount of cash that is generated by Vermilion
that is available to repay debt and fund potential future acquisitions
and capital expenditures.
Dividends declared, total net dividends, capital expenditures and asset
retirement obligations settled and total net dividends, capital
expenditures and asset retirement obligations settled (excluding the
Corrib project) are reconciled to their most directly comparable GAAP
measures as follows:
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Dividends declared
|
61,003
|
60,776
|
56,196
|
|
|
181,391
|
167,282
|
Issuance of shares pursuant to the dividend reinvestment plan
|
(19,354)
|
(18,630)
|
(17,251)
|
|
|
(53,516)
|
(53,590)
|
Net dividends
|
41,649
|
42,146
|
38,945
|
|
|
127,875
|
113,692
|
Drilling and development
|
135,110
|
75,005
|
96,212
|
|
|
389,635
|
262,064
|
Dispositions
|
-
|
-
|
-
|
|
|
(8,627)
|
-
|
Exploration and evaluation
|
551
|
3,113
|
10,043
|
|
|
13,240
|
33,439
|
Asset retirement obligations settled
|
2,738
|
2,370
|
1,968
|
|
|
6,496
|
5,315
|
Total net dividends, capital expenditures and asset retirement
obligations settled
|
180,048
|
122,634
|
147,168
|
|
|
528,619
|
414,510
|
Capital expenditures and asset retirement obligations settled
|
|
|
|
|
|
|
|
related to the Corrib project
|
(35,028)
|
(24,878)
|
(17,164)
|
|
|
(76,426)
|
(40,574)
|
Total net dividends, capital expenditures and asset retirement
obligations settled
|
|
|
|
|
|
|
|
(excluding the Corrib project)
|
145,020
|
97,756
|
130,004
|
|
|
452,193
|
373,936
|
"Net debt" is the sum of long-term debt and working capital as presented in
Vermilion's consolidated balance sheets. Net debt is used by
management to analyze the financial position and leverage of
Vermilion. The most directly comparable GAAP measure is long-term
debt.
Long-term debt as presented in Vermilion's consolidated balance sheets
is reconciled to net debt as follows:
|
|
|
|
|
As At
|
|
|
|
|
|
Sept 30,
|
Dec 31,
|
($M)
|
|
|
|
|
2013
|
2012
|
Long-term debt
|
|
|
|
|
781,074
|
642,022
|
Current liabilities
|
|
|
|
|
389,757
|
355,711
|
Current assets
|
|
|
|
|
(470,545)
|
(320,502)
|
Net debt
|
|
|
|
|
700,286
|
677,231
|
"Netbacks" are per boe and per mcf measures used in the analysis of operational
activities and as a basis for decisions on capital allocation.
"Diluted shares outstanding" is the sum of shares outstanding at the period-end plus outstanding
awards under Vermilion's equity based compensation plan, based on
current estimates of future performance factors and forfeitures. The
most directly comparable GAAP measure is shares outstanding.
Shares outstanding is reconciled to diluted shares outstanding as
follows:
|
As At
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
('000s of shares)
|
2013
|
2013
|
2012
|
Shares outstanding
|
101,787
|
101,418
|
98,729
|
Potential shares issuable pursuant to the equity based compensation plan
|
2,408
|
2,317
|
2,420
|
Diluted shares outstanding
|
104,195
|
103,735
|
101,149
|
OPERATIONAL ACTIVITIES
Canada
Vermilion drilled 21 (16.3 net) wells during the third quarter of 2013.
In the Cardium, the Company drilled 17 (14.3 net) wells and brought 11
gross operated wells on production. In the Mannville, Vermilion drilled
four (2.0 net) wells and brought one well on production. Of the wells
drilled in the third quarter, seven were long reach wells, including
two 2-mile long wells.
France
Vermilion completed 3D seismic and subsurface studies in the Vic Bihl
region that were begun late in the second quarter. The Company also
completed a number of workovers in both the Paris and Aquitaine Basins,
along with preparations for the Company's 2014 capital program.
Netherlands
Operating activities in the third quarter focused on facility
maintenance and site construction, including retrofitting the
Middenmeer Treatment Centre. The upgrades to this facility will ensure
reliability and capacity to support upcoming planned drilling programs
in the Slootdorp and Opmeer concessions. Vermilion is currently
planning and preparing for a three well drilling program in the
Netherlands, beginning in late-2013.
Australia
In Australia, efforts were focused on minor facilities repairs and
engineering studies. Wandoo A received a five-year platform
recertification during the third quarter of 2013.
PRODUCTION
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
|
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Canada
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil & NGLs (bbls/d)
|
9,866
|
10,610
|
8,526
|
|
(7%)
|
16%
|
|
|
9,928
|
8,825
|
|
12%
|
|
Natural gas (mmcf/d)
|
43.40
|
43.69
|
35.54
|
|
(1%)
|
22%
|
|
|
42.72
|
39.55
|
|
8%
|
|
Total (boe/d)
|
17,099
|
17,892
|
14,449
|
|
(4%)
|
18%
|
|
|
17,047
|
15,417
|
|
11%
|
|
% of consolidated
|
41%
|
42%
|
40%
|
|
|
|
|
|
42%
|
40%
|
|
|
France
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil (bbls/d)
|
11,625
|
10,390
|
9,767
|
|
12%
|
19%
|
|
|
10,786
|
9,989
|
|
8%
|
|
Natural gas (mmcf/d)
|
5.23
|
4.19
|
3.39
|
|
25%
|
54%
|
|
|
4.54
|
3.48
|
|
30%
|
|
Total (boe/d)
|
12,496
|
11,088
|
10,333
|
|
13%
|
21%
|
|
|
11,544
|
10,569
|
|
9%
|
|
% of consolidated
|
30%
|
26%
|
28%
|
|
|
|
|
|
28%
|
28%
|
|
|
Netherlands
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NGLs (bbls/d)
|
48
|
50
|
41
|
|
(4%)
|
17%
|
|
|
65
|
66
|
|
(2%)
|
|
Natural gas (mmcf/d)
|
28.78
|
38.52
|
34.59
|
|
(25%)
|
(17%)
|
|
|
34.71
|
34.47
|
|
1%
|
|
Total (boe/d)
|
4,845
|
6,470
|
5,806
|
|
(25%)
|
(17%)
|
|
|
5,849
|
5,811
|
|
1%
|
|
% of consolidated
|
12%
|
15%
|
16%
|
|
|
|
|
|
14%
|
15%
|
|
|
Australia
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil (bbls/d)
|
7,070
|
7,363
|
5,958
|
|
(4%)
|
19%
|
|
|
6,580
|
6,523
|
|
1%
|
|
% of consolidated
|
17%
|
17%
|
16%
|
|
|
|
|
|
16%
|
17%
|
|
|
Consolidated
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude oil & NGLs (bbls/d)
|
28,609
|
28,413
|
24,292
|
|
1%
|
18%
|
|
|
27,359
|
25,403
|
|
8%
|
|
% of consolidated
|
69%
|
66%
|
66%
|
|
|
|
|
|
67%
|
66%
|
|
|
|
Natural gas (mmcf/d)
|
77.41
|
86.40
|
73.52
|
|
(10%)
|
5%
|
|
|
81.97
|
77.50
|
|
6%
|
|
% of consolidated
|
31%
|
34%
|
34%
|
|
|
|
|
|
33%
|
34%
|
|
|
|
Total (boe/d)
|
41,510
|
42,813
|
36,546
|
|
(3%)
|
14%
|
|
|
41,020
|
38,320
|
|
7%
|
Canadian production of 17,099 boe/d during the third quarter of 2013
represented a modest decrease compared to 17,892 boe/d in the second
quarter, but an increase compared to 14,449 boe/d in the third quarter
of the prior year. The slight quarter-over-quarter decrease is mainly
attributable to declines given lack of activity during break-up. The
18% year-over-year increase in production is largely attributable to
continued development in the Cardium, supplemented by Mannville wells
brought on during the year. Vermilion continues to focus on high
netback oil and liquids, representing approximately 58% of Canadian
production in the third quarter of 2013.
Production in France averaged 12,496 boe/d in the third quarter of 2013,
an increase of 13% compared to production of 11,088 boe/d in the second
quarter of 2013. On a year-over-year basis, production has grown by
21%. This increase in volume is mainly attributable to production from
the five-well drilling program in Champotran which was brought on late
in the second quarter of 2013. In France, Vermilion remains
predominantly weighted to Brent crude at approximately 93% of
production in the third quarter of 2013.
Production volumes averaged 4,845 boe/d in the Netherlands during the
third quarter of 2013, a 25% decrease compared to 6,470 boe/d in the
prior quarter and a 17% decrease compared to 5,806 boe/d in the third
quarter of 2012. The decrease in production is mainly attributable to
downtime and retrofitting the Garijp and Middenmeer Treatment Centre.
Production in Australia averaged 7,070 boe/d during the third quarter of
2013, which represented a 4% decrease compared to the second quarter of
2013, but a year-over-year increase of 19% compared to 5,958 boe/d in
the third quarter of 2012. Production volumes continue to reflect the
strong drilling results achieved from the two-well program completed
earlier in 2013 in which the new wells were brought on production at
restricted rates.
FINANCIAL REVIEW
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Net earnings
|
67,796
|
106,198
|
30,798
|
|
(36%)
|
120%
|
|
|
226,131
|
133,708
|
|
69%
|
Fund flows from operations
|
165,645
|
174,592
|
137,094
|
|
(5%)
|
21%
|
|
|
503,866
|
415,991
|
|
21%
|
Cash flow from operating activities
|
158,236
|
179,074
|
148,301
|
|
(12%)
|
7%
|
|
|
528,022
|
396,673
|
|
33%
|
Net debt
|
700,286
|
674,368
|
549,491
|
|
4%
|
27%
|
|
|
700,286
|
549,491
|
|
27%
|
Long-term debt
|
781,074
|
780,470
|
492,669
|
|
-
|
59%
|
|
|
781,074
|
492,669
|
|
59%
|
Ratio of net debt to annualized fund flows
|
|
|
|
|
|
|
|
|
|
|
|
|
from operations
|
1.1
|
1.0
|
1.0
|
|
10%
|
10%
|
|
|
1.0
|
1.0
|
|
-
|
Total net dividends, capital expenditures
|
|
|
|
|
|
|
|
|
|
|
|
|
and asset retirement obligations settled
|
|
|
|
|
|
|
|
|
|
|
|
|
% of fund flows from operations
|
109%
|
70%
|
107%
|
|
|
|
|
|
105%
|
100%
|
|
|
% of fund flows from operations
|
|
|
|
|
|
|
|
|
|
|
|
|
(excluding the Corrib project)
|
87%
|
55%
|
93%
|
|
|
|
|
|
89%
|
88%
|
|
|
Net earnings for the third quarter of 2013 decreased as compared to the
second quarter of 2013 primarily as a result of increases in unrealized
losses on derivative instruments and reduced unrealized foreign
exchange gains. The unrealized foreign exchange gain of $4.2 million
recorded in the third quarter of 2013 primarily resulted from the
impact of the appreciation of the Euro against the Canadian dollar and
the resultant impact on Vermilion's financial balances. The decrease
in net earnings quarter-over-quarter was partially offset by stronger
commodity pricing for crude oil.
Net earnings for the three and nine months ended September 30, 2013
increased as compared to the same periods in 2012 due to the increases
in operating income resulting from production growth in Canada, France
and Australia coupled with increases in the AECO and WTI reference
prices for both periods and Dated Brent crude oil price
quarter-over-quarter. Additionally, net earnings increased due to
unrealized foreign exchange gains recorded in the current periods and
decreases in unrealized losses on derivative instruments. The
unrealized foreign exchange gain of $29.7 million recorded in nine
months ended September 30, 2013 primarily resulted from the
appreciation of the Euro against the Canadian dollar and the resultant
impact on Vermilion's financial balances. The increase in net earnings
year-over-year was partially offset by increases in operating expense
in France as result of an inventory draw in the current year versus a
build in the nine months ended September 30, 2012.
Fund flows from operations for the third quarter of 2013 was 5% lower
($8.9 million) than the second quarter. This decrease was largely due
to increased current taxes in France as well as consolidated realized
foreign exchange and derivative losses of $1.2 million and $4.8
million, respectively, during the quarter. In addition, stronger WTI
and Dated Brent crude pricing also contributed favourably to fund flows
from operations, more than offsetting the impact of weaker AECO prices
for Canadian natural gas quarter-over-quarter.
Fund flows from operations for the three and nine months ended September
30, 2013 was 21% higher for both periods in 2013 as compared to the
same periods in 2012. The increases were largely the result of
quarter-over-quarter production growth in Canada, France and Australia
coupled with the stronger commodity pricing. On a year-to-date basis,
ending inventory decreased by 213,000 bbls in 2013 versus a decrease of
46,000 bbls in 2012, which resulted in increased sold volumes. The
increase in sold volumes coupled with higher base production growth led
to higher fund flows from operations year-over-year. While the Dated
Brent reference price declined by 3% from 2012, the impact of the
decline was entirely offset by increased realized prices for
Vermilion's production in Canada and the Netherlands.
Cash flow from operating activities for the third quarter of 2013
decreased as compared to the second quarter of 2013 due to the impact
of timing differences pertaining to working capital. Cash flow from
operating activities for the three and nine months ended September 30,
2013 increased as compared to the same periods in 2012 due to the
aforementioned increase in fund flows from operations. In addition,
timing differences pertaining to working capital for the nine month
period ended September 30, 2013 also contributed to the increase
year-over-year.
Vermilion continues to maintain a strong balance sheet, with a net debt
to annualized fund flows from operations of 1.0. Long-term debt as at
September 30, 2013 increased to $781.1 million from $642.0 million as
at December 31, 2012 as a result of increased borrowings on the
revolving credit facility to fund development capital expenditures in
Canada and Ireland. Canadian development activities continue to be
focused on the development of the Cardium light oil play. In Ireland,
development activities related to tunnelling, onshore pipelining,
offshore umbilical-laying and offshore seismic acquisition activities.
2013 capital spending also included drilling programs in Australia and
France. As capital expenditures and dividends paid exceeded fund flows
from operations, Vermilion ended the third quarter with net debt of
$700.3 million, an increase from $674.4 million as at June 30, 2013 and
$677.2 million as at December 31, 2012.
COMMODITY PRICES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Average reference prices
|
|
|
|
|
|
|
|
|
|
|
|
|
WTI (US $/bbl)
|
105.82
|
94.22
|
92.22
|
|
12%
|
15%
|
|
|
98.14
|
96.21
|
|
2%
|
Edmonton Sweet index (US $/bbl)
|
101.10
|
90.56
|
85.01
|
|
12%
|
19%
|
|
|
93.03
|
86.94
|
|
7%
|
Dated Brent (US $/bbl)
|
110.37
|
102.44
|
109.61
|
|
8%
|
1%
|
|
|
108.45
|
112.10
|
|
(3%)
|
AECO ($/GJ)
|
2.31
|
3.35
|
2.17
|
|
(31%)
|
6%
|
|
|
2.89
|
2.00
|
|
45%
|
Netherlands gas price ($/GJ)
|
9.94
|
10.14
|
9.06
|
|
(2%)
|
10%
|
|
|
10.17
|
9.38
|
|
8%
|
Netherlands gas price (€/GJ)
|
7.20
|
7.57
|
7.28
|
|
(5%)
|
(1%)
|
|
|
7.53
|
7.30
|
|
3%
|
Average realized prices ($/boe)
|
|
|
|
|
|
|
|
|
|
|
|
|
Canada
|
63.56
|
62.00
|
53.61
|
|
3%
|
19%
|
|
|
61.16
|
53.67
|
|
14%
|
France
|
107.08
|
98.04
|
104.95
|
|
9%
|
2%
|
|
|
104.29
|
106.00
|
|
(2%)
|
Netherlands
|
61.44
|
65.08
|
56.88
|
|
(6%)
|
8%
|
|
|
62.70
|
57.95
|
|
8%
|
Australia
|
120.95
|
111.54
|
114.44
|
|
8%
|
6%
|
|
|
117.65
|
117.40
|
|
-
|
Consolidated
|
86.10
|
80.21
|
80.35
|
|
7%
|
7%
|
|
|
83.10
|
79.83
|
|
4%
|
Production mix (% of production)
|
|
|
|
|
|
|
|
|
|
|
|
|
% priced with reference to WTI
|
24%
|
25%
|
23%
|
|
|
|
|
|
24%
|
23%
|
|
|
% priced with reference to AECO
|
17%
|
17%
|
16%
|
|
|
|
|
|
17%
|
17%
|
|
|
% priced with reference to European gas
|
14%
|
17%
|
17%
|
|
|
|
|
|
16%
|
17%
|
|
|
% priced with reference to Dated Brent
|
45%
|
41%
|
44%
|
|
|
|
|
|
43%
|
43%
|
|
|
Reference prices
During the third quarter of 2013, Dated Brent increased 8% while WTI
increased by 12% as compared to the second quarter. This increase in
crude oil prices was a result of supply disruptions in Libya and
intensified concerns over the conflict in Syria. Western Canadian
supply issues and increased rail capacity resulted in a further
narrowing of the differential for both WTI and the Edmonton Sweet index
versus Dated Brent (US$4.55 and US$9.27 per bbl, respectively, for the
second quarter of 2013 as compared to US$8.22 and US$11.88 per bbl,
respectively, for the second quarter of 2013).
The AECO reference price for the third quarter of 2013 decreased 31% as
compared to the second quarter of 2013. The significant
quarter-over-quarter decline occurred as a result of increased
short-term toll prices, which led to higher natural gas storage levels.
Realized pricing
The realized price of Vermilion's crude oil in Canada is directly linked
to WTI but is subject to market conditions in Western Canada. These
market conditions can result in fluctuations in the pricing
differential, as reflected by the Edmonton Sweet index price. The
realized price of Vermilion's NGLs in Canada is based on product
specific differentials pertaining to trading hubs in the U.S. The
realized price of Vermilion's natural gas in Canada is based on the
AECO spot price in Alberta.
Vermilion's crude oil in France and Australia is priced with reference
to Dated Brent.
As of January 1, 2013, the price of Vermilion's natural gas in the
Netherlands is now based on the TTF day-ahead index, as determined on
the Title Transfer Facility Virtual Trading Point operated by Dutch TSO
Gas Transport Services, plus various fees. GasTerra, a state owned
entity, continues to purchase all natural gas produced by Vermilion in
the Netherlands. Prior to 2013, the natural gas price received by
Vermilion in the Netherlands was calculated using a trailing average of
Dated Brent and the natural gas prices from European trading hubs.
Vermilion's average realized prices will differ from their corresponding
average reference prices due to a number of factors, including the
timing of the sale of production, differences in the quality of
production and point of settlement. In Canada, average realized prices
are also impacted by the production mix of crude oil, NGLs and natural
gas.
CAPITAL EXPENDITURES AND ACQUISITIONS
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
By classification
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Drilling and development
|
135,110
|
75,005
|
96,212
|
|
|
389,635
|
262,064
|
Dispositions
|
-
|
-
|
-
|
|
|
(8,627)
|
-
|
Exploration and evaluation
|
551
|
3,113
|
10,043
|
|
|
13,240
|
33,439
|
Capital expenditures
|
135,661
|
78,118
|
106,255
|
|
|
394,248
|
295,503
|
|
|
|
|
|
|
|
|
Property acquisition
|
7,586
|
-
|
-
|
|
|
7,586
|
106,184
|
Acquisitions
|
7,586
|
-
|
-
|
|
|
7,586
|
106,184
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
By category
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Land (net of dispositions)
|
(4,450)
|
2,307
|
7,666
|
|
|
(7,641)
|
46,046
|
Seismic
|
5,284
|
5,569
|
2,653
|
|
|
14,666
|
4,779
|
Drilling and completion
|
63,590
|
20,235
|
55,320
|
|
|
210,010
|
138,487
|
Production equipment and facilities
|
47,665
|
40,819
|
34,691
|
|
|
138,426
|
86,164
|
Recompletions
|
15,650
|
4,510
|
2,956
|
|
|
24,291
|
7,004
|
Other
|
7,922
|
4,678
|
2,969
|
|
|
14,496
|
13,023
|
Capital expenditures
|
135,661
|
78,118
|
106,255
|
|
|
394,248
|
295,503
|
Acquisitions
|
7,586
|
-
|
-
|
|
|
7,586
|
106,184
|
Total capital expenditures and acquisitions
|
143,247
|
78,118
|
106,255
|
|
|
401,834
|
401,687
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
By country
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Canada
|
70,359
|
17,578
|
63,701
|
|
|
174,573
|
191,139
|
France
|
23,664
|
23,223
|
10,416
|
|
|
68,479
|
132,539
|
Netherlands
|
8,316
|
4,157
|
5,257
|
|
|
12,845
|
13,206
|
Australia
|
5,880
|
8,282
|
9,721
|
|
|
69,511
|
24,132
|
Ireland
|
35,028
|
24,878
|
17,160
|
|
|
76,426
|
40,671
|
Capital expenditures for the third quarter of 2013 were higher than both
the second quarter of 2013 and the third quarter of 2012. The
increase was the result of higher drilling activity in Canada, and
increased activities related to tunnelling, onshore pipelining,
offshore umbilical-laying, offshore seismic acquisition and workover
activities in Ireland. These increases were partially offset by
reduced land purchases in Canada in the third quarter of 2013 compared
to the same period in 2012. In Canada, Vermilion participated in the
drilling of 21 (16.3 net) wells during the third quarter of 2013 as
compared to three (1.9 net) wells during the second quarter and 16
(11.5 net) wells during the third quarter of 2012.
Capital expenditures for the nine months ended September 30, 2013 were
higher than the same period in 2012 largely due to the aforementioned
increase quarter-over-quarter coupled with 2013 drilling activity in
France and Australia. In France, Vermilion participated in the
drilling of five (5.0 net) wells for 2013, while in the same period in
2012, France had focused on its annual workover and recompletion
activities as well as integrating its 2012 acquisitions. In Australia,
Vermilion participated in the drilling of a two-well (2.0 net)
sidetrack program during the first half of 2013. During the same
period in 2012 Australia had focused on preparations and permitting
activities pertaining to the sidetrack program in 2013.
PETROLEUM AND NATURAL GAS SALES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By product
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe and per mcf)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Crude oil & NGLs
|
284,484
|
255,183
|
243,471
|
|
11%
|
17%
|
|
|
799,165
|
716,888
|
|
11%
|
Per boe
|
108.87
|
98.95
|
100.70
|
|
10%
|
8%
|
|
|
103.95
|
102.32
|
|
2%
|
Natural gas
|
42,701
|
56,783
|
41,367
|
|
(25%)
|
3%
|
|
|
149,562
|
124,982
|
|
20%
|
Per mcf
|
6.00
|
7.22
|
6.12
|
|
(17%)
|
(2%)
|
|
|
6.68
|
5.89
|
|
13%
|
Petroleum and natural gas sales
|
327,185
|
311,966
|
284,838
|
|
5%
|
15%
|
|
|
948,727
|
841,870
|
|
13%
|
Per boe
|
86.10
|
80.21
|
80.35
|
|
7%
|
7%
|
|
|
83.10
|
79.83
|
|
4%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By country
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Canada
|
100,000
|
100,950
|
71,268
|
|
(1%)
|
40%
|
|
|
284,638
|
226,726
|
|
26%
|
Per boe
|
63.56
|
62.00
|
53.61
|
|
3%
|
19%
|
|
|
61.16
|
53.67
|
|
14%
|
France
|
120,574
|
100,418
|
102,369
|
|
20%
|
18%
|
|
|
342,558
|
300,708
|
|
14%
|
Per boe
|
107.08
|
98.04
|
104.95
|
|
9%
|
2%
|
|
|
104.29
|
106.00
|
|
(2%)
|
Netherlands
|
27,382
|
38,316
|
30,386
|
|
(29%)
|
(10%)
|
|
|
100,119
|
92,268
|
|
9%
|
Per boe
|
61.44
|
65.08
|
56.88
|
|
(6%)
|
8%
|
|
|
62.70
|
57.95
|
|
8%
|
Australia
|
79,229
|
72,282
|
80,815
|
|
10%
|
(2%)
|
|
|
221,412
|
222,168
|
|
-
|
Per boe
|
120.95
|
111.54
|
114.44
|
|
8%
|
6%
|
|
|
117.65
|
117.40
|
|
-
|
Vermilion's consolidated petroleum and natural gas sales for the third
quarter of 2013 were higher than second quarter of 2013 as a result of
increased crude oil sales volumes in France and higher realized pricing
for crude oil. Higher crude oil sales were offset by a decrease in
natural gas sales as a result of lower natural gas production and lower
AECO pricing. Petroleum and natural gas sales for the third quarter of
2013 were higher than the same period in 2012 as a result of increased
sales volumes and favourable commodity prices.
Vermilion's consolidated petroleum and natural gas sales for the nine
months ended September 30, 2013 were higher than the same period in
2012. This increase was the result of increased sales volumes in all
of Vermilion's jurisdictions, higher North American commodity prices,
partially offset by lower Dated Brent pricing year-over-year.
CRUDE OIL INVENTORY
Vermilion carries an inventory of crude oil in France and Australia,
which is a result of timing differences between production and sales.
The following table summarizes the changes in Vermilion's crude oil
inventory positions:
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
(mbbls)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
France
|
|
|
|
|
|
|
|
|
Opening crude oil inventory
|
202
|
218
|
271
|
|
|
354
|
187
|
|
Adjustments
|
-
|
-
|
-
|
|
|
5
|
-
|
|
Crude oil production
|
1,069
|
945
|
899
|
|
|
2,945
|
2,737
|
|
Crude oil sales
|
(1,045)
|
(961)
|
(924)
|
|
|
(3,078)
|
(2,678)
|
|
Closing crude oil inventory
|
226
|
202
|
246
|
|
|
226
|
246
|
Australia
|
|
|
|
|
|
|
|
|
Opening crude oil inventory
|
187
|
165
|
275
|
|
|
268
|
222
|
|
Crude oil production
|
650
|
670
|
548
|
|
|
1,796
|
1,787
|
|
Crude oil sales
|
(654)
|
(648)
|
(706)
|
|
|
(1,881)
|
(1,892)
|
|
Closing crude oil inventory
|
183
|
187
|
117
|
|
|
183
|
117
|
Inventory held on the balance sheet as at September 30, 2013 was
comprised of the following components:
($M)
|
|
|
|
|
France
|
Australia
|
Total
|
Operating expense
|
|
|
|
|
3,813
|
4,482
|
8,295
|
Royalties
|
|
|
|
|
1,332
|
-
|
1,332
|
Depletion
|
|
|
|
|
4,796
|
3,736
|
8,532
|
|
|
|
|
|
9,941
|
8,218
|
18,159
|
DERIVATIVE INSTRUMENTS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Realized loss (gain) on
|
|
|
|
|
|
|
|
|
|
|
|
|
derivative instruments
|
4,765
|
(1,770)
|
1,869
|
|
(369%)
|
155%
|
|
|
5,782
|
11,178
|
|
(48%)
|
Per boe
|
1.25
|
(0.46)
|
0.53
|
|
(372%)
|
136%
|
|
|
0.51
|
1.06
|
|
(52%)
|
The realized loss on derivative instruments for the third quarter of
2013 resulted from payments made on our crude oil derivative
instruments as the reference prices exceeded the ceiling and swap
prices on those instruments. This realized loss was partially offset
by a $1.0 million gain on our natural gas derivative instruments.
The realized loss for the nine months ended September 30, 2013 was lower
than the realized loss for the same period in 2012 due to the gains
realized in the second quarter of 2013 and the absence of premiums paid
in 2012 on funded derivatives.
The following tables summarize Vermilion's outstanding risk management
positions as at September 30, 2013:
|
Note
|
Daily Volume
|
Strike Price(s)
|
Crude Oil
|
|
|
|
WTI - Collar
|
|
|
|
January 2014 - March 2014
|
|
1,000 bbl/d
|
97.50 - 104.69 USD $
|
WTI - Swap
|
|
|
|
January 2013 - December 2013
|
|
2,000 bbl/d
|
93.04 USD $
|
July 2013 - December 2013
|
|
500 bbl/d
|
94.98 USD $
|
October 2013 - December 2013
|
|
500 bbl/d
|
101.00 CAD $
|
October 2013 - December 2013
|
|
1,300 bbl/d
|
100.50 USD $
|
January 2014 - March 2014
|
|
500 bbl/d
|
101.22 USD $
|
January 2014 - March 2014
|
1
|
250 bbl/d
|
105.45 USD $
|
January 2014 - June 2014
|
|
250 bbl/d
|
100.05 USD $
|
January 2014 - June 2014
|
2
|
250 bbl/d
|
103.27 USD $
|
Dated Brent - Collar
|
|
|
|
January 2013 - December 2013
|
|
3,500 bbl/d
|
96.14 - 107.34 USD $
|
July 2013 - December 2013
|
|
1,000 bbl/d
|
97.50 - 109.10 USD $
|
October 2013 - December 2013
|
|
3,750 bbl/d
|
102.73 - 110.56 USD $
|
January 2014 - March 2014
|
|
1,500 bbl/d
|
103.33 - 110.00 USD $
|
Dated Brent - Swap
|
|
|
|
January 2014 - March 2014
|
|
1,250 bbl/d
|
107.51 USD $
|
January 2014 - June 2014
|
|
500 bbl/d
|
107.89 USD $
|
MSW - Fixed Price Differential (Physical)
|
|
|
|
January 2013 - December 2013
|
|
2,000 bbl/d
|
WTI less 4.50 USD $
|
October 2013 - December 2013
|
|
500 bbl/d
|
WTI less 8.50 USD $
|
MSW - Fixed Price Sale (Physical)
|
|
|
|
January 2014 - March 2014
|
|
500 bbl/d
|
92.03 CAD $
|
|
|
|
|
Canadian Natural Gas
|
|
|
|
AECO - Collar
|
|
|
|
April 2013 - October 2013
|
|
3,500 GJ/d
|
3.05 - 3.66 CAD $
|
April 2013 - December 2013
|
|
5,000 GJ/d
|
2.93 - 3.52 CAD $
|
October 2013 - December 2013
|
|
2,500 GJ/d
|
2.85 - 3.56 CAD $
|
January 2014 - December 2014
|
|
2,500 GJ/d
|
3.15 - 3.86 CAD $
|
AECO - Swap
|
|
|
|
May 2013 - December 2013
|
|
2,500 GJ/d
|
3.65 CAD $
|
AECO - Collar (Physical)
|
3
|
|
|
April 2012 - March 2014
|
|
5,500 GJ/d
|
2.60 - 3.78 CAD $
|
June 2012 - March 2014
|
|
3,000 GJ/d
|
2.30 - 3.75 CAD $
|
|
|
|
|
European Natural Gas
|
|
|
|
TTF - Swap
|
|
|
|
May 2013 - December 2013
|
|
3,600 GJ/d
|
7.41 EUR €
|
June 2013 - December 2013
|
|
14,400 GJ/d
|
7.44 EUR €
|
October 2013 - December 2013
|
|
1,800 GJ/d
|
7.53 EUR €
|
1
|
Prior to the expiration of this swap, the counterparty has the option to
extend the swap to June 30, 2014 at the contracted volume and price.
|
2
|
Prior to the expiration of this swap, the counterparty has the option to
extend the swap to December 31, 2014 at the contracted volume and
price.
|
3
|
Physical AECO collars have a funded cost of $0.10/GJ.
|
From time to time Vermilion enters into new risk management positions.
Up-to-date information regarding outstanding risk management positions
is available on Vermilion's website at www.vermilionenergy.com/ir/hedging.cfm.
ROYALTIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By product
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe and per mcf)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Crude oil & NGLs
|
17,919
|
15,353
|
12,087
|
|
17%
|
48%
|
|
|
48,082
|
39,570
|
|
22%
|
Per boe
|
6.86
|
5.95
|
5.00
|
|
15%
|
37%
|
|
|
6.25
|
5.65
|
|
11%
|
Natural gas
|
811
|
447
|
276
|
|
81%
|
194%
|
|
|
2,238
|
576
|
|
289%
|
Per mcf
|
0.11
|
0.06
|
0.04
|
|
83%
|
175%
|
|
|
0.10
|
0.03
|
|
233%
|
Royalties
|
18,730
|
15,800
|
12,363
|
|
19%
|
52%
|
|
|
50,320
|
40,146
|
|
25%
|
Per boe
|
4.93
|
4.06
|
3.49
|
|
21%
|
41%
|
|
|
4.41
|
3.81
|
|
16%
|
% of petroleum and natural gas sales
|
5.7%
|
5.1%
|
4.3%
|
|
|
|
|
|
5.3%
|
4.8%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By country
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Canada
|
11,156
|
9,707
|
7,081
|
|
15%
|
58%
|
|
|
29,852
|
24,266
|
|
23%
|
Per boe
|
7.09
|
5.96
|
5.33
|
|
19%
|
33%
|
|
|
6.41
|
5.74
|
|
12%
|
% of petroleum and natural gas sales
|
11.2%
|
9.6%
|
9.9%
|
|
|
|
|
|
10.5%
|
10.7%
|
|
|
France
|
7,574
|
6,093
|
5,282
|
|
24%
|
43%
|
|
|
20,468
|
15,880
|
|
29%
|
Per boe
|
6.73
|
5.95
|
5.42
|
|
13%
|
24%
|
|
|
6.23
|
5.60
|
|
11%
|
% of petroleum and natural gas sales
|
6.3%
|
6.1%
|
5.2%
|
|
|
|
|
|
6.0%
|
5.3%
|
|
|
In Canada, royalties as a percentage of sales for the third quarter of
2013 increased to 11.2% as compared to 9.6% for the second quarter of
2013 and 9.9% for the third quarter of 2012. The slightly higher
percentage in the current quarter is associated with the timing of
placing Cardium wells on production due to the associated royalty
incentive on initial production volumes. On a year-over-year basis,
royalties as a percentage of sales remained consistent.
In France, royalties as a percentage of sales for the third quarter of
2013 remained relatively consistent with the prior quarter. As
compared to the same periods of the prior year, royalties as a
percentage of sales for the three and nine months ended September 30,
2013 increased due to a higher proportion of R31 royalty associated
with incremental production from a 2012 French acquisition as well as
new wells that have come on production in 2013. Although the RCDM
component of the royalties levied in France is based on units of
production and is not subject to changes in commodity prices, certain
wells are also subject to the R31 royalty which is based on revenue.
Production in the Netherlands and Australia is not subject to royalties.
OPERATING EXPENSE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By product
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe and per mcf)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
2012
|
Crude oil & NGLs
|
34,275
|
35,682
|
36,889
|
|
(4%)
|
(7%)
|
|
|
111,812
|
102,400
|
|
9%
|
Per boe
|
13.12
|
13.84
|
15.26
|
|
(5%)
|
(14%)
|
|
|
14.54
|
14.62
|
|
(1%)
|
Natural gas
|
11,971
|
12,400
|
10,141
|
|
(3%)
|
18%
|
|
|
35,091
|
32,408
|
|
8%
|
Per mcf
|
1.68
|
1.58
|
1.50
|
|
6%
|
12%
|
|
|
1.57
|
1.53
|
|
3%
|
Operating
|
46,246
|
48,082
|
47,030
|
|
(4%)
|
(2%)
|
|
|
146,903
|
134,808
|
|
9%
|
Per boe
|
12.17
|
12.36
|
13.27
|
|
(2%)
|
(8%)
|
|
|
12.87
|
12.78
|
|
1%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By country
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
2012
|
Canada
|
12,770
|
15,975
|
13,420
|
|
(20%)
|
(5%)
|
|
|
42,586
|
40,904
|
|
4%
|
Per boe
|
8.12
|
9.81
|
10.10
|
|
(17%)
|
(20%)
|
|
|
9.15
|
9.68
|
|
(5%)
|
France
|
14,599
|
16,935
|
12,351
|
|
(14%)
|
18%
|
|
|
51,473
|
41,208
|
|
25%
|
Per boe
|
12.97
|
16.53
|
12.66
|
|
(22%)
|
2%
|
|
|
15.67
|
14.53
|
|
8%
|
Netherlands
|
5,209
|
5,260
|
3,870
|
|
(1%)
|
35%
|
|
|
14,438
|
13,436
|
|
7%
|
Per boe
|
11.69
|
8.93
|
7.24
|
|
31%
|
61%
|
|
|
9.04
|
8.44
|
|
7%
|
Australia
|
13,668
|
9,912
|
17,389
|
|
38%
|
(21%)
|
|
|
38,406
|
39,260
|
|
(2%)
|
Per boe
|
20.86
|
15.30
|
24.62
|
|
36%
|
(15%)
|
|
|
20.41
|
20.75
|
|
(2%)
|
In Canada, third quarter operating expense of $12.8 million was lower
than the previous quarter's $16.0 million due to lower electricity
costs, less emulsion trucking and reduced lease mat rentals. This
resulted in a decrease to $8.12 per boe for the current quarter versus
$9.81 per boe for the prior quarter. Operating expense for the third
quarter of 2013 was relatively consistent with the $13.4 million for
the same quarter of the previous year. The year-over-year increase in
operating expense from $40.9 million to $42.6 million was related to
higher fuel and electricity costs and gas gathering fees as well as
increased preventative maintenance work. Operating expense per boe
decreased for the three and nine months ended September 30, 2013 as
compared to the same periods of the prior year due to higher current
year volumes.
In the Netherlands, operating expense for the three and nine months
ended September 30, 2013 increased against the comparable prior year
periods due to the timing of maintenance activity. The higher level of
expense resulted in an increase in operating expense per boe for the
current year as compared to the same periods of 2012. Operating
expense per boe increased for the third quarter of 2013 as compared to
the second quarter despite a similar level of expense due to lower
quarter-over-quarter volumes.
As a result of shipment timing, Vermilion carries an inventory of crude
oil in France and Australia. When crude oil is inventoried, the
related costs of production are deferred and carried on the balance
sheet. When the inventory is subsequently sold, those costs are
expensed in the period of sale. As a result, the timing of inventory
builds and draws results in fluctuations in the amount of operating
expense recognized for a given period.
In France, the quarter-over-quarter decrease in operating expense was
primarily the result of reduced maintenance activity. The increase in
operating expense for the three and nine months ended September 30,
2013 as compared to the same periods of the prior year is associated
with incremental costs related to a December 2012 acquisition as well
as additional repair and maintenance activities year-over-year. Higher
operating expense resulted in an increase on a per boe basis for the
three and nine months ended September 30, 2013 despite significantly
higher volumes.
In Australia, operating expense for the third quarter of 2013 increased
as compared to the previous quarter due primarily to increased repairs
and maintenance activity. Operating expense for the third quarter of
2013 decreased as compared to the third quarter of 2012 due to a crude
oil inventory draw in the prior year. Operating expense for the nine
months ended September 30, 2013 remained relatively consistent with the
same period of the prior year. The variance in expense per boe for the
third quarter of 2013 as compared to the prior quarter and the third
quarter of 2012 is largely due to the timing of major project work. On
a year-to-date basis, operating expense per boe in 2013 remained
relatively consistent with the prior year.
TRANSPORTATION EXPENSE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By country
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Canada
|
3,272
|
2,611
|
2,005
|
|
25%
|
63%
|
|
|
8,152
|
6,399
|
|
27%
|
Per boe
|
2.08
|
1.60
|
1.51
|
|
30%
|
38%
|
|
|
1.75
|
1.51
|
|
16%
|
France
|
2,713
|
2,416
|
1,840
|
|
12%
|
47%
|
|
|
7,883
|
6,382
|
|
24%
|
Per boe
|
2.41
|
2.36
|
1.89
|
|
2%
|
28%
|
|
|
2.40
|
2.25
|
|
7%
|
Ireland
|
564
|
1,626
|
1,899
|
|
(65%)
|
(70%)
|
|
|
3,808
|
5,874
|
|
(35%)
|
Transportation
|
6,549
|
6,653
|
5,744
|
|
(2%)
|
14%
|
|
|
19,843
|
18,655
|
|
6%
|
Per boe
|
1.72
|
1.71
|
1.62
|
|
1%
|
6%
|
|
|
1.74
|
1.77
|
|
(2%)
|
Transportation expense in Canada and France for the three and nine
months ended September 30, 2013 was higher compared to the expense for
the same periods in 2012 and the second quarter of 2013. These
increases resulted from higher sales volumes in France and increased
crude oil production subject to transportation costs in Canada.
On a consolidated basis, the increases in transportation expense in
Canada and France were offset by lower payments under the ship or pay
agreement related to the Corrib project.
GENERAL AND ADMINISTRATION EXPENSE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
General and administration
|
12,033
|
11,313
|
12,669
|
|
6%
|
(5%)
|
|
|
35,956
|
34,885
|
|
3%
|
Per boe
|
3.17
|
2.91
|
3.57
|
|
9%
|
(11%)
|
|
|
3.15
|
3.31
|
|
(5%)
|
The minor variance in general administration expense for the third
quarter of 2013 versus the comparative quarter and year-over-year is
due to the timing of corporate expenditures. For the nine months ended
September 30, 2013, general and administration expense was slightly
higher than the corresponding period in 2012 as a result of increased
staffing levels required to support Vermilion's operational activities.
EQUITY BASED COMPENSATION EXPENSE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Equity based compensation
|
12,779
|
10,724
|
8,704
|
|
19%
|
47%
|
|
|
39,639
|
28,620
|
|
39%
|
Per boe
|
3.36
|
2.76
|
2.46
|
|
22%
|
37%
|
|
|
3.47
|
2.71
|
|
28%
|
Equity based compensation expense relates to non-cash compensation
expense attributable to long-term incentives granted to directors,
officers and employees under the Vermilion Incentive Plan ("VIP"). The
expense is recognized over the vesting period based on the grant date
fair value of awards, adjusted for the ultimate number of awards that
actually vest as determined by the Company's achievement of performance
conditions.
Equity based compensation expense for the three and nine months ended
September 30, 2013 was higher than the same periods in 2012. The
year-over-year increases resulted from the revision of future
performance condition assumptions starting in the fourth quarter of
2012 and higher staffing levels required to support Vermilion's
operating activities.
INTEREST EXPENSE
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Interest expense
|
10,109
|
9,336
|
7,229
|
|
8%
|
40%
|
|
|
28,134
|
19,930
|
|
41%
|
Per boe
|
2.66
|
2.40
|
2.04
|
|
11%
|
30%
|
|
|
2.46
|
1.89
|
|
30%
|
Interest expense for the three and nine months ended September 30, 2013
increased versus the comparable periods due to increased borrowings
under Vermilion's revolving credit facility.
DEPLETION AND DEPRECIATION, ACCRETION, IMPAIRMENTS AND GAIN ON
ACQUISITION
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Depletion and depreciation
|
78,826
|
78,418
|
76,941
|
|
1%
|
2%
|
|
|
238,692
|
229,301
|
|
4%
|
Per boe
|
20.74
|
20.16
|
21.70
|
|
3%
|
(4%)
|
|
|
20.91
|
21.74
|
|
(4%)
|
Accretion
|
6,214
|
6,000
|
5,891
|
|
4%
|
5%
|
|
|
18,038
|
16,921
|
|
7%
|
Per boe
|
1.64
|
1.54
|
1.66
|
|
6%
|
(1%)
|
|
|
1.58
|
1.60
|
|
(1%)
|
Impairments
|
-
|
-
|
-
|
|
-
|
-
|
|
|
-
|
65,800
|
|
(100%)
|
Per boe
|
-
|
-
|
-
|
|
-
|
-
|
|
|
-
|
6.24
|
|
(100%)
|
Gain on acquisition
|
-
|
-
|
-
|
|
-
|
-
|
|
|
-
|
(45,309)
|
|
(100%)
|
Per boe
|
-
|
-
|
-
|
|
-
|
-
|
|
|
-
|
(4.30)
|
|
(100%)
|
Depletion and depreciation expense for the third quarter of 2013 was
relatively consistent with both the second quarter of 2013 and the
third quarter of 2012. Depletion and depreciation expense for the nine
months ended September 30, 2013 was 4% higher than the same period in
2012 primarily due to increased production year-over-year.
Accretion expense for the third quarter of 2013 was relatively
consistent with both the second quarter of 2013 and the third quarter
of 2012. Accretion expense was higher for the nine months ended
September 30, 2013 as compared to the same period in 2012 as a result
of additional accretion expense pertaining to asset retirement
obligations recorded on new wells drilled during the year and an
acquisition in France late in 2012.
The impairment losses for the nine months ended September 30, 2012
pertained to impairment losses recorded on Vermilion's conventional
deep gas and shallow coal bed methane natural gas plays. These
impairment charges were the result of significant declines in the
forward pricing assumptions for natural gas in Canada.
The gain on acquisition for the nine months ended September 30, 2012
related to Vermilion's acquisition of certain working interests in the
Paris and Aquitaine basins. The gain arose as a result of the increase
in the fair value of the acquired petroleum and natural gas reserves
from the time when the acquisition was negotiated to the acquisition
date. The increase resulted from a change in the underlying commodity
price forecasts used to determine the fair value of the acquired
reserves.
TAXES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By classification
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Current taxes before PRRT
|
46,453
|
36,719
|
38,784
|
|
27%
|
20%
|
|
|
118,729
|
100,373
|
|
18%
|
Per boe
|
12.22
|
9.44
|
10.94
|
|
29%
|
12%
|
|
|
10.40
|
9.52
|
|
9%
|
PRRT
|
15,649
|
12,590
|
22,743
|
|
24%
|
(31%)
|
|
|
39,392
|
58,472
|
|
(33%)
|
Per boe
|
4.12
|
3.24
|
6.42
|
|
27%
|
(36%)
|
|
|
3.45
|
5.54
|
|
(38%)
|
Current taxes
|
62,102
|
49,309
|
61,527
|
|
26%
|
1%
|
|
|
158,121
|
158,845
|
|
0%
|
Per boe
|
16.34
|
12.68
|
17.36
|
|
29%
|
(6%)
|
|
|
13.85
|
15.06
|
|
(8%)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
% change
|
|
|
Nine Months Ended
|
|
% change
|
By country
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
Q3/13 vs.
|
Q3/13 vs.
|
|
|
Sept 30,
|
Sept 30,
|
|
2013 vs.
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
Q2/13
|
Q3/12
|
|
|
2013
|
2012
|
|
2012
|
Canada
|
260
|
328
|
36
|
|
(21%)
|
622%
|
|
|
839
|
1,323
|
|
(37%)
|
Per boe
|
0.17
|
0.20
|
0.03
|
|
(15%)
|
467%
|
|
|
0.18
|
0.31
|
|
(42%)
|
France
|
31,717
|
16,124
|
21,051
|
|
97%
|
51%
|
|
|
66,500
|
49,671
|
|
34%
|
Per boe
|
28.17
|
15.74
|
21.58
|
|
79%
|
31%
|
|
|
20.25
|
17.51
|
|
16%
|
Netherlands
|
6,810
|
9,621
|
9,614
|
|
(29%)
|
(29%)
|
|
|
25,865
|
24,546
|
|
5%
|
Per boe
|
15.28
|
16.34
|
18.00
|
|
(6%)
|
(15%)
|
|
|
16.20
|
15.42
|
|
5%
|
Australia
|
23,315
|
23,236
|
30,826
|
|
-
|
(24%)
|
|
|
64,917
|
83,305
|
|
(22%)
|
Per boe
|
35.59
|
35.86
|
43.66
|
|
(1%)
|
(18%)
|
|
|
34.49
|
44.02
|
|
(22%)
|
Vermilion pays current taxes in France, the Netherlands and Australia.
Corporate income taxes in France and the Netherlands apply to taxable
income after eligible deductions. In France, taxable income is taxed
at a rate of approximately 34.4%, plus an additional temporary surtax
tax of 5% levied until 2014 for companies which have annual revenue in
excess of €250 million. Vermilion is therefore taxable in France at a
statutory rate of 36.1% until 2014. In the Netherlands, taxable income
is taxed at a rate of approximately 46%. As a function of the impact
of Vermilion's Canadian tax pools, the Company does not presently pay
current taxes in Canada. The Canadian segment includes holding
companies that pay current taxes in foreign jurisdictions.
During the second half of 2013, the France government proposed changes
to corporate tax legislation that could lead to increases in current
tax for companies operating in France. One of the proposals includes
an increase in the temporary surtax from 5% currently to 10.7% (with
the surtax levied as a percent of base corporate income tax payable).
The new surtax rate would be applicable for companies which have annual
revenue in excess of €250 million and would effectively increase the
statutory rate applicable to Vermilion's French operations from the
36.1% to 38.0%, with retrospective application to January 1, 2013.
Another proposal adds a new test to the existing rules governing
interest deductions for related party financing. Under the proposed
rule, interest deductions would be allowed only if the French borrower
demonstrates that the lender is subject to corporate tax on interest
income that equals 25% or more of the corporate tax that would
otherwise be due under French tax rules. This proposal, among other
proposed changes, may reduce the effectiveness of Vermilion's existing
international corporate financing structures and could result in a
reduction of certain eligible deductions in our French operating
companies.
The Company has been in receipt of tax assessments in France for certain
prior periods. A provision for the assessments has been recorded and
the Company has entered into discussions with the tax authorities in
France regarding the assessments.
In Australia, current taxes include both corporate income taxes and
PRRT. Corporate income taxes are applied at a rate of approximately
30% on taxable income after eligible deductions, which include PRRT.
PRRT is a profit based tax applied at a rate of 40% on sales less
eligible expenditures, including operating expenses and capital
expenditures.
Current taxes for the third quarter of 2013 were higher than the second
quarter of 2013 and the same period in 2012 due in part to higher taxes
in France as a result of prior periods assessments from the French tax
authority as well as higher petroleum and natural gas sales. Partially
offsetting the impact of higher sales was the use of tax pools in
Canada, which will remain non-taxable for a number of years.
Current taxes for the three and nine months ended September 30, 2013 was
consistent with the same period in 2012 despite higher petroleum and
natural gas sales and current taxes in France due to higher capital
expenditures during the first half of 2013 in Australia, which resulted
in decreased PRRT.
OTHER EXPENSE (INCOME)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Other expense (income)
|
55
|
271
|
(277)
|
|
|
259
|
8,291
|
Per boe
|
0.01
|
0.07
|
(0.08)
|
|
|
0.02
|
0.79
|
Other expense for the nine months ended September 30, 2012 was comprised
primarily of $8.5 million relating to transfer taxes paid to regulatory
authorities in France pursuant to the first quarter of 2012 acquisition
of certain working interests in six producing fields located in the
Paris and Aquitaine basins.
FOREIGN EXCHANGE
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
Sept 30,
|
June 30,
|
Sept 30,
|
|
|
Sept 30,
|
Sept 30,
|
($M except per boe)
|
2013
|
2013
|
2012
|
|
|
2013
|
2012
|
Unrealized foreign exchange (gain) loss
|
(4,232)
|
(28,025)
|
6,740
|
|
|
(29,738)
|
18,223
|
Per boe
|
(1.11)
|
(7.21)
|
1.89
|
|
|
(2.60)
|
1.73
|
Realized foreign exchange loss (gain)
|
1,227
|
(1,272)
|
(410)
|
|
|
572
|
(345)
|
Per boe
|
0.32
|
(0.33)
|
(0.11)
|
|
|
0.05
|
(0.03)
|
Foreign exchange (gain) loss
|
(3,005)
|
(29,297)
|
6,330
|
|
|
(29,166)
|
17,878
|
Per boe
|
(0.79)
|
(7.54)
|
1.78
|
|
|
(2.55)
|
1.70
|
As a result of Vermilion's international operations, Vermilion conducts
business in currencies other than the Canadian dollar and has monetary
assets and liabilities (including cash, receivables, payables,
derivative assets and liabilities, and intercompany loans) denominated
in such currencies. Vermilion's exposure to foreign currencies
includes the U.S. Dollar, the Euro and the Australian Dollar.
Foreign exchange gains and losses are comprised of both unrealized and
realized amounts. Unrealized foreign exchange gains and losses are the
result of translating monetary assets and liabilities held in
non-functional currencies to the respective functional currencies of
Vermilion and its subsidiaries. Realized gains and losses are the
result of foreign exchange fluctuations and the timing of payments on
transactions conducted in non-functional currencies and as such are
subject to fluctuations.
For the three and nine months ended September 30, 2013, the unrealized
foreign exchange gain primarily resulted from the impact of the
appreciation of the Euro against the Canadian dollar and the resultant
impact on Vermilion's financial balances.
SUMMARY OF RESULTS
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Sept 30,
|
Jun 30,
|
Mar 31,
|
Dec 31,
|
Sept 30,
|
Jun 30,
|
Mar 31,
|
Dec 31,
|
($M except per share)
|
2013
|
2013
|
2013
|
2012
|
2012
|
2012
|
2012
|
2011
|
Petroleum and natural gas sales
|
327,185
|
311,966
|
309,576
|
241,233
|
284,838
|
246,544
|
310,488
|
275,172
|
Net earnings (loss)
|
67,796
|
106,198
|
52,137
|
56,914
|
30,798
|
37,816
|
65,094
|
(30,243)
|
Net earnings (loss) per share
|
|
|
|
|
|
|
|
|
|
Basic
|
0.67
|
1.05
|
0.53
|
0.58
|
0.31
|
0.39
|
0.67
|
(0.32)
|
|
Diluted
|
0.66
|
1.04
|
0.51
|
0.57
|
0.31
|
0.38
|
0.66
|
(0.32)
|
The fluctuations in Vermilion's petroleum and natural gas sales and net
earnings (loss) from quarter-to-quarter are primarily caused by
variations in sales volumes, crude oil and natural gas prices and the
impact of royalties and tax legislation in the jurisdictions in which
Vermilion operates. In addition, changes in foreign exchange rates may
result in unrealized gains and losses on Vermilion's financial balances
held in foreign currencies while changes in petroleum and natural gas
prices may impact gains and losses on derivative instruments and may
result in impairment charges or the reversal of impairment charges
incurred in previous periods.
LIQUIDITY AND CAPITAL RESOURCES
Vermilion's net debt as at September 30, 2013 was $700.3 million
compared to $677.2 million as at December 31, 2012.
Long-term debt was comprised of the following:
|
Annualized Interest Rate
|
|
|
As At
|
|
Sept 30,
|
Dec 31,
|
|
|
Sept 30,
|
Dec 31,
|
($M)
|
2013
|
2012
|
|
|
2013
|
2012
|
Revolving credit facility
|
3.3%
|
3.3%
|
|
|
558,171
|
419,784
|
Senior unsecured notes
|
6.5%
|
6.5%
|
|
|
222,903
|
222,238
|
Long-term debt
|
4.3%
|
4.7%
|
|
|
781,074
|
642,022
|
Revolving Credit Facility
At September 30, 2013, Vermilion had in place a bank revolving credit
facility totalling $1.2 billion, of which approximately $558.2 million
was drawn. The facility, which matures on May 31, 2016, is fully
revolving up to the date of maturity.
The facility is extendable from time to time, but not more than once per
year, for a period not longer than three years, at the option of the
lenders and upon notice from Vermilion. If no extension is granted by
the lenders, the amounts owing pursuant to the facility are repayable
on the maturity date. This facility bears interest at a rate
applicable to demand loans plus applicable margins.
The amount available to Vermilion under this facility is reduced by
certain outstanding letters of credit associated with Vermilion's
operations totalling $11.5 million as at September 30, 2013 (December
31, 2012 - $49.2 million).
The facility is secured by various fixed and floating charges against
the subsidiaries of Vermilion. Under the terms of the facility,
Vermilion must maintain a ratio of total bank borrowings (defined as
consolidated total debt), to consolidated net earnings before interest,
income taxes, depreciation, accretion and other certain non-cash items
(defined as consolidated EBITDA) of not greater than 4.0. In addition,
Vermilion must maintain a ratio of consolidated total senior debt
(defined as consolidated total debt excluding unsecured and
subordinated debt) to consolidated EBITDA of not greater than 3.0.
As at September 30, 2013, Vermilion was in compliance with its financial
covenants.
Senior Unsecured Notes
On February 10, 2011, Vermilion issued $225.0 million of senior
unsecured notes at par. The notes bear interest at a rate of 6.5% per
annum and will mature on February 10, 2016. As direct senior unsecured
obligations of Vermilion, the notes rank pari passu with all other
present and future unsecured and unsubordinated indebtedness of the
Company.
Vermilion may, at its option, prior to February 10, 2014, redeem up to
35% of the notes with net proceeds of equity offerings by the Company
at a redemption price equal to 106.5% of the principal amount of the
notes to be redeemed, plus accrued and unpaid interest, if any, to the
applicable redemption date. Subsequently, Vermilion may, on or after
February 10, 2014, redeem all or part of the notes at fixed redemption
prices, plus, in each case, accrued and unpaid interest, if any, to the
applicable redemption date. The notes were initially recognized at
fair value net of transaction costs and are subsequently measured at
amortized cost using an effective interest rate of 7.1%.
ASSET RETIREMENT OBLIGATIONS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As At
|
|
|
|
|
|
Sept 30,
|
Dec 31,
|
($M)
|
|
|
|
|
2013
|
2012
|
Asset retirement obligations
|
|
|
|
|
362,537
|
371,063
|
The decrease in asset retirement obligations was primarily the result of
an overall increase in the discount rates applied to the obligations.
This decrease was partially offset by the appreciation of the Euro
against the Canadian dollar and the resulting impact of translating the
asset retirement obligations that are denominated in Euros to Canadian
dollars.
DIVIDENDS
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
Year Ended
|
($M)
|
Sept 30, 2013
|
|
|
Sept 30, 2013
|
Dec 31, 2012
|
Cash flows from operating activities
|
158,236
|
|
|
528,022
|
496,580
|
Net earnings
|
67,796
|
|
|
226,131
|
190,622
|
Dividends declared
|
61,003
|
|
|
181,391
|
223,717
|
Excess of cash flows from operating activities over dividends declared
|
97,233
|
|
|
346,631
|
272,863
|
Excess (shortfall) of net earnings over dividends declared
|
6,793
|
|
|
44,740
|
(33,095)
|
During the nine months ended September 30, 2013, Vermilion maintained
monthly dividends at $0.20 per share and declared dividends totalling
$181.4 million.
Excess cash flows from operating activities over dividends declared are
used to fund capital expenditures, asset retirement obligations and
debt repayments.
Following Vermilion's conversion to a trust in January 2003, the
distribution remained at $0.17 per unit per month until it was
increased to $0.19 per unit per month in December 2007. Effective
September 1, 2010, Vermilion converted to a dividend paying corporation
and dividends remained at $0.19 per share per month until increased to
$0.20 per share per month in January 2013. The January 2013 increase
was announced on November 14, 2012 and resulted in an increase in the
monthly cash dividends by 5.3% to $0.20 per share per month beginning
with the January 2013 dividend (paid on February 15, 2013).
Vermilion's policy with respect to dividends is to be conservative and
maintain a low ratio of dividends to fund flows from operations.
During low price commodity cycles, Vermilion will initially maintain
dividends and allow the ratio to rise. Should low commodity price
cycles remain for an extended period of time, Vermilion will evaluate
the necessity of changing the level of dividends, taking into
consideration capital development requirements, debt levels and
acquisition opportunities.
Over the next two years, Vermilion anticipates that Corrib, Cardium and
other exploration and development activities will require a significant
capital investment by Vermilion. Although Vermilion currently expects
to be able to maintain its current dividend, Vermilion's fund flows
from operations may not be sufficient during this period to fund cash
dividends, capital expenditures and asset retirement obligations.
Vermilion will evaluate its ability to finance any shortfalls with
debt, issuances of equity or by reducing some or all categories of
expenditures to ensure that total expenditures do not exceed available
funds.
SHAREHOLDERS' EQUITY
During the nine months ended September 30, 2013, Vermilion issued 2.7
million common shares pursuant to the dividend reinvestment plan and
Vermilion's equity based compensation programs. Shareholders' capital
increased by $118.3 million as a result of the issuance of those
shares.
As at September 30, 2013, there were 101.8 million shares outstanding.
As at November 6, 2013, there were 101.9 million shares outstanding.
CORRIB PROJECT
Vermilion holds an 18.5% non-operating interest in the offshore Corrib
gas field located off the northwest coast of Ireland. Production from
Corrib is expected to increase Vermilion's volumes by approximately 58
mmcf/d (9,700 boe/d) once the field reaches peak production. Vermilion
acquired its 18.5% working interest in the project on July 30, 2009.
The project comprises six offshore wells, both offshore and onshore
pipeline segments as well as a natural gas processing facility. At the
time of the acquisition most of the key components of the project, with
the exception of the onshore pipeline, were either complete or in the
latter stages of development. Vermilion's interest was acquired for
cash consideration of $136.8 million with subsequent capital
expenditures to September 30, 2013 of $379.0 million, primarily related
to completion of the natural gas processing facility, sub-surface well
work, and permitting, preparations and construction of the onshore
pipeline. Furthermore, pursuant to the terms of the acquisition
agreement, Vermilion made an additional payment to the vendor of $134.3
million (US$135 million) at the end of 2012. In 2011, approvals and
permissions were granted for the onshore gas pipeline and tunneling
activities commenced in December of 2012. Vermilion expects to
continue significant capital investment on this project over the next
two years and currently expects to achieve initial gas production from
this field in mid-2015.
RISK MANAGEMENT
Vermilion is exposed to various market and operational risks. For a
detailed discussion of these risks, please see Vermilion's Annual
Report and Annual Information Form, each for the year ended December
31, 2012.
CRITICAL ACCOUNTING ESTIMATES
The preparation of financial statements in accordance with IFRS requires
management to make estimates, judgments and assumptions that affect
reported assets, liabilities, revenues and expenses, gains and losses,
and disclosures of any possible contingencies. These estimates and
assumptions are developed based on the best available information which
management believed to be reasonable at the time such estimates and
assumptions were made. As such, these assumptions are uncertain at the
time estimates are made and could change, resulting in a material
impact on Vermilion's consolidated financial statements. Estimates are
reviewed by management on an ongoing basis and as a result may change
from period to period due to the availability of new information.
Additionally, as a result of the unique circumstances of each
jurisdiction that Vermilion operates in, the critical accounting
estimates may affect one or more jurisdictions.
The following outlines what management believes to be the most critical
accounting policies involving the use of estimates and assumptions:
i.
|
Depletion and depreciation charges are based on estimates of total
proven and probable reserves that Vermilion expects to recover in the
future.
|
ii.
|
Asset retirement obligations are based on past experience and current
economic factors which management believes are reasonable.
|
iii.
|
Impairment tests are performed at the cash generating unit (CGU) level,
which is determined based on management's judgment. The calculation of
the recoverable amount of a CGU is based on market factors as well as
estimates of PNG reserves and future costs required to develop
reserves.
|
iv.
|
Deferred tax amounts recognized in the consolidated financial statements
are based on management's assessment of the tax positions at the end of
each reporting period.
|
OFF BALANCE SHEET ARRANGEMENTS
Vermilion has certain lease agreements that are entered into in the
normal course of operations, all of which are operating leases and
accordingly no asset or liability value has been assigned to the
consolidated balance sheet as at September 30, 2013.
Vermilion has not entered into any guarantee or off balance sheet
arrangements that would materially impact Vermilion's financial
position or results of operations.
INTERNAL CONTROL OVER FINANCIAL REPORTING
There was no change in Vermilion's internal control over financial
reporting that occurred during the period covered by this MD&A that has
materially affected, or is reasonably likely to materially affect, its
internal control over financial reporting.
RECENTLY ADOPTED ACCOUNTING PRONOUNCEMENTS
As of January 1, 2013, Vermilion adopted the following pronouncements as
issued by the IASB. The adoption of these standards did not have a
material impact on Vermilion's consolidated financial statements.
IFRS 10 "Consolidated Financial Statements"
IFRS 10 replaced Standing Interpretations Committee 12, "Consolidation -
Special Purpose Entities" and the consolidation requirements of IAS 27
"Consolidated and Separate Financial Statements". The new standard
replaces the existing risk and rewards based approaches and establishes
control as the determining factor when determining whether an interest
in another entity should be included in the consolidated financial
statements.
IFRS 11 "Joint Arrangements"
IFRS 11 replaced IAS 31 "Interests in Joint Ventures". The new standard
focuses on the rights and obligations of an arrangement, rather than
its legal form. The standard redefines joint operations and joint
ventures and requires joint operations to be proportionately
consolidated and joint ventures to be equity accounted.
IFRS 12 "Disclosure of Interests in Other Entities"
IFRS 12 provides comprehensive disclosure requirements for interests in
other entities, including joint arrangements, associates, and special
purpose entities. The new disclosures are intended to assist financial
statement users in evaluating the nature, risks and financial effects
of an entity's interest in subsidiaries and joint arrangements.
IFRS 13 "Fair Value Measurement"
IFRS 13 provides a common definition of fair value within IFRS. The new
standard provides measurement and disclosure guidance and applies when
another IFRS requires or permits an item to be measured at fair value,
with limited exceptions.
IAS 34 "Interim Financial Reporting"
Amendments to IAS 34 require specific disclosures on the fair value of
financial instruments for interim reporting.
ACCOUNTING PRONOUNCEMENTS NOT YET ADOPTED
The adoption of the following pronouncements is not expected to have a
material impact on Vermilion's consolidated financial statements:
IFRS 9 "Financial Instruments"
As of January 1, 2015, Vermilion will be required to adopt IFRS 9, as
part of the first phase of the IASB's project to replace IAS 39,
"Financial Instruments: Recognition and Measurement". The new standard
replaces the current multiple classification and measurement models for
financial assets and liabilities with a single model that has only two
classification categories: amortized cost and fair value.
NETBACKS
The following table includes segmented financial information on a per
unit basis. Natural gas sales volumes have been converted on a basis
of six thousand cubic feet of natural gas to one barrel of oil
equivalent.
|
Three Months Ended Sept 30, 2013
|
|
Nine Months Ended Sept 30, 2013
|
|
|
Three Months
Ended Sept 30,
2012
|
|
Nine Months
Ended Sept 30,
2012
|
|
Oil & NGLs
|
Natural Gas
|
Total
|
|
Oil & NGLs
|
Natural Gas
|
Total
|
|
|
Total
|
|
Total
|
|
$/bbl
|
$/mcf
|
$/boe
|
|
$/bbl
|
$/mcf
|
$/boe
|
|
|
$/boe
|
|
$/boe
|
Canada
|
|
|
|
|
|
|
|
|
|
|
|
|
Price
|
98.14
|
2.73
|
63.56
|
|
90.81
|
3.30
|
61.16
|
|
|
53.61
|
|
53.67
|
Realized hedging (loss) gain
|
(4.10)
|
0.14
|
(2.02)
|
|
(1.16)
|
0.05
|
(0.55)
|
|
|
(0.21)
|
|
(0.32)
|
Royalties
|
(11.56)
|
(0.17)
|
(7.09)
|
|
(10.32)
|
(0.16)
|
(6.41)
|
|
|
(5.33)
|
|
(5.74)
|
Transportation
|
(2.92)
|
(0.16)
|
(2.08)
|
|
(2.31)
|
(0.16)
|
(1.75)
|
|
|
(1.51)
|
|
(1.51)
|
Operating
|
(7.35)
|
(1.53)
|
(8.12)
|
|
(8.79)
|
(1.61)
|
(9.15)
|
|
|
(10.10)
|
|
(9.68)
|
Operating netback
|
72.21
|
1.01
|
44.25
|
|
68.23
|
1.42
|
43.30
|
|
|
36.46
|
|
36.42
|
France
|
|
|
|
|
|
|
|
|
|
|
|
|
Price
|
110.65
|
10.08
|
107.08
|
|
107.19
|
10.20
|
104.29
|
|
|
104.95
|
|
106.00
|
Realized hedging loss
|
(1.32)
|
-
|
(1.23)
|
|
(0.65)
|
-
|
(0.61)
|
|
|
(1.39)
|
|
(3.27)
|
Royalties
|
(7.10)
|
(0.30)
|
(6.73)
|
|
(6.53)
|
(0.30)
|
(6.23)
|
|
|
(5.42)
|
|
(5.60)
|
Transportation
|
(2.59)
|
-
|
(2.41)
|
|
(2.56)
|
-
|
(2.40)
|
|
|
(1.89)
|
|
(2.25)
|
Operating
|
(13.33)
|
(1.38)
|
(12.97)
|
|
(16.11)
|
(1.52)
|
(15.67)
|
|
|
(12.66)
|
|
(14.53)
|
Operating netback
|
86.31
|
8.40
|
83.74
|
|
81.34
|
8.38
|
79.38
|
|
|
83.59
|
|
80.35
|
Netherlands
|
|
|
|
|
|
|
|
|
|
|
|
|
Price
|
98.86
|
10.18
|
61.44
|
|
97.06
|
10.39
|
62.70
|
|
|
56.88
|
|
57.95
|
Realized hedging (loss) gain
|
-
|
0.19
|
1.15
|
|
-
|
0.05
|
0.32
|
|
|
-
|
|
-
|
Operating
|
-
|
(1.97)
|
(11.69)
|
|
-
|
(1.52)
|
(9.04)
|
|
|
(7.24)
|
|
(8.44)
|
Operating netback
|
98.86
|
8.40
|
50.90
|
|
97.06
|
8.92
|
53.98
|
|
|
49.64
|
|
49.51
|
Australia
|
|
|
|
|
|
|
|
|
|
|
|
|
Price
|
120.95
|
-
|
120.95
|
|
117.65
|
-
|
117.65
|
|
|
114.44
|
|
117.40
|
Realized hedging loss
|
(1.11)
|
-
|
(1.11)
|
|
(0.92)
|
-
|
(0.92)
|
|
|
(0.33)
|
|
(0.30)
|
Operating
|
(20.86)
|
-
|
(20.86)
|
|
(20.41)
|
-
|
(20.41)
|
|
|
(24.62)
|
|
(20.75)
|
PRRT 1
|
(23.89)
|
-
|
(23.89)
|
|
(20.93)
|
-
|
(20.93)
|
|
|
(32.21)
|
|
(30.90)
|
Operating netback
|
75.09
|
-
|
75.09
|
|
75.39
|
-
|
75.39
|
|
|
57.28
|
|
65.45
|
Total Company
|
|
|
|
|
|
|
|
|
|
|
|
|
Price
|
108.87
|
6.00
|
86.10
|
|
103.95
|
6.68
|
83.10
|
|
|
80.35
|
|
79.83
|
Realized hedging (loss) gain
|
(2.23)
|
0.15
|
(1.25)
|
|
(0.89)
|
0.05
|
(0.51)
|
|
|
(0.53)
|
|
(1.06)
|
Royalties
|
(6.86)
|
(0.11)
|
(4.93)
|
|
(6.25)
|
(0.10)
|
(4.41)
|
|
|
(3.49)
|
|
(3.81)
|
Transportation
|
(2.05)
|
(0.17)
|
(1.72)
|
|
(1.84)
|
(0.25)
|
(1.74)
|
|
|
(1.62)
|
|
(1.77)
|
Operating
|
(13.12)
|
(1.68)
|
(12.17)
|
|
(14.54)
|
(1.57)
|
(12.87)
|
|
|
(13.27)
|
|
(12.78)
|
PRRT 1
|
(5.99)
|
-
|
(4.12)
|
|
(5.12)
|
-
|
(3.45)
|
|
|
(6.42)
|
|
(5.54)
|
Operating netback
|
78.62
|
4.19
|
61.91
|
|
75.31
|
4.81
|
60.12
|
|
|
55.02
|
|
54.87
|
General and administration
|
|
|
(3.17)
|
|
|
|
(3.15)
|
|
|
(3.57)
|
|
(3.31)
|
Interest expense
|
|
|
(2.66)
|
|
|
|
(2.46)
|
|
|
(2.04)
|
|
(1.89)
|
Realized foreign exchange (loss) gain
|
(0.32)
|
|
|
|
(0.05)
|
|
|
0.11
|
|
0.03
|
Other income (expense)
|
0.06
|
|
|
|
0.07
|
|
|
0.08
|
|
(0.74)
|
Current income taxes 1
|
|
|
(12.22)
|
|
|
|
(10.40)
|
|
|
(10.94)
|
|
(9.52)
|
Fund flows netback
|
|
|
43.60
|
|
|
|
44.13
|
|
|
38.66
|
|
39.44
|
Accretion
|
|
|
(1.64)
|
|
|
|
(1.58)
|
|
|
(1.66)
|
|
(1.60)
|
Depletion and depreciation
|
|
|
(20.74)
|
|
|
|
(20.91)
|
|
|
(21.70)
|
|
(21.74)
|
Impairments
|
|
|
-
|
|
|
|
-
|
|
|
-
|
|
(6.24)
|
Gain on acquisition
|
|
|
-
|
|
|
|
-
|
|
|
-
|
|
4.30
|
Deferred taxes
|
|
|
(0.08)
|
|
|
|
(1.22)
|
|
|
0.76
|
|
2.92
|
Unrealized other expense
|
(0.07)
|
|
|
|
(0.09)
|
|
|
-
|
|
(0.05)
|
Unrealized foreign exchange gain (loss)
|
1.11
|
|
|
|
2.60
|
|
|
(1.89)
|
|
(1.73)
|
Unrealized (loss) gain on derivative instruments
|
(0.97)
|
|
|
|
0.34
|
|
|
(3.02)
|
|
0.09
|
Equity based compensation
|
|
|
(3.36)
|
|
|
|
(3.47)
|
|
|
(2.46)
|
|
(2.71)
|
Earnings netback
|
|
|
17.85
|
|
|
|
19.80
|
|
|
8.69
|
|
12.68
|
1
|
Vermilion considers Australian PRRT to be an operating item and
accordingly has included PRRT in the calculation of operating
netbacks. Current income taxes presented above excludes PRRT.
|
CONSOLIDATED BALANCE SHEETS
(THOUSANDS OF CANADIAN DOLLARS, UNAUDITED)
|
|
September 30,
|
December 31,
|
|
Note
|
|
2013
|
|
2012
|
ASSETS
|
|
|
|
|
|
Current
|
|
|
|
|
|
Cash and cash equivalents
|
|
|
256,135
|
|
102,125
|
Accounts receivable
|
|
|
178,662
|
|
180,064
|
Crude oil inventory
|
|
|
18,159
|
|
25,719
|
Derivative instruments
|
|
|
2,372
|
|
2,086
|
Prepaid expenses
|
|
|
15,217
|
|
10,508
|
|
|
|
470,545
|
|
320,502
|
|
|
|
|
|
|
Deferred taxes
|
|
|
194,448
|
|
193,354
|
Exploration and evaluation assets
|
4
|
|
135,982
|
|
117,161
|
Capital assets
|
3
|
|
2,623,450
|
|
2,445,240
|
|
|
|
3,424,425
|
|
3,076,257
|
|
|
|
|
|
|
LIABILITIES
|
|
|
|
|
|
Current
|
|
|
|
|
|
Accounts payable and accrued liabilities
|
|
|
281,112
|
|
300,682
|
Dividends payable
|
7
|
|
20,357
|
|
18,836
|
Derivative instruments
|
|
|
4,931
|
|
8,484
|
Income taxes payable
|
|
|
83,357
|
|
27,709
|
|
|
|
389,757
|
|
355,711
|
|
|
|
|
|
|
Long-term debt
|
6
|
|
781,074
|
|
642,022
|
Asset retirement obligations
|
5
|
|
362,537
|
|
371,063
|
Deferred taxes
|
|
|
302,272
|
|
288,815
|
|
|
|
1,835,640
|
|
1,657,611
|
|
|
|
|
|
|
SHAREHOLDERS' EQUITY
|
|
|
|
|
|
Shareholders' capital
|
7
|
|
1,599,668
|
|
1,481,345
|
Contributed surplus
|
|
|
54,221
|
|
69,581
|
Accumulated other comprehensive loss
|
|
|
(165)
|
|
(32,409)
|
Deficit
|
|
|
(64,939)
|
|
(99,871)
|
|
|
|
1,588,785
|
|
1,418,646
|
|
|
|
3,424,425
|
|
3,076,257
|
CONSOLIDATED STATEMENTS OF NET EARNINGS AND COMPREHENSIVE INCOME
(THOUSANDS OF CANADIAN DOLLARS, EXCEPT SHARE AND PER SHARE AMOUNTS,
UNAUDITED)
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
|
Sept 30,
|
|
Sept 30,
|
|
Sept 30,
|
|
Sept 30,
|
|
Note
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
REVENUE
|
|
|
|
|
|
|
|
|
|
Petroleum and natural gas sales
|
|
|
327,185
|
|
284,838
|
|
948,727
|
|
841,870
|
Royalties
|
|
|
(18,730)
|
|
(12,363)
|
|
(50,320)
|
|
(40,146)
|
Petroleum and natural gas revenue
|
|
|
308,455
|
|
272,475
|
|
898,407
|
|
801,724
|
|
|
|
|
|
|
|
|
|
|
EXPENSES
|
|
|
|
|
|
|
|
|
|
Operating
|
|
|
46,246
|
|
47,030
|
|
146,903
|
|
134,808
|
Transportation
|
|
|
6,549
|
|
5,744
|
|
19,843
|
|
18,655
|
Equity based compensation
|
8
|
|
12,779
|
|
8,704
|
|
39,639
|
|
28,620
|
Loss on derivative instruments
|
|
|
8,464
|
|
12,590
|
|
1,943
|
|
10,223
|
Interest expense
|
|
|
10,109
|
|
7,229
|
|
28,134
|
|
19,930
|
General and administration
|
|
|
12,033
|
|
12,669
|
|
35,956
|
|
34,885
|
Foreign exchange (gain) loss
|
|
|
(3,005)
|
|
6,330
|
|
(29,166)
|
|
17,878
|
Other expense (income)
|
|
|
55
|
|
(277)
|
|
259
|
|
8,291
|
Accretion
|
5
|
|
6,214
|
|
5,891
|
|
18,038
|
|
16,921
|
Depletion and depreciation
|
3, 4
|
|
78,826
|
|
76,941
|
|
238,692
|
|
229,301
|
Impairments
|
3
|
|
-
|
|
-
|
|
-
|
|
65,800
|
Gain on acquisition
|
|
|
-
|
|
-
|
|
-
|
|
(45,309)
|
|
|
|
178,270
|
|
182,851
|
|
500,241
|
|
540,003
|
EARNINGS BEFORE INCOME TAXES
|
|
|
130,185
|
|
89,624
|
|
398,166
|
|
261,721
|
|
|
|
|
|
|
|
|
|
|
INCOME TAXES
|
|
|
|
|
|
|
|
|
|
Deferred
|
|
|
287
|
|
(2,701)
|
|
13,914
|
|
(30,832)
|
Current
|
|
|
62,102
|
|
61,527
|
|
158,121
|
|
158,845
|
|
|
|
62,389
|
|
58,826
|
|
172,035
|
|
128,013
|
|
|
|
|
|
|
|
|
|
|
NET EARNINGS
|
|
|
67,796
|
|
30,798
|
|
226,131
|
|
133,708
|
|
|
|
|
|
|
|
|
|
|
OTHER COMPREHENSIVE INCOME (LOSS)
|
|
|
|
|
|
|
|
|
|
Currency translation adjustments
|
|
|
14,621
|
|
(12,753)
|
|
32,244
|
|
(21,783)
|
COMPREHENSIVE INCOME
|
|
|
82,417
|
|
18,045
|
|
258,375
|
|
111,925
|
|
|
|
|
|
|
|
|
|
|
NET EARNINGS PER SHARE
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
0.67
|
|
0.31
|
|
2.25
|
|
1.37
|
Diluted
|
|
|
0.66
|
|
0.31
|
|
2.22
|
|
1.35
|
|
|
|
|
|
|
|
|
|
|
WEIGHTED AVERAGE SHARES OUTSTANDING ('000s)
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
101,613
|
|
98,523
|
|
100,634
|
|
97,704
|
Diluted
|
|
|
102,763
|
|
99,748
|
|
102,083
|
|
98,848
|
CONSOLIDATED STATEMENTS OF CASH FLOWS
(THOUSANDS OF CANADIAN DOLLARS, UNAUDITED)
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
|
Sept 30,
|
|
Sept 30,
|
|
Sept 30,
|
|
Sept 30,
|
|
Note
|
|
2013
|
|
2012
|
|
2013
|
|
2012
|
OPERATING
|
|
|
|
|
|
|
|
|
|
Net earnings
|
|
|
67,796
|
|
30,798
|
|
226,131
|
|
133,708
|
Adjustments:
|
|
|
|
|
|
|
|
|
|
|
Accretion
|
5
|
|
6,214
|
|
5,891
|
|
18,038
|
|
16,921
|
|
Depletion and depreciation
|
3, 4
|
|
78,826
|
|
76,941
|
|
238,692
|
|
229,301
|
|
Impairments
|
3
|
|
-
|
|
-
|
|
-
|
|
65,800
|
|
Gain on acquisition
|
|
|
-
|
|
-
|
|
-
|
|
(45,309)
|
|
Unrealized loss (gain) on derivative instruments
|
|
|
3,699
|
|
10,721
|
|
(3,839)
|
|
(955)
|
|
Equity based compensation
|
8
|
|
12,779
|
|
8,704
|
|
39,639
|
|
28,620
|
|
Unrealized foreign exchange (gain) loss
|
|
|
(4,232)
|
|
6,740
|
|
(29,738)
|
|
18,223
|
|
Unrealized other expense
|
|
|
276
|
|
-
|
|
1,029
|
|
514
|
|
Deferred taxes
|
|
|
287
|
|
(2,701)
|
|
13,914
|
|
(30,832)
|
Asset retirement obligations settled
|
5
|
|
(2,738)
|
|
(1,968)
|
|
(6,496)
|
|
(5,315)
|
Changes in non-cash operating working capital
|
|
|
(4,671)
|
|
13,175
|
|
30,652
|
|
(14,003)
|
Cash flows from operating activities
|
|
|
158,236
|
|
148,301
|
|
528,022
|
|
396,673
|
|
|
|
|
|
|
|
|
|
|
INVESTING
|
|
|
|
|
|
|
|
|
|
Drilling and development
|
3
|
|
(135,110)
|
|
(96,212)
|
|
(389,635)
|
|
(262,064)
|
Exploration and evaluation
|
4
|
|
(551)
|
|
(10,043)
|
|
(13,240)
|
|
(33,439)
|
Property acquisitions
|
3, 4
|
|
(7,586)
|
|
-
|
|
(7,586)
|
|
(106,184)
|
Dispositions
|
3
|
|
-
|
|
-
|
|
8,627
|
|
-
|
Changes in non-cash investing working capital
|
|
|
44,876
|
|
28,376
|
|
7,473
|
|
(1,408)
|
Cash flows used in investing activities
|
|
|
(98,371)
|
|
(77,879)
|
|
(394,361)
|
|
(403,095)
|
|
|
|
|
|
|
|
|
|
|
FINANCING
|
|
|
|
|
|
|
|
|
|
Increase in long-term debt
|
|
|
-
|
|
40,350
|
|
139,429
|
|
117,124
|
Issuance of shares pursuant to the dividend reinvestment plan
|
|
|
-
|
|
-
|
|
-
|
|
36,339
|
Cash dividends
|
|
|
(41,576)
|
|
(38,869)
|
|
(126,354)
|
|
(149,594)
|
Cash flows (used in) from financing activities
|
|
|
(41,576)
|
|
1,481
|
|
13,075
|
|
3,869
|
Foreign exchange gain (loss) on cash held in foreign currencies
|
|
|
2,248
|
|
(5,931)
|
|
7,274
|
|
(8,509)
|
|
|
|
|
|
|
|
|
|
|
Net change in cash and cash equivalents
|
|
|
20,537
|
|
65,972
|
|
154,010
|
|
(11,062)
|
Cash and cash equivalents, beginning of period
|
|
|
235,598
|
|
157,473
|
|
102,125
|
|
234,507
|
Cash and cash equivalents, end of period
|
|
|
256,135
|
|
223,445
|
|
256,135
|
|
223,445
|
|
|
|
|
|
|
|
|
|
|
Supplementary information for operating activities - cash payments
|
|
|
|
|
|
|
|
|
|
|
Interest paid
|
|
|
13,544
|
|
11,775
|
|
34,053
|
|
25,701
|
|
Income taxes paid
|
|
|
50,203
|
|
38,871
|
|
101,507
|
|
142,582
|
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY
(THOUSANDS OF CANADIAN DOLLARS, UNAUDITED)
|
|
|
|
|
|
Accumulated
|
|
|
|
|
|
|
|
|
|
|
Other
|
|
Total
|
|
|
Shareholders'
|
Contributed
|
Comprehensive
|
|
Shareholders'
|
|
Note
|
Capital
|
Surplus
|
|
Loss
|
Deficit
|
Equity
|
Balances as at January 1, 2012
|
|
|
1,368,145
|
|
56,468
|
|
(33,387)
|
|
(59,625)
|
|
1,331,601
|
Net earnings
|
|
|
-
|
|
-
|
|
-
|
|
133,708
|
|
133,708
|
Currency translation adjustments
|
|
|
-
|
|
-
|
|
(21,783)
|
|
-
|
|
(21,783)
|
Equity based compensation expense
|
|
|
-
|
|
27,984
|
|
-
|
|
-
|
|
27,984
|
Dividends declared
|
7
|
|
-
|
|
-
|
|
-
|
|
(167,282)
|
|
(167,282)
|
Issuance of shares pursuant to the
|
|
|
|
|
|
|
|
|
|
|
|
dividend reinvestment plan
|
7
|
|
53,590
|
|
-
|
|
-
|
|
-
|
|
53,590
|
Vesting of equity based awards
|
7, 8
|
|
33,356
|
|
(33,356)
|
|
-
|
|
-
|
|
-
|
Share-settled dividends
|
|
|
|
|
|
|
|
|
|
|
|
on vested equity based awards
|
7, 8
|
|
7,151
|
|
-
|
|
-
|
|
(7,151)
|
|
-
|
Shares issued pursuant to the bonus plan
|
7
|
|
636
|
|
-
|
|
-
|
|
-
|
|
636
|
Balances as at September 30, 2012
|
|
|
1,462,878
|
|
51,096
|
|
(55,170)
|
|
(100,350)
|
|
1,358,454
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated
|
|
|
|
|
|
|
|
|
|
|
Other
|
|
Total
|
|
|
Shareholders'
|
Contributed
|
Comprehensive
|
|
Shareholders'
|
|
Note
|
Capital
|
Surplus
|
|
Loss
|
Deficit
|
Equity
|
Balances as at January 1, 2013
|
|
|
1,481,345
|
|
69,581
|
|
(32,409)
|
|
(99,871)
|
|
1,418,646
|
Net earnings
|
|
|
-
|
|
-
|
|
-
|
|
226,131
|
|
226,131
|
Currency translation adjustments
|
|
|
-
|
|
-
|
|
32,244
|
|
-
|
|
32,244
|
Equity based compensation expense
|
|
|
-
|
|
39,010
|
|
-
|
|
-
|
|
39,010
|
Dividends declared
|
7
|
|
-
|
|
-
|
|
-
|
|
(181,391)
|
|
(181,391)
|
Issuance of shares pursuant to the
|
|
|
|
|
|
|
|
|
|
|
|
dividend reinvestment plan
|
7
|
|
53,516
|
|
-
|
|
-
|
|
-
|
|
53,516
|
Vesting of equity based awards
|
7, 8
|
|
54,370
|
|
(54,370)
|
|
-
|
|
-
|
|
-
|
Share-settled dividends
|
|
|
|
|
|
|
|
|
|
|
|
on vested equity based awards
|
7, 8
|
|
9,808
|
|
-
|
|
-
|
|
(9,808)
|
|
-
|
Shares issued pursuant to the bonus plan
|
7
|
|
629
|
|
-
|
|
-
|
|
-
|
|
629
|
Balances as at September 30, 2013
|
|
|
1,599,668
|
|
54,221
|
|
(165)
|
|
(64,939)
|
|
1,588,785
|
DESCRIPTION OF EQUITY RESERVES
Shareholders' capital
Represents the recognized amount for common shares when issued, net of
equity issuance costs and deferred taxes.
Contributed surplus
Represents the recognized value of employee awards which are settled in
shares. Once vested, the value of the awards is transferred to
shareholders' capital.
Accumulated other comprehensive loss
Represents the cumulative income and expenses which are not recorded
immediately in net earnings and are accumulated until an event triggers
recognition in net earnings. The current balance consists of currency
translation adjustments resulting from translating financial statements
of subsidiaries with a foreign functional currency to Canadian dollars
at period-end rates.
Retained earnings (deficit)
Represents the cumulative net earnings less distributed earnings of
Vermilion Energy Inc.
NOTES TO THE CONDENSED CONSOLIDATED INTERIM FINANCIAL STATEMENTS
FOR THE THREE AND NINE MONTHS ENDED SEPTEMBER 30, 2013 AND 2012
(TABULAR AMOUNTS IN THOUSANDS OF CANADIAN DOLLARS, EXCEPT SHARE AND PER
SHARE AMOUNTS, UNAUDITED)
1. BASIS OF PRESENTATION
Vermilion Energy Inc. (the "Company" or "Vermilion") is a corporation
governed by the laws of the Province of Alberta and is actively engaged
in the business of crude oil and natural gas exploration, development,
acquisition and production.
These condensed consolidated interim financial statements are in
compliance with IAS 34, "Interim financial reporting" and have been
prepared using the same accounting policies and methods of computation
as Vermilion's consolidated financial statements for the year ended
December 31, 2012, except as discussed in Note 2.
These condensed consolidated interim financial statements should be read
in conjunction with Vermilion's consolidated financial statements for
the year ended December 31, 2012, which are contained within
Vermilion's Annual Report for the year ended December 31, 2012 and are
available on SEDAR at www.sedar.com or on Vermilion's website at www.vermilionenergy.com.
These condensed consolidated interim financial statements were approved
and authorized for issuance by the Board of Directors of Vermilion on
November 6, 2013.
2. RECENTLY ADOPTED ACCOUNTING PRONOUNCEMENTS
On January 1, 2013, Vermilion adopted the following pronouncements as
issued by the IASB. The adoption of these standards did not have a
material impact on Vermilion's consolidated financial statements.
IFRS 10 "Consolidated Financial Statements"
IFRS 10 replaced Standing Interpretations Committee 12, "Consolidation -
Special Purpose Entities" and the consolidation requirements of IAS 27
"Consolidated and Separate Financial Statements". The new standard
replaces the existing risk and rewards based approaches and establishes
control as the determining factor when determining whether an interest
in another entity should be included in the consolidated financial
statements.
IFRS 11 "Joint Arrangements"
IFRS 11 replaced IAS 31 "Interests in Joint Ventures". The new standard
focuses on the rights and obligations of an arrangement, rather than
its legal form. The standard redefines joint operations and joint
ventures and requires joint operations to be proportionately
consolidated and joint ventures to be equity accounted.
IFRS 12 "Disclosure of Interests in Other Entities"
IFRS 12 provides comprehensive disclosure requirements for interests in
other entities, including joint arrangements, associates, and special
purpose entities. The new disclosures are intended to assist financial
statement users in evaluating the nature, risks and financial effects
of an entity's interest in subsidiaries and joint arrangements.
IFRS 13 "Fair Value Measurement"
IFRS 13 provides a common definition of fair value within IFRS. The new
standard provides measurement and disclosure guidance and applies when
another IFRS requires or permits an item to be measured at fair value,
with limited exceptions.
IAS 34 "Interim Financial Reporting"
Amendments to IAS 34 require specific disclosure on the fair value of
financial instruments for interim reporting. These disclosures are
included in Note 11.
3. CAPITAL ASSETS
The following table reconciles the change in Vermilion's capital assets:
|
Petroleum and
|
Furniture and
|
|
Total
|
($M)
|
Natural Gas Assets
|
Office Equipment
|
|
Capital Assets
|
Balance at January 1, 2012
|
|
2,016,611
|
|
15,071
|
|
2,031,682
|
Additions
|
|
407,973
|
|
5,248
|
|
413,221
|
Transfers from exploration and evaluation assets
|
|
10,528
|
|
-
|
|
10,528
|
Property acquisitions
|
|
206,260
|
|
-
|
|
206,260
|
Corporate acquisitions
|
|
136,297
|
|
-
|
|
136,297
|
Borrowing costs capitalized
|
|
9,994
|
|
-
|
|
9,994
|
Changes in estimate for asset retirement obligations
|
|
1,334
|
|
-
|
|
1,334
|
Depletion and depreciation
|
|
(289,194)
|
|
(5,165)
|
|
(294,359)
|
Impairments
|
|
(65,800)
|
|
-
|
|
(65,800)
|
Effect of movements in foreign exchange rates
|
|
(3,882)
|
|
(35)
|
|
(3,917)
|
Balance at December 31, 2012
|
|
2,430,121
|
|
15,119
|
|
2,445,240
|
Additions
|
|
386,313
|
|
3,322
|
|
389,635
|
Dispositions
|
|
(8,627)
|
|
-
|
|
(8,627)
|
Changes in estimate for asset retirement obligations
|
|
(29,747)
|
|
-
|
|
(29,747)
|
Depletion and depreciation
|
|
(229,955)
|
|
(4,365)
|
|
(234,320)
|
Effect of movements in foreign exchange rates
|
|
61,114
|
|
155
|
|
61,269
|
Balance at September 30, 2013
|
|
2,609,219
|
|
14,231
|
|
2,623,450
|
4. EXPLORATION AND EVALUATION ASSETS
The following table reconciles the change in Vermilion's exploration and
evaluation assets:
($M)
|
Exploration and Evaluation Assets
|
Balance at January 1, 2012
|
|
92,301
|
Additions
|
|
39,317
|
Transfers to petroleum and natural gas assets
|
|
(10,528)
|
Depreciation
|
|
(3,485)
|
Effect of movements in foreign exchange rates
|
|
(444)
|
Balance at December 31, 2012
|
|
117,161
|
Additions
|
|
13,240
|
Property acquisitions
|
|
7,586
|
Depreciation
|
|
(2,743)
|
Effect of movements in foreign exchange rates
|
|
738
|
Balance at September 30, 2013
|
|
135,982
|
5. ASSET RETIREMENT OBLIGATIONS
The following table reconciles the change in Vermilion's asset
retirement obligations:
($M)
|
Asset Retirement Obligations
|
Balance at January 1, 2012
|
|
|
310,531
|
Additional obligations recognized
|
|
|
55,228
|
Changes in estimates for existing obligations
|
|
|
(26,560)
|
Obligations settled
|
|
|
(13,739)
|
Accretion
|
|
|
23,040
|
Changes in discount rates
|
|
|
22,807
|
Effect of movements in foreign exchange rates
|
|
|
(244)
|
Balance at December 31, 2012
|
|
|
371,063
|
Additional obligations recognized
|
|
|
2,114
|
Obligations settled
|
|
|
(6,496)
|
Accretion
|
|
|
18,038
|
Changes in discount rates
|
|
|
(31,861)
|
Effect of movements in foreign exchange rates
|
|
|
9,679
|
Balance at September 30, 2013
|
|
|
362,537
|
6. LONG-TERM DEBT
The following table summarizes Vermilion's outstanding long-term debt:
|
As At
|
($M)
|
Sept 30, 2013
|
Dec 31, 2012
|
Revolving credit facility
|
|
558,171
|
|
419,784
|
Senior unsecured notes
|
|
222,903
|
|
222,238
|
Long-term debt
|
|
781,074
|
|
642,022
|
Revolving Credit Facility
At September 30, 2013, Vermilion had in place a bank revolving credit
facility totalling $1.2 billion, of which approximately $558.2 million
was drawn. The facility, which matures on May 31, 2016, is fully
revolving up to the date of maturity.
The facility is extendable from time to time, but not more than once per
year, for a period not longer than three years, at the option of the
lenders and upon notice from Vermilion. If no extension is granted by
the lenders, the amounts owing pursuant to the facility are repayable
on the maturity date. This facility bears interest at a rate
applicable to demand loans plus applicable margins.
The amount available to Vermilion under this facility is reduced by
certain outstanding letters of credit associated with Vermilion's
operations totalling $11.5 million as at September 30, 2013 (December
31, 2012 - $49.2 million).
The facility is secured by various fixed and floating charges against
the subsidiaries of Vermilion. Under the terms of the facility,
Vermilion must maintain a ratio of total bank borrowings (defined as
consolidated total debt), to consolidated net earnings before interest,
income taxes, depreciation, accretion and other certain non-cash items
(defined as consolidated EBITDA) of not greater than 4.0. In addition,
Vermilion must maintain a ratio of consolidated total senior debt
(defined as consolidated total debt excluding unsecured and
subordinated debt) to consolidated EBITDA of not greater than 3.0.
As at September 30, 2013, Vermilion was in compliance with its financial
covenants.
Senior Unsecured Notes
On February 10, 2011, Vermilion issued $225.0 million of senior
unsecured notes at par. The notes bear interest at a rate of 6.5% per
annum and will mature on February 10, 2016. As direct senior unsecured
obligations of Vermilion, the notes rank pari passu with all other
present and future unsecured and unsubordinated indebtedness of the
Company.
Vermilion may, at its option, prior to February 10, 2014, redeem up to
35% of the notes with net proceeds of equity offerings by the Company
at a redemption price equal to 106.5% of the principal amount of the
notes to be redeemed, plus accrued and unpaid interest, if any, to the
applicable redemption date. Subsequently, Vermilion may, on or after
February 10, 2014, redeem all or part of the notes at fixed redemption
prices, plus, in each case, accrued and unpaid interest, if any, to the
applicable redemption date. The notes were initially recognized at
fair value net of transaction costs and are subsequently measured at
amortized cost using an effective interest rate of 7.1%.
7. SHAREHOLDERS' CAPITAL
The following tables reconcile the change in Vermilion's shareholders'
capital:
Shareholders' Capital
|
Number of Shares ('000s)
|
|
Amount ($M)
|
Balance as at January 1, 2012
|
|
96,430
|
|
1,368,145
|
Issuance of shares pursuant to the dividend reinvestment plan
|
|
1,631
|
|
72,058
|
Vesting of equity based awards
|
|
904
|
|
33,355
|
Share-settled dividends on vested equity based awards
|
|
157
|
|
7,151
|
Shares issued pursuant to the bonus plan
|
|
13
|
|
636
|
Balance as at December 31, 2012
|
|
99,135
|
|
1,481,345
|
Issuance of shares pursuant to the dividend reinvestment plan
|
|
1,066
|
|
53,516
|
Vesting of equity based awards
|
|
1,372
|
|
54,370
|
Share-settled dividends on vested equity based awards
|
|
202
|
|
9,808
|
Shares issued pursuant to the bonus plan
|
|
12
|
|
629
|
Balance as at September 30, 2013
|
|
101,787
|
|
1,599,668
|
Dividends declared to shareholders for the nine months ended September
30, 2013 were $181.4 million.
Subsequent to the end of the period and prior to the condensed
consolidated interim financial statements being authorized for issue on
November 6, 2013, Vermilion declared dividends totalling $20.4 million
or $0.20 per share.
8. EQUITY BASED COMPENSATION
The following table summarizes the number of awards outstanding under
the Vermilion Incentive Plan ("VIP"):
Number of Awards ('000s)
|
|
|
|
|
2013
|
|
2012
|
Opening balance
|
|
|
|
|
1,690
|
|
1,750
|
Granted
|
|
|
|
|
774
|
|
681
|
Vested
|
|
|
|
|
(749)
|
|
(596)
|
Forfeited
|
|
|
|
|
(89)
|
|
(145)
|
Closing balance
|
|
|
|
|
1,626
|
|
1,690
|
The fair value of a VIP award is determined on the grant date at the
closing price of Vermilion's common shares on the Toronto Stock
Exchange, adjusted by the estimated performance factor that will
ultimately be achieved. Dividends, which notionally accrue to the
awards during the vesting period, are not included in the determination
of grant date fair values.
9. SEGMENTED INFORMATION
The following segment information has been prepared by segregating the
results into the geographic areas in which Vermilion operates. The
following amounts include transactions between segments, which are
recorded at fair value at the date of recognition.
|
Three Months Ended September 30, 2013
|
($M)
|
Canada
|
|
France
|
|
Netherlands
|
|
Australia
|
|
Ireland
|
|
Total
|
Drilling and development
|
62,222
|
|
23,664
|
|
8,316
|
|
5,880
|
|
35,028
|
|
135,110
|
Exploration and evaluation
|
551
|
|
-
|
|
-
|
|
-
|
|
-
|
|
551
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales to external customers
|
100,000
|
|
120,574
|
|
27,382
|
|
79,229
|
|
-
|
|
327,185
|
Royalties
|
(11,156)
|
|
(7,574)
|
|
-
|
|
-
|
|
-
|
|
(18,730)
|
Revenue from external customers
|
88,844
|
|
113,000
|
|
27,382
|
|
79,229
|
|
-
|
|
308,455
|
Realized (loss) gain on derivative instruments
|
(3,169)
|
|
(1,382)
|
|
510
|
|
(724)
|
|
-
|
|
(4,765)
|
Transportation expense
|
(3,272)
|
|
(2,713)
|
|
-
|
|
-
|
|
(564)
|
|
(6,549)
|
Operating expense
|
(12,770)
|
|
(14,599)
|
|
(5,209)
|
|
(13,668)
|
|
-
|
|
(46,246)
|
Operating income (loss)
|
69,633
|
|
94,306
|
|
22,683
|
|
64,837
|
|
(564)
|
|
250,895
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate income taxes
|
260
|
|
31,717
|
|
6,810
|
|
7,666
|
|
-
|
|
46,453
|
PRRT
|
-
|
|
-
|
|
-
|
|
15,649
|
|
-
|
|
15,649
|
Current income taxes
|
260
|
|
31,717
|
|
6,810
|
|
23,315
|
|
-
|
|
62,102
|
|
Three Months Ended September 30, 2012
|
($M)
|
Canada
|
|
France
|
|
Netherlands
|
|
Australia
|
|
Ireland
|
|
Total
|
Drilling and development
|
53,658
|
|
10,416
|
|
5,257
|
|
9,721
|
|
17,160
|
|
96,212
|
Exploration and evaluation
|
10,043
|
|
-
|
|
-
|
|
-
|
|
-
|
|
10,043
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales to external customers
|
71,268
|
|
102,369
|
|
30,386
|
|
80,815
|
|
-
|
|
284,838
|
Royalties
|
(7,081)
|
|
(5,282)
|
|
-
|
|
-
|
|
-
|
|
(12,363)
|
Revenue from external customers
|
64,187
|
|
97,087
|
|
30,386
|
|
80,815
|
|
-
|
|
272,475
|
Realized loss on derivative instruments
|
(274)
|
|
(1,360)
|
|
-
|
|
(235)
|
|
-
|
|
(1,869)
|
Transportation expense
|
(2,005)
|
|
(1,840)
|
|
-
|
|
-
|
|
(1,899)
|
|
(5,744)
|
Operating expense
|
(13,420)
|
|
(12,351)
|
|
(3,870)
|
|
(17,389)
|
|
-
|
|
(47,030)
|
Operating income (loss)
|
48,488
|
|
81,536
|
|
26,516
|
|
63,191
|
|
(1,899)
|
|
217,832
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate income taxes
|
36
|
|
21,051
|
|
9,614
|
|
8,083
|
|
-
|
|
38,784
|
PRRT
|
-
|
|
-
|
|
-
|
|
22,743
|
|
-
|
|
22,743
|
Current income taxes
|
36
|
|
21,051
|
|
9,614
|
|
30,826
|
|
-
|
|
61,527
|
|
|
Nine Months Ended September 30, 2013
|
($M)
|
Canada
|
France
|
Netherlands
|
Australia
|
Ireland
|
Total
|
Total assets
|
1,350,574
|
|
930,568
|
|
144,813
|
|
301,350
|
|
697,120
|
|
3,424,425
|
Drilling and development
|
160,747
|
|
68,479
|
|
14,472
|
|
69,511
|
|
76,426
|
|
389,635
|
Exploration and evaluation
|
13,240
|
|
-
|
|
-
|
|
-
|
|
-
|
|
13,240
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales to external customers
|
284,638
|
|
342,558
|
|
100,119
|
|
221,412
|
|
-
|
|
948,727
|
Royalties
|
(29,852)
|
|
(20,468)
|
|
-
|
|
-
|
|
-
|
|
(50,320)
|
Revenue from external customers
|
254,786
|
|
322,090
|
|
100,119
|
|
221,412
|
|
-
|
|
898,407
|
Realized (loss) gain on derivative instruments
|
(2,572)
|
|
(1,990)
|
|
509
|
|
(1,729)
|
|
-
|
|
(5,782)
|
Transportation expense
|
(8,152)
|
|
(7,883)
|
|
-
|
|
-
|
|
(3,808)
|
|
(19,843)
|
Operating expense
|
(42,586)
|
|
(51,473)
|
|
(14,438)
|
|
(38,406)
|
|
-
|
|
(146,903)
|
Operating income (loss)
|
201,476
|
|
260,744
|
|
86,190
|
|
181,277
|
|
(3,808)
|
|
725,879
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate income taxes
|
839
|
|
66,500
|
|
25,865
|
|
25,525
|
|
-
|
|
118,729
|
PRRT
|
-
|
|
-
|
|
-
|
|
39,392
|
|
-
|
|
39,392
|
Current income taxes
|
839
|
|
66,500
|
|
25,865
|
|
64,917
|
|
-
|
|
158,121
|
|
|
Nine Months Ended September 30, 2012
|
($M)
|
Canada
|
France
|
Netherlands
|
Australia
|
Ireland
|
Total
|
Total assets
|
1,270,547
|
|
674,355
|
|
138,630
|
|
286,960
|
|
528,925
|
|
2,899,417
|
Drilling and development
|
157,680
|
|
26,424
|
|
13,157
|
|
24,132
|
|
40,671
|
|
262,064
|
Exploration and evaluation
|
33,390
|
|
-
|
|
49
|
|
-
|
|
-
|
|
33,439
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas sales to external customers
|
226,726
|
|
300,708
|
|
92,268
|
|
222,168
|
|
-
|
|
841,870
|
Royalties
|
(24,266)
|
|
(15,880)
|
|
-
|
|
-
|
|
-
|
|
(40,146)
|
Revenue from external customers
|
202,460
|
|
284,828
|
|
92,268
|
|
222,168
|
|
-
|
|
801,724
|
Realized loss on derivative instruments
|
(1,335)
|
|
(9,274)
|
|
-
|
|
(569)
|
|
-
|
|
(11,178)
|
Transportation expense
|
(6,399)
|
|
(6,382)
|
|
-
|
|
-
|
|
(5,874)
|
|
(18,655)
|
Operating expense
|
(40,904)
|
|
(41,208)
|
|
(13,436)
|
|
(39,260)
|
|
-
|
|
(134,808)
|
Operating income (loss)
|
153,822
|
|
227,964
|
|
78,832
|
|
182,339
|
|
(5,874)
|
|
637,083
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate income taxes
|
1,323
|
|
49,671
|
|
24,546
|
|
24,833
|
|
-
|
|
100,373
|
PRRT
|
-
|
|
-
|
|
-
|
|
58,472
|
|
-
|
|
58,472
|
Current income taxes
|
1,323
|
|
49,671
|
|
24,546
|
|
83,305
|
|
-
|
|
158,845
|
Reconciliation of operating income to net earnings
|
Three Months Ended
|
|
Nine Months Ended
|
($M)
|
Sept 30, 2013
|
Sept 30, 2012
|
|
Sept 30, 2013
|
Sept 30, 2012
|
Operating income
|
250,895
|
217,832
|
|
725,879
|
637,083
|
Equity based compensation
|
(12,779)
|
(8,704)
|
|
(39,639)
|
(28,620)
|
Unrealized (loss) gain on derivative instruments
|
(3,699)
|
(10,721)
|
|
3,839
|
955
|
Interest expense
|
(10,109)
|
(7,229)
|
|
(28,134)
|
(19,930)
|
General and administration
|
(12,033)
|
(12,669)
|
|
(35,956)
|
(34,885)
|
Foreign exchange gain (loss)
|
3,005
|
(6,330)
|
|
29,166
|
(17,878)
|
Other (expense) income
|
(55)
|
277
|
|
(259)
|
(8,291)
|
Accretion
|
(6,214)
|
(5,891)
|
|
(18,038)
|
(16,921)
|
Depletion and depreciation
|
(78,826)
|
(76,941)
|
|
(238,692)
|
(229,301)
|
Impairments
|
-
|
-
|
|
-
|
(65,800)
|
Gain on acquisition
|
-
|
-
|
|
-
|
45,309
|
Earnings before income taxes
|
130,185
|
89,624
|
|
398,166
|
261,721
|
Income taxes
|
(62,389)
|
(58,826)
|
|
(172,035)
|
(128,013)
|
Net earnings
|
67,796
|
30,798
|
|
226,131
|
133,708
|
10. CAPITAL DISCLOSURES
|
Three Months Ended
|
|
Nine Months Ended
|
($M except as indicated)
|
Sept 30, 2013
|
Sept 30, 2012
|
|
Sept 30, 2013
|
Sept 30, 2012
|
Long-term debt
|
781,074
|
492,669
|
|
781,074
|
492,669
|
Current liabilities
|
389,757
|
442,376
|
|
389,757
|
442,376
|
Current assets
|
(470,545)
|
(385,554)
|
|
(470,545)
|
(385,554)
|
Net debt [1]
|
700,286
|
549,491
|
|
700,286
|
549,491
|
|
|
|
|
|
|
Cash flows from operating activities
|
158,236
|
148,301
|
|
528,022
|
396,673
|
Changes in non-cash operating working capital
|
4,671
|
(13,175)
|
|
(30,652)
|
14,003
|
Asset retirement obligations settled
|
2,738
|
1,968
|
|
6,496
|
5,315
|
Fund flows from operations
|
165,645
|
137,094
|
|
503,866
|
415,991
|
Annualized fund flows from operations [2]
|
662,580
|
548,376
|
|
671,821
|
554,655
|
|
|
|
|
|
|
Ratio of net debt to annualized fund flows from operations ([1] ÷ [2])
|
1.1
|
1.0
|
|
1.0
|
1.0
|
The ratio of net debt to annualized fund flows from operations for the
three and nine months ended September 30, 2013 was relatively
consistent with same periods in 2012 as fund flows from operations
increased proportionately with net debt. The increase in net debt was
the result of the second of two acquisitions that occurred in France
during 2012 and capital expenditures pertaining to the Ireland assets,
which are currently under development.
Vermilion is subject to certain externally imposed capital requirements
under its revolving credit facility. During the periods covered by
these consolidated financial statements, Vermilion continued to comply
with these requirements.
11. FINANCIAL INSTRUMENTS
Classification of Financial Instruments
The following table summarizes information relating to Vermilion's
financial instruments as at September 30, 2013 and December 31, 2012:
|
|
|
|
|
|
|
As at Sep 30, 2013
|
|
|
As at Dec 31, 2012
|
|
|
|
Class of financial
instrument
|
Consolidated balance
sheet caption
|
Accounting
designation
|
Related caption on Statement of Net
Earnings
|
|
|
Carrying
value ($M)
|
|
Fair value
($M)
|
|
|
Carrying
value ($M)
|
|
Fair value
($M)
|
|
|
Fair value
measurement
hierarchy
|
Cash
|
Cash and cash
equivalents
|
HFT
|
Gains and losses on foreign exchange
are included in foreign exchange (gain)
loss
|
|
|
256,135
|
|
256,135
|
|
|
102,125
|
|
102,125
|
|
|
Level 1
|
Receivables
|
Accounts receivable
|
LAR
|
Gains and losses on foreign exchange
are included in foreign exchange (gain)
loss and impairments are recognized as
general and administration expense
|
|
|
178,662
|
|
178,662
|
|
|
180,064
|
|
180,064
|
|
|
Not applicable
|
Derivative assets
|
Derivative instruments
|
HFT
|
Gain on derivative instruments
|
|
|
2,372
|
|
2,372
|
|
|
2,086
|
|
2,086
|
|
|
Level 2
|
Derivative liabilities
|
Derivative instruments
|
HFT
|
Gain on derivative instruments
|
|
|
(4,931)
|
|
(4,931)
|
|
|
(8,484)
|
|
(8,484)
|
|
|
Level 2
|
Payables
|
Accounts payable and
accrued liabilities
|
OTH
|
Gains and losses on foreign exchange
are included in foreign exchange (gain)
loss
|
|
|
(301,469)
|
|
(301,469)
|
|
|
(319,518)
|
|
(319,518)
|
|
|
Not applicable
|
|
|
Dividends payable
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt
|
Long-term debt
|
OTH
|
Interest expense
|
|
|
(781,074)
|
|
(791,653)
|
|
|
(642,022)
|
|
(656,315)
|
|
|
Not applicable
|
The accounting designations used in the above table refer to the
following:
HFT - Classified as "Held for trading" in accordance with International
Accounting Standard 39 "Financial Instruments: Recognition and
Measurement". These financial assets and liabilities are carried at
fair value on the consolidated balance sheets with associated gains and
losses reflected in net earnings.
LAR - "Loans and receivables" are initially recognized at fair value and
are subsequently measured at amortized cost. Impairments and foreign
exchange gains and losses are recognized in net earnings.
OTH - "Other financial liabilities" are initially recognized at fair
value net of transaction costs directly attributable to the issuance of
the instrument and subsequently are measured at amortized cost.
Interest is recognized in net earnings using the effective interest
method. Foreign exchange gains and losses are recognized in net
earnings.
Level 1 - Fair value measurement is determined by reference to
unadjusted quoted prices in active markets for identical assets or
liabilities.
Level 2 - Fair value measurement is determined based on inputs other
than unadjusted quoted prices that are observable, either directly or
indirectly.
Level 3 - Fair value measurement is based on inputs for the asset or
liability that are not based on observable market data.
Determination of Fair Values
The level in the fair value hierarchy into which the fair value
measurements are categorized is determined on the basis of the lowest
level input that is significant to the fair value measurement.
Transfers between levels on the fair value hierarchy are deemed to have
occurred at the end of the reporting period.
Fair values for derivative assets and derivative liabilities are
determined using pricing models incorporating future prices that are
based on assumptions which are supported by prices from observable
market transactions and are adjusted for credit risk.
The carrying value of receivables approximate their fair value due to
their short maturities.
The carrying value of long-term debt outstanding on the revolving credit
facility approximates its fair value due to the use of short-term
borrowing instruments at market rates of interest.
The fair value of the senior unsecured notes changes in response to
changes in the market rates of interest payable on similar instruments
and was determined with reference to prevailing market rates for such
instruments.
Nature and Extent of Risks Arising from Financial Instruments
Market risk:
Vermilion's financial instruments are exposed to currency risk related
to changes in foreign currency denominated financial instruments and
commodity price risk related to outstanding derivative positions. The
following table summarizes what the impact on comprehensive income
before tax would be for the nine months ended September 30, 2013 given
changes in the relevant risk variables that Vermilion considers were
reasonably possible at the balance sheet date. The impact on
comprehensive income before tax associated with changes in these risk
variables for assets and liabilities that are not considered financial
instruments are excluded from this analysis. This analysis does not
attempt to reflect any interdependencies between the relevant risk
variables.
|
September 30, 2013
|
|
Before tax effect on comprehensive income
|
Risk ($M)
|
Description of change in risk variable
|
Increase (decrease)
|
Currency risk - Euro to Canadian
|
Increase in strength of the Canadian dollar against the
|
|
(5,671)
|
|
Euro by 5% over the relevant closing rates on September 30, 2013
|
|
|
|
Decrease in strength of the Canadian dollar against the
|
|
5,671
|
|
Euro by 5% over the relevant closing rates on September 30, 2013
|
|
|
Currency risk - US $ to Canadian
|
Increase in strength of the Canadian dollar against the
|
|
(5,954)
|
|
US$ by 5% over the relevant closing rates on September 30, 2013
|
|
|
|
Decrease in strength of the Canadian dollar against the
|
|
5,954
|
|
US$ by 5% over the relevant closing rates on September 30, 2013
|
|
|
Commodity price risk
|
Increase in relevant oil reference price within option pricing models used to
|
|
(7,388)
|
|
determine the fair value of financial derivative positions by
US$5.00/bbl at September 30, 2013
|
|
|
|
Decrease in relevant oil reference price within option pricing models used to
|
|
6,886
|
|
determine the fair value of financial derivative positions by
US$5.00/bbl at September 30, 2013
|
|
|
Interest rate risk
|
Increase in average Canadian prime interest rate
|
|
(3,655)
|
|
by 100 basis points during the nine months ended September 30, 2013
|
|
|
|
|
Decrease in average Canadian prime interest rate
|
|
3,655
|
|
by 100 basis points during the nine months ended September 30, 2013
|
|
|
|
12. SUBSEQUENT EVENTS
Northern Petroleum Nederland B.V.
On October 10, 2013, Vermilion acquired, through its wholly-owned
subsidiary, 100% of the shares of Northern Petroleum Nederland B.V., a
subsidiary of UK-based Northern Petroleum Plc. ("Northern"). The
acquisition is a complementary addition to the existing Netherlands
asset base, including interests in six onshore licences in production
or development, three onshore exploration licenses, and one offshore
production license in the Netherlands. Taking into consideration an
effective date of January 1, 2013 and customary closing adjustments,
Vermilion paid approximately $27.5 million cash at closing. Vermilion
funded this acquisition from cash on hand. Vermilion also granted
Northern minority net profit participation rights on select license
interests included in the acquisition.
Given the recent timing of the acquisition, the Company has not yet
completed the accounting for the acquisition and accordingly not all
relevant disclosures are available for the business combination. The
Company will report the purchase price allocation in the Company's
consolidated financial statements for the year ended December 31, 2013.
Purchase and Sale Agreement with GDF Suez E&P Deutschland GmbH
On November 6, 2013, Vermilion announced that it entered into a
definitive purchase and sale agreement with GDF Suez E&P Deutschland
GmbH ("GDF") whereby Vermilion, through its wholly-owned subsidiary,
will acquire GDF's 25% interest in four producing natural gas fields
and a surrounding exploration license located in northwest Germany.
GDF is an affiliate of GDF Suez S.A., a publicly traded, French
multinational utility. In addition, the acquisition also includes the
purchase of 0.4% of the equity of Ergas Munster GmbH ("EGM"), a joint
venture created in 1959 to jointly transport, process, and market gas
in northwest Germany. The acquisition represents Vermilion's entry
into the German exploration and production business, a producing region
with a long history of oil and gas development activity, low political
risk and strong marketing fundamentals. The acquisition is well
aligned with Vermilion's European focus, and will increase its exposure
to the strong fundamentals and pricing of the European natural gas
markets. The estimated cash cost to close is approximately $170
million, subject to final closing adjustments. The acquisition will be
funded with existing credit facilities and is expected to close prior
to the end of January, 2014.
SOURCE Vermilion Energy Inc.