- Sale of company-owned retail sites is progressing as planned;
gain of $716 million in the third
quarter
- Upstream unit cash costs down 35 percent versus 2014, averaging
less than US$20 per barrel
- Record high petroleum product sales of 505,000 barrels per
day
CALGARY, Oct. 28, 2016 /CNW/ -
|
|
|
|
|
|
|
|
|
Third quarter
|
|
Nine months
|
(millions of Canadian
dollars, unless noted)
|
2016
|
2015
|
%
|
|
2016
|
2015
|
%
|
Net income (loss)
(U.S. GAAP)
|
1,003
|
479
|
109
|
|
721
|
1,020
|
(29)
|
Net income (loss) per
common share
|
|
|
|
|
|
|
|
|
- assuming dilution
(dollars)
|
1.18
|
0.56
|
109
|
|
0.85
|
1.20
|
(29)
|
Capital and
exploration expenditures
|
205
|
1,142
|
(82)
|
|
948
|
3,011
|
(69)
|
Imperial's third quarter results reflect the company's
disciplined approach to cost management, operational integrity and
capturing the value of its integrated business model.
Earnings in the quarter were $1,003
million, or $1.18 per-share,
including a gain of $716 million
($0.84 per-share) from the sale of
retail sites. This compares to earnings of $479 million in the third quarter of 2015. The
sale of the company-owned Esso retail sites for $2.8 billion, announced in the first quarter, is
expected to be complete by year end. Currently, more than 200 sites
involved in the sale have converted to the Esso branded distributor
operating model, representing more than 40 percent of the total
transaction value.
Imperial continues to focus its efforts on reducing costs and
prudently managing cash in a low commodity price environment.
"Upstream unit cash costs are averaging less than US$20 per barrel year to date," said Rich Kruger, chairman, president and chief
executive officer. "That's a decline of more than 35 percent since
2014 when global crude prices began their descent. It's a testament
to our team's unrelenting focus on operational excellence and
profitability." Third quarter capital and exploration expenditures
were $205 million, down $937 million from 2015, reflecting the completion
of major upstream growth projects and an ongoing focus on capital
selectivity.
Gross oil-equivalent production was 393,000 barrels per day, up
7,000 barrels per day compared to the same period in 2015 and up by
64,000 barrels per day compared to the second quarter. Syncrude
production averaged 85,000 barrels per day (Imperial's share), up
26,000 barrels per day from the same quarter of 2015. "The increase
in production illustrates the company's strong recovery from the
effects of the northern Alberta
wildfires," Kruger said. "Syncrude achieved the second highest
quarterly production in its nearly 40-year history, reflecting
ongoing efforts to improve the reliability of operations."
Refinery throughput was 407,000 barrels per day, an increase of
17,000 barrels per day compared to the same quarter of 2015.
Refinery capacity utilization approached a record high at 97
percent, an increase of 4 percent from the comparable period in
2015. The company achieved record high petroleum product sales of
505,000 barrels per day, compared to 495,000 barrels per day in the
same period of 2015.
The company continues to evaluate the pace and scope of future
investments in light of overall market and business conditions. Our
objective remains to deliver industry leading performance in all
business environments.
Third quarter highlights
- Net income of $1,003 million
or $1.18 per-share on a diluted
basis, up from net income of $479
million or $0.56 per-share in
the third quarter of 2015. Third quarter 2016 results include a
$716 million ($0.84 per-share) gain from the sale of retail
sites.
- Production averaged 393,000 gross oil-equivalent barrels per
day, compared to 386,000 barrels per day in the same period of
2015. Increased production reflects improved reliability at
Syncrude operations, which more than offset planned and unplanned
maintenance impacts at Kearl. Compared to the second quarter,
production increased by about 64,000 barrels per day, reflecting
the strong recovery from the effects of the northern Alberta wildfires.
- Refinery throughput averaged 407,000 barrels per day,
compared to 390,000 barrels in the third quarter of 2015. Increased
throughput reflects lower maintenance activity than in the same
period of 2015. Refinery capacity utilization approached a record
high at 97 percent, an increase of 4 percent from the comparable
period in 2015.
- Petroleum product sales were a record 505,000 barrels per
day, up 10,000 barrels per day from the third quarter of 2015,
with growth concentrated in higher value commercial and retail
channels.
- Sale of retail sites progressing as planned. The sale of
the company-owned Esso retail sites for $2.8
billion, announced in the first quarter, is expected to be
complete by year-end. Currently, more than 200 of the approximately
500 sites involved in the sale have converted to the Esso branded
distributor operating model, representing more than 40 percent of
the total transaction value.
- Cash generated from operating activities was $772 million, a decrease of $332 million from the third quarter of 2015,
reflecting lower earnings, excluding the gain on the sale of retail
sites.
- Proceeds from asset sales were $1,194
million, before tax, mainly due to the sale of the
retail sites.
- Total debt was reduced from $8,426
million to $7,310 million,
bringing the debt to capital ratio to about 23 percent.
- Capital and exploration expenditures totalled $205 million, a decrease of $937 million from the third quarter of 2015,
reflecting completion of major upstream growth projects and an
ongoing focus on capital selectivity.
- An estimated $6 million in
artworks and art sale proceeds to be donated to Canadian museums
and galleries to mark Canada's
upcoming sesquicentennial. The artwork donations include pieces
by Group of Seven artist Lawren
Harris and other prominent Canadian artists. Proceeds from
the auction of some company-owned artworks, totalling nearly
$800,000, have been donated to United
Way partners across Canada.
Third quarter 2016 vs. third quarter 2015
The company's net income for the third quarter of 2016 was
$1,003 million or $1.18 per-share on a diluted basis, compared to
net income of $479 million or
$0.56 per-share for the same period
last year. Third quarter 2016 results included a $716 million ($0.84
per-share) gain from the sale of retail sites.
Upstream recorded a net loss in the third quarter of
$26 million, compared to a net loss
of $52 million in the same period of
2015. Results in the third quarter of 2016 mainly reflect the
impact of higher Syncrude volumes of about $90 million and lower operating expenses,
partially offset by lower realizations of about $90 million.
West Texas Intermediate (WTI) averaged US$44.94 per barrel in the third quarter of 2016,
down from US$46.57 per barrel in the
same quarter of 2015. Western Canada Select (WCS) averaged
US$31.43 per barrel and US$33.38 per barrel respectively for the same
periods. The WTI / WCS differential widened to 30 percent in the
third quarter of 2016, from 28 percent in the same period of
2015.
The Canadian dollar averaged US$0.77 in the third quarter of 2016 and was
essentially unchanged versus the same period of 2015.
Imperial's average Canadian dollar realizations for bitumen and
synthetic crudes declined essentially in line with the North
American benchmarks, adjusted for changes in the exchange rate and
transportation costs. Bitumen realizations averaged $30.16 per barrel for the third quarter of 2016,
a decrease of $2.45 per barrel versus
the third quarter of 2015. Synthetic crude realizations averaged
$58.97 per barrel, a decrease of
$2.24 per barrel for the same period
of 2015.
Gross production of Cold Lake
bitumen averaged 157,000 barrels per day in the third quarter,
compared to 166,000 barrels in the same period last year. The lower
production was mainly due to the timing of steam cycles.
Gross production of Kearl bitumen averaged 159,000 barrels per
day in the third quarter (113,000 barrels Imperial's share)
compared to 181,000 barrels per day (128,000 barrels Imperial's
share) during the third quarter of 2015. Lower production was the
result of planned and unplanned maintenance activities.
The company's share of gross production from Syncrude averaged
85,000 barrels per day, up from 59,000 barrels in the third quarter
of 2015. Increased production reflects ongoing efforts to improve
the reliability of operations.
Downstream net income was $1,002
million in the third quarter, compared to $454 million in the same period of 2015. Earnings
increased mainly due to a gain of $716
million from the sale of retail sites, improved refinery
operations of $80 million and higher
marketing sales volumes of $50
million, partially offset by lower industry margins of about
$300 million.
Refinery throughput averaged 407,000 barrels per day, up from
390,000 barrels in the third quarter of 2015. Increased throughput
reflects lower maintenance activities than in the same period of
2015.
Petroleum product sales were 505,000 barrels per day, up from
495,000 barrels per day in the third quarter of 2015, with growth
concentrated in the higher value commercial and retail
channels.
Chemical net income was $56
million in the third quarter, compared to $78 million in the same quarter of 2015.
Net income effects from Corporate and Other were negative
$29 million in the third quarter,
compared to negative $1 million in
the same period of 2015.
Cash flow generated from operating activities was $772 million in the third quarter, compared with
$1,104 million in the corresponding
period in 2015, reflecting lower earnings, excluding the gain on
the sale of retail sites.
Investing activities generated net cash of $1,005 million in the third quarter, compared
with cash used in investing activities of $619 million in the same period of 2015,
reflecting proceeds from asset sales in 2016 and the completion of
major upstream growth projects.
Cash used in financing activities was $1,724 million in the third quarter, compared
with $147 million in the third
quarter of 2015. Cash from operating activities and proceeds from
asset sales were mainly used in the third quarter of 2016 to reduce
outstanding short-term debt. Dividends paid in the third quarter of
2016 were $127 million. The per-share
dividend paid in the third quarter was $0.15, up from $0.13 in the same period of 2015.
The company's cash balance was $248
million at September 30, 2016,
versus $366 million at the end of the
third quarter of 2015.
Nine months highlights
- Net income of $721 million,
compared to net income of $1,020
million in the prior year.
- Net income per-share on a diluted basis was $0.85 compared to net income per-share of
$1.20 in 2015.
- Cash flow generated from operating activities was $1,264 million, versus $1,762 million in 2015.
- Gross oil-equivalent production averaged 380,000 barrels per
day, up 7 percent from 355,000 barrels from the same period in
2015.
- Refinery throughput averaged 351,000 barrels per day, compared
to 385,000 barrels in 2015.
- Per-share dividends declared during the year totalled
$0.44, up $0.04 per-share from 2015.
- Assessing impact of oil and gas prices on oil and gas reserves
and asset valuation.
Nine months 2016 vs. nine months 2015
Net income in the first nine months of 2016 was $721 million, or $0.85 per-share on a diluted basis, including a
gain of $719 million ($0.85 per-share) from the sale of retail sites,
versus net income of $1,020 million
or $1.20 per-share for the first nine
months of 2015.
Upstream recorded a net loss of $764
million for the first nine months of 2016, compared to a net
loss of $415 million for the same
period last year. The loss in 2016 reflected lower realizations of
about $970 million, the impact of the
northern Alberta wildfires of
about $155 million and higher
depreciation expense of about $90
million. These factors were partially offset by higher
volumes of about $230 million, the
impact of a weaker Canadian dollar of about $130 million, the favourable impact of lower
royalties of about $90 million and
lower energy cost of about $60
million. Earnings in 2015 reflected the impact associated
with the Alberta corporate income
tax rate increase of about $327
million.
West Texas Intermediate averaged US$41.54 per barrel in the first nine months of
2016, down from US$51.03 per barrel
in the same period last year. Western Canada Select averaged
US$27.74 per barrel and US$37.89 per barrel respectively for the same
periods. The WTI/WCS differential widened to 33 percent in the
first nine months of 2016, up from 26 percent in the same period of
2015.
During the first nine months of 2016, the Canadian dollar
weakened relative to the U.S. dollar versus the same period of
2015. The Canadian dollar averaged US$0.76 in the first nine months of 2016, a
decrease of almost US$0.04 from the
same period of 2015.
Imperial's average Canadian dollar realizations for bitumen and
synthetic crudes declined essentially in line with the North
American benchmarks, adjusted for changes in the exchange rate and
transportation costs. Bitumen realizations averaged $23.77 (US$18.18)
for the first nine months of 2016, a decrease of $12.71 per barrel versus the same period of 2015.
Synthetic crude realizations averaged $53.45 (US$40.33)
per barrel, a decrease of $9.58 per
barrel for the same period of 2015.
Gross production of Cold Lake
bitumen averaged 162,000 barrels per day in the first nine months,
up from 160,000 barrels from the same period last year. Production
from the expansion project offset the impacts from cycle
timing.
Gross production of Kearl bitumen averaged 169,000 barrels per
day in the first nine months of 2016 (120,000 barrels Imperial's
share) compared to 136,000 barrels per day (96,000 barrels
Imperial's share) for the same period of 2015. The increase was the
result of start-up of the expansion project and improved
reliability of the initial development.
During the first nine months of 2016, the company's share of
gross production from Syncrude averaged 61,000 barrels per day,
consistent with the same period of 2015.
Downstream net income was $1,393
million, up from $1,234
million from the same period of 2015. Earnings increased
mainly due to a gain of $719 million
from the sale of retail sites, the impact of a weaker Canadian
dollar of about $130 million, higher
marketing sales volumes of $70
million and lower fuels marketing operating costs of about
$50 million, partially offset by
lower downstream margins of about $780
million.
Refinery throughput averaged 351,000 barrels per day in the
first nine months of 2016, compared to 385,000 barrels in the same
period of 2015. Capacity utilization decreased to 83 percent from
92 percent in the same period of 2015, reflecting the more
significant scope of turnaround maintenance activity in the current
year.
Petroleum product sales were 481,000 barrels per day in the
first nine months of 2016, compared to 482,000 barrels per day in
the same period of 2015.
Chemical net income was $160
million, compared to $213
million in the same period of 2015.
For the first nine months of 2016, net income effects from
Corporate and Other were negative $68
million, versus negative $12
million in 2015, primarily due to lower capitalized interest
and the absence of the impact from the Alberta tax rate increase in 2015.
Cash flow generated from operating activities was $1,264 million in the first nine months of 2016,
compared with $1,762 million in the
same period of 2015, reflecting lower earnings, excluding the gain
on retail sites.
Investing activities generated net cash of $350 million in the first nine months of 2016,
compared with cash used in investing activities of $2,345 million in the same period of 2015,
reflecting proceeds from asset sales and the completion of major
upstream growth projects.
Cash used in financing activities was $1,569 million in the first nine months of 2016,
compared with cash provided by financing activities of $734 million in the same period of 2015. Cash
from operating activities and proceeds from the asset sales were
used to reduce outstanding short-term debt. Dividends paid in the
first nine months of 2016 were $364
million. The per-share dividend paid in the first nine
months was $0.43, up from
$0.39 in the same period of 2015.
Oil and gas reserves
If prices in the range seen during the first nine months of 2016
persist for the remainder of the year, under the SEC definition of
proved reserves, certain quantities of oil, such as those
associated with all or part of the oil sands operations at Kearl
and Cold Lake will not qualify as
proved reserves at year-end 2016. Amounts that could be required to
be de-booked as proved reserves on an SEC basis amount to
approximately 2.6 billion barrels of bitumen at Kearl and
approximately 0.4 billion barrels at Cold
Lake, and will be determined once the price and costs have
been finalized at year-end. Among the factors that would result in
these reserves being re-booked as proved reserves at some point in
the future are a recovery in price levels, a further decline in
costs, and / or operating efficiencies. Under the terms of
government royalty regimes, lower prices can also increase proved
reserves attributable to Imperial. The company does not expect the
de-booking of reported proved reserves under the SEC definitions to
affect the operation of the underlying projects or to alter our
outlook for future production volumes.
Impact of oil and gas reserves and prices and margins on
testing for impairment
In light of continued weakness in the upstream industry
environment during 2016, and as part of Imperial's annual planning
and budgeting process, the company is performing an assessment of
its major long-lived assets most at risk for potential impairment,
similar to the exercise undertaken in late 2015. The assessment
reflects crude and natural gas price outlooks consistent with those
that management uses to evaluate investment opportunities and
generally consistent with the long-term price forecasts published
by third-party industry experts. Development of future undiscounted
cash flow estimates requires significant management judgement,
particularly in cases where an asset's life is expected to extend
decades into the future. An asset group would be impaired if its
estimated undiscounted cash flows were less than the asset's
carrying value, and impairment would be measured by the amount by
which the carrying value exceeds fair value. Imperial will complete
its asset recoverability assessment and analyze the conclusions of
that assessment in connection with the preparation and review of
the company's year-end financial statements for inclusion in its
2016 Form 10-K. Until these activities are complete, it is not
practicable to reasonably estimate the existence or range of
potential future impairments related to the company's long-lived
assets.
Key financial and operating data follow.
Forward-looking statements
Statements of future events or conditions in this report,
including projections, targets, expectations, estimates, and
business plans are forward-looking statements. Actual future
financial and operating results, including demand growth and energy
source mix; production growth and mix; project plans, dates, costs
and capacities; production rates; production life and resource
recoveries; cost savings; product sales; financing sources; and
capital and environmental expenditures could differ materially
depending on a number of factors, such as changes in the supply of
and demand for crude oil, natural gas, and petroleum and
petrochemical products and resulting price impacts; availability
and allocation of capital; currency exchange rates; political or
regulatory events; project schedules; commercial negotiations; the
receipt, in a timely manner, of regulatory and third-party
approvals; unanticipated operational disruptions; unexpected
technological developments; and other factors discussed in this
report and Item 1A of Imperial's most recent Form 10-K.
Forward-looking statements are not guarantees of future performance
and involve a number of risks and uncertainties, some that are
similar to other oil and gas companies and some that are unique to
Imperial. Imperial's actual results may differ materially from
those expressed or implied by its forward-looking statements and
readers are cautioned not to place undue reliance on them. Imperial
undertakes no obligation to update any forward-looking statements
contained herein, except as required by applicable law.
The term "project" as used in this release can refer to a
variety of different activities and does not necessarily have the
same meaning as in any government payment transparency reports.
IMPERIAL OIL
LIMITED
|
|
|
|
Attachment
I
|
|
|
|
|
|
|
|
Third
Quarter
|
|
Nine
Months
|
millions of Canadian
dollars, unless noted
|
2016
|
2015
|
|
2016
|
2015
|
|
|
|
|
|
|
Net Income (loss)
(U.S. GAAP)
|
|
|
|
|
|
|
Total revenues and
other income
|
7,442
|
7,155
|
|
18,912
|
20,659
|
|
Total
expenses
|
6,260
|
6,518
|
|
18,131
|
18,865
|
|
Income (loss) before
income taxes
|
1,182
|
637
|
|
781
|
1,794
|
|
Income
taxes
|
179
|
158
|
|
60
|
774
|
|
Net income
(loss)
|
1,003
|
479
|
|
721
|
1,020
|
|
|
|
|
|
|
|
Net income (loss) per
common share (dollars)
|
1.18
|
0.56
|
|
0.85
|
1.20
|
|
Net income (loss) per
common share - assuming dilution (dollars)
|
1.18
|
0.56
|
|
0.85
|
1.20
|
|
|
|
|
|
|
Other Financial
Data
|
|
|
|
|
|
|
Federal excise tax
included in operating revenues
|
434
|
416
|
|
1,237
|
1,180
|
|
|
|
|
|
|
|
Gain (loss) on asset
sales, after tax
|
774
|
26
|
|
808
|
65
|
|
|
|
|
|
|
|
Total assets at
September 30
|
|
|
|
42,094
|
43,452
|
|
|
|
|
|
|
|
Total debt at
September 30
|
|
|
|
7,310
|
8,426
|
|
Interest coverage
ratio - earnings basis (times covered)
|
|
|
|
8.3
|
29.1
|
|
|
|
|
|
|
|
Other long-term
obligations at September 30
|
|
|
|
3,444
|
3,900
|
|
|
|
|
|
|
|
Shareholders' equity
at September 30
|
|
|
|
23,982
|
23,161
|
|
Capital employed at
September 30
|
|
|
|
31,309
|
31,604
|
|
Return on average
capital employed (percent) (a)
|
|
|
|
2.8
|
5.6
|
|
|
|
|
|
|
|
Dividends declared on
common stock
|
|
|
|
|
|
|
|
Total
|
127
|
119
|
|
373
|
339
|
|
|
Per common share
(dollars)
|
0.15
|
0.14
|
|
0.44
|
0.40
|
|
|
|
|
|
|
|
Millions of common
shares outstanding
|
|
|
|
|
|
|
|
At September
30
|
|
|
|
847.6
|
847.6
|
|
|
Average - assuming
dilution
|
850.8
|
850.9
|
|
850.6
|
850.7
|
|
|
|
|
|
|
(a)
|
Return on capital
employed is the rolling average net income excluding after-tax cost
of financing divided by the average rolling four
quarters' capital employed.
|
IMPERIAL OIL
LIMITED
|
|
|
|
|
|
Attachment
II
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third
Quarter
|
|
Nine
Months
|
millions of Canadian
dollars
|
2016
|
2015
|
|
2016
|
2015
|
|
|
|
|
|
|
Total cash and
cash equivalents at period end
|
248
|
366
|
|
248
|
366
|
|
|
|
|
|
|
Net income
(loss)
|
1,003
|
479
|
|
721
|
1,020
|
Adjustments for
non-cash items:
|
|
|
|
|
|
|
Depreciation and
depletion
|
398
|
400
|
|
1,229
|
1,052
|
|
(Gain) loss on asset
sales
|
(909)
|
(29)
|
|
(952)
|
(80)
|
|
Deferred income taxes
and other
|
215
|
86
|
|
35
|
358
|
Changes in operating
assets and liabilities
|
65
|
168
|
|
231
|
(588)
|
Cash flows from
(used in) operating activities
|
772
|
1,104
|
|
1,264
|
1,762
|
|
|
|
|
|
|
Cash flows from
(used in) investing activities
|
1,005
|
(619)
|
|
350
|
(2,345)
|
|
Proceeds associated
with asset sales
|
1,194
|
28
|
|
1,244
|
118
|
|
|
|
|
|
|
Cash flows from
(used in) financing activities
|
(1,724)
|
(147)
|
|
(1,569)
|
734
|
|
|
|
|
|
|
IMPERIAL OIL
LIMITED
|
|
|
|
|
|
Attachment
III
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third
Quarter
|
|
Nine
Months
|
millions of Canadian
dollars
|
2016
|
2015
|
|
2016
|
2015
|
|
|
|
|
|
|
Net income (loss)
(U.S. GAAP)
|
|
|
|
|
|
|
Upstream
|
(26)
|
(52)
|
|
(764)
|
(415)
|
|
Downstream
|
1,002
|
454
|
|
1,393
|
1,234
|
|
Chemical
|
56
|
78
|
|
160
|
213
|
|
Corporate and
other
|
(29)
|
(1)
|
|
(68)
|
(12)
|
|
Net income
(loss)
|
1,003
|
479
|
|
721
|
1,020
|
|
|
|
|
|
|
Revenues and other
income
|
|
|
|
|
|
|
Upstream
|
2,026
|
2,081
|
|
5,237
|
6,410
|
|
Downstream
|
6,094
|
5,623
|
|
15,078
|
16,037
|
|
Chemical
|
340
|
360
|
|
955
|
1,082
|
|
Eliminations /
Other
|
(1,018)
|
(909)
|
|
(2,358)
|
(2,870)
|
|
Revenues and other
income
|
7,442
|
7,155
|
|
18,912
|
20,659
|
|
|
|
|
|
|
Purchases of crude
oil and products
|
|
|
|
|
|
|
Upstream
|
861
|
879
|
|
2,584
|
2,787
|
|
Downstream
|
3,827
|
3,906
|
|
10,139
|
11,172
|
|
Chemical
|
188
|
176
|
|
518
|
563
|
|
Eliminations
|
(1,019)
|
(908)
|
|
(2,357)
|
(2,869)
|
|
Purchases of crude
oil and products
|
3,857
|
4,053
|
|
10,884
|
11,653
|
|
|
|
|
|
|
Production and
manufacturing
|
|
|
|
|
|
|
Upstream
|
887
|
923
|
|
2,634
|
2,826
|
|
Downstream
|
323
|
377
|
|
1,059
|
1,125
|
|
Chemical
|
51
|
51
|
|
149
|
154
|
|
Eliminations
|
-
|
-
|
|
-
|
-
|
|
Production and
manufacturing
|
1,261
|
1,351
|
|
3,842
|
4,105
|
|
|
|
|
|
|
Capital and
exploration expenditures
|
|
|
|
|
|
|
Upstream
|
149
|
1,050
|
|
745
|
2,644
|
|
Downstream
|
38
|
55
|
|
145
|
276
|
|
Chemical
|
7
|
17
|
|
21
|
33
|
|
Corporate and
other
|
11
|
20
|
|
37
|
58
|
|
Capital and
exploration expenditures
|
205
|
1,142
|
|
948
|
3,011
|
|
|
|
|
|
|
|
Exploration expenses
charged to income included above
|
16
|
19
|
|
75
|
52
|
|
|
|
|
|
|
IMPERIAL OIL
LIMITED
|
|
|
|
|
Attachment
IV
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating
statistics
|
Third
Quarter
|
|
Nine
Months
|
|
2016
|
2015
|
|
2016
|
2015
|
|
|
|
|
|
|
Gross crude oil
and Natural Gas Liquids (NGL) production
|
|
|
|
|
|
(thousands of barrels
per day)
|
|
|
|
|
|
|
Cold Lake
|
157
|
166
|
|
162
|
160
|
|
Kearl
|
113
|
128
|
|
120
|
96
|
|
Syncrude
|
85
|
59
|
|
61
|
61
|
|
Conventional
|
14
|
12
|
|
14
|
14
|
|
Total crude oil
production
|
369
|
365
|
|
357
|
331
|
|
NGLs available for
sale
|
1
|
2
|
|
1
|
2
|
|
Total crude oil and
NGL production
|
370
|
367
|
|
358
|
333
|
|
|
|
|
|
|
Gross natural gas
production (millions of cubic feet per day)
|
135
|
116
|
|
131
|
132
|
|
|
|
|
|
|
Gross
oil-equivalent production (a)
|
393
|
386
|
|
380
|
355
|
(thousands of
oil-equivalent barrels per day)
|
|
|
|
|
|
|
|
|
|
|
|
Net crude oil and
NGL production (thousands of barrels per day)
|
|
|
|
|
|
|
Cold Lake
|
134
|
141
|
|
137
|
141
|
|
Kearl
|
110
|
125
|
|
118
|
94
|
|
Syncrude
|
85
|
58
|
|
61
|
57
|
|
Conventional
|
12
|
13
|
|
13
|
13
|
|
Total crude oil
production
|
341
|
337
|
|
329
|
305
|
|
NGLs available for
sale
|
1
|
1
|
|
1
|
1
|
|
Total crude oil and
NGL production
|
342
|
338
|
|
330
|
306
|
|
|
|
|
|
|
Net natural gas
production (millions of cubic feet per day)
|
122
|
118
|
|
125
|
127
|
|
|
|
|
|
|
Net oil-equivalent
production (a)
|
362
|
358
|
|
351
|
327
|
(thousands of
oil-equivalent barrels per day)
|
|
|
|
|
|
|
|
|
|
|
|
Cold Lake blend
sales (thousands of barrels per day)
|
198
|
211
|
|
213
|
212
|
Kearl blend
sales (thousands of barrels per day)
|
146
|
170
|
|
161
|
120
|
NGL sales
(thousands of barrels per day)
|
5
|
5
|
|
5
|
6
|
|
|
|
|
|
|
Average
realizations (Canadian dollars)
|
|
|
|
|
|
|
Bitumen realizations
(per barrel)
|
30.16
|
32.61
|
|
23.77
|
36.48
|
|
Synthetic oil
realizations (per barrel)
|
58.97
|
61.21
|
|
53.45
|
63.03
|
|
Conventional crude
oil realizations (per barrel)
|
40.33
|
37.72
|
|
33.51
|
37.68
|
|
NGL realizations (per
barrel)
|
11.50
|
6.48
|
|
13.21
|
13.94
|
|
Natural gas
realizations (per thousand cubic feet)
|
2.56
|
1.75
|
|
2.17
|
2.44
|
|
|
|
|
|
|
Refinery
throughput (thousands of barrels per day)
|
407
|
390
|
|
351
|
385
|
Refinery capacity
utilization (percent)
|
97
|
93
|
|
83
|
92
|
|
|
|
|
|
|
Petroleum product
sales (thousands of barrels per day)
|
|
|
|
|
|
|
Gasolines
|
275
|
261
|
|
262
|
247
|
|
Heating, diesel and
jet fuels
|
171
|
168
|
|
167
|
173
|
|
Heavy fuel
oils
|
17
|
16
|
|
14
|
17
|
|
Lube oils and other
products
|
42
|
50
|
|
38
|
45
|
|
Net petroleum
products sales
|
505
|
495
|
|
481
|
482
|
|
|
|
|
|
|
Petrochemical
sales (thousands of tonnes)
|
242
|
239
|
|
704
|
706
|
|
|
|
|
|
|
(a)
|
Gas converted to
oil-equivalent at six million cubic feet per one thousand
barrels.
|
IMPERIAL OIL
LIMITED
|
|
|
|
|
|
Attachment
V
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
per
|
|
Net income (loss)
(U.S. GAAP)
|
|
common share -
diluted
|
|
(millions of Canadian
dollars)
|
|
(dollars)
|
|
|
|
|
2012
|
|
|
|
First
Quarter
|
1,015
|
|
1.19
|
Second
Quarter
|
635
|
|
0.75
|
Third
Quarter
|
1,040
|
|
1.22
|
Fourth
Quarter
|
1,076
|
|
1.26
|
Year
|
3,766
|
|
4.42
|
|
|
|
|
2013
|
|
|
|
First
Quarter
|
798
|
|
0.94
|
Second
Quarter
|
327
|
|
0.38
|
Third
Quarter
|
647
|
|
0.76
|
Fourth
Quarter
|
1,056
|
|
1.24
|
Year
|
2,828
|
|
3.32
|
|
|
|
|
2014
|
|
|
|
First
Quarter
|
946
|
|
1.11
|
Second
Quarter
|
1,232
|
|
1.45
|
Third
Quarter
|
936
|
|
1.10
|
Fourth
Quarter
|
671
|
|
0.79
|
Year
|
3,785
|
|
4.45
|
|
|
|
|
2015
|
|
|
|
First
Quarter
|
421
|
|
0.50
|
Second
Quarter
|
120
|
|
0.14
|
Third
Quarter
|
479
|
|
0.56
|
Fourth
Quarter
|
102
|
|
0.12
|
Year
|
1,122
|
|
1.32
|
|
|
|
|
2016
|
|
|
|
First
Quarter
|
(101)
|
|
(0.12)
|
Second
Quarter
|
(181)
|
|
(0.21)
|
Third
Quarter
|
1,003
|
|
1.18
|
|
721
|
|
0.85
|
After more than a century, Imperial continues
to be an industry leader in applying technology and innovation to
responsibly develop Canada's
energy resources. As Canada's
largest petroleum refiner, a major producer of crude oil and
natural gas, a key petrochemical producer and a leading fuels
marketer from coast to coast, our company remains committed to high
standards across all areas of our business.
SOURCE Imperial Oil Limited