Market Overview

Imperial earns $196 million in the second quarter of 2018

Share:

Imperial Oil Limited (TSX:IMO):

  • Nearly $900 million of cash generated from operations; more than $1
    billion returned to shareholders
  • Renewed share purchase program; returned $1.6 billion to shareholders
    under prior 12-month program
  • Major upstream and downstream planned maintenance completed;
    positioned for strong second half
 
    Second quarter     Six months
millions of Canadian dollars, unless noted     2018   2017   %     2018   2017   %
Net income (loss) (U.S. GAAP) 196   (77 )   355 712   256   178
Net income (loss) per common share 0.24 (0.09 ) 367 0.86 0.30 187
- assuming dilution (dollars)
Capital and exploration expenditures 284 143 99 558 296 89

Estimated net income in the second quarter of 2018 was $196 million, an
increase of $273 million compared to the net loss of $77 million in the
same period of 2017.

The quarter was characterized by significant planned maintenance at
Imperial's major upstream and downstream assets. These activities
affected operational results and were aligned with the company's
commitment to maintain safe and reliable operations. Planned turnarounds
occurred at one of Kearl's two plants, Cold Lake's second largest plant,
Syncrude's largest coker, and at Strathcona, the company's largest
refinery.

"Completion of the heavy maintenance schedule in the second quarter
positions the company for strong operational performance in the second
half of 2018," said Rich Kruger, chairman, president and chief executive
officer.

Refinery throughput averaged 363,000 barrels per day and petroleum
product sales averaged 510,000 barrels per day. Despite the Strathcona
refinery turnaround, Imperial achieved its highest quarterly sales
volumes in nearly 30 years, demonstrating the company's commitment to
grow sales and reliably supply customers. To maximize value, Imperial
continued to leverage its logistics and processing capabilities to take
advantage of discounted Canadian heavy crude prices.

Upstream gross oil-equivalent production was 336,000 barrels per day,
reflecting the impact of planned turnaround activities. Recovery from
the June 20 power outage at Syncrude is ongoing with partial production
restored in July and return to full rates anticipated in September. The
company continued to progress activities to enhance future operations,
including construction to add supplemental crushing capacity at Kearl
and scaled application of new solvent technology at Cold Lake.

In the quarter, Imperial renewed its share purchase program, allowing
the company to buy approximately 40 million shares over the 12-months
ending June 26, 2019. Under the prior program that ended June 26, 2018,
Imperial purchased 41 million shares for $1.6 billion. In the first half
of 2018, Imperial returned $1.4 billion to shareholders through share
purchases and dividends. Imperial's approach to capital allocation
focuses on maintaining a strong balance sheet, paying a reliable and
growing dividend, investing in attractive growth opportunities and
returning surplus cash to shareholders through share buybacks.

"Our business model offers distinct competitive advantages that are
difficult for others to replicate," added Kruger. "We are focused on
capitalizing on these advantages to maximize near-term business results
and long-term shareholder value."

Second quarter highlights

  • Net income of $196 million or $0.24 per share on a diluted basis, an
    increase of $273 million compared to a net loss of $77 million or
    $0.09 per share in the second quarter of 2017.
  • Cash generated from operating activities was $859 million, an
    increase of $367 million from the second quarter of 2017.
  • Capital and exploration expenditures totalled $284 million, an
    increase of $141 million from the second quarter of 2017. Spending
    continues to be focused on sustaining capital and previously announced
    projects. Previous full-year guidance for capital expenditures was in
    the range of $1.5 billion to $1.7 billion. Spending is now expected to
    be at the low end of the range.
  • Dividends paid and share purchases totalled $1,025 million in the
    second quarter of 2018
    , including the purchase of approximately
    21.4 million shares at a cost of $893 million. Higher share purchases
    in the second quarter reflect the amendment in April to increase the
    share limit under the program that ended June 26, 2018.
  • Renewal of share purchase program continues commitment to deliver
    shareholder value.
    In June, Imperial received Toronto Stock
    Exchange approval to continue its program enabling the purchase of up
    to five percent of its common shares outstanding, approximately 40
    million shares, during the 12-month period ending June 26, 2019. The
    company's cash generation capability supports its ability to flexibly
    return surplus cash to shareholders through share buybacks.
  • Production averaged 336,000 gross oil-equivalent barrels per day,
    up from 331,000 barrels per day in the same period of 2017.
  • Cold Lake bitumen production averaged 133,000 barrels per day, compared
    to 160,000 barrels per day in the same quarter of 2017. Lower volumes
    were primarily due to planned maintenance and production timing.
    Imperial completed its first major turnaround in three years at Cold
    Lake. Specifically, a planned 38-day turnaround was completed at the
    Maskwa facility, the second largest of Cold Lake's five plants. In
    addition, production in the quarter was affected by later
    implementation of new solvent-based recovery technology.
  • Gross production of Kearl bitumen averaged 180,000 barrels per day
    in the quarter
    (128,000 barrels Imperial's share), up from 171,000
    barrels per day (121,000 barrels Imperial's share) in the same period
    of 2017. Production was impacted by 48,000 barrels per day (34,000
    barrels Imperial's share) associated with planned turnaround
    activities at one of the two plants. The company continued to progress
    reliability improvements during the quarter, including construction
    activities to add supplemental crushing capacity. Imperial continues
    to expect annual average gross production at Kearl of 200,000 barrels
    per day in 2018.
  • The company's share of gross production from Syncrude averaged
    50,000 barrels per day
    , up from 27,000 barrels per day in the
    second quarter of 2017. Production in the quarter was impacted by
    about 25,000 barrels per day (Imperial's share) associated with
    planned turnaround activities, focused on the largest of its three
    cokers. On June 20, Syncrude experienced a power disruption that
    resulted in a shutdown of all processing units. Shipments have since
    resumed with return to full production anticipated in mid-September.
  • Refinery throughput averaged 363,000 barrels per day, up from
    358,000 barrels per day in the second quarter of 2017. Capacity
    utilization was 86 percent, reflecting the impact of a 72-day planned
    turnaround at the Strathcona facility completed in mid-June. Excluding
    maintenance impacts, utilization was estimated to be 94 percent in the
    quarter. The turnaround at Strathcona, the largest in its history,
    impacted earnings by about $250 million relative to the first quarter
    of 2018.
  • Petroleum product sales were 510,000 barrels per day, up from
    486,000 barrels per day in the second quarter of 2017. Imperial
    successfully sourced product by leveraging its refining network,
    building inventory and third-party purchases to reliably supply its
    customers during the planned turnaround at its Strathcona refinery.
  • Matched best-ever quarterly chemical earnings of $78 million,
    up from $64 million in the same period of 2017. Imperial continues to
    deliver excellent results in its chemical business through high
    reliability, price-advantaged feedstocks and strong market pricing.
  • Successfully deployed the largest autonomous haul truck in the
    world at Kearl.
    As part of an ongoing pilot, Imperial along with
    its development partners moved the first payload using a fully
    autonomous 400-ton haul truck in June. This is the largest autonomous
    truck put into a productive operating environment. The company's
    testing program is targeted to ramp up to a fleet of seven autonomous
    trucks by year-end.
  • Imperial supports Indigenous leaders at the G7 Women's Forum
    Canada.
    The company sponsored a panel discussion showcasing the
    accomplishments and leadership of Indigenous women at the Women's
    Forum for the Economy and Society held in Toronto in May. Imperial is
    committed to the advancement of women across Canada and has invested
    more than $2 million in leadership programs over the past five years.

Second quarter 2018 vs. second quarter 2017

The company's net income for the second quarter of 2018 was $196 million
or $0.24 per share on a diluted basis, an increase of $273 million
compared to the net loss of $77 million or $0.09 per share, for the same
period last year.

Upstream recorded a net loss in the second quarter of $6 million
compared to a net loss of $201 million in the same period of 2017.
Improved results reflect the impact of higher Canadian crude oil
realizations of about $280 million, partially offset by higher royalty
costs of about $50 million and higher operating expenses of about $50
million mainly associated with planned turnarounds.

West Texas Intermediate (WTI) averaged US$67.91 per barrel in the second
quarter of 2018, up from US$48.20 per barrel in the same quarter of
2017. Western Canada Select (WCS) averaged US$48.81 per barrel and
US$37.18 per barrel respectively for the same periods. The WTI / WCS
differential widened to approximately US$19 per barrel in the second
quarter of 2018, from approximately US$11 per barrel in the same period
of 2017.

The Canadian dollar averaged US$0.78 in the second quarter of 2018, an
increase of US$0.04 from the second quarter of 2017.

Imperial's average Canadian dollar realizations for bitumen and
synthetic crudes increased generally in line with the North American
benchmarks, adjusted for changes in exchange rates and transportation
costs. Bitumen realizations averaged $48.90 per barrel for the second
quarter of 2018, an increase of $10.68 per barrel versus the second
quarter of 2017. Synthetic crude realizations averaged $86.31 per
barrel, an increase of $21.24 per barrel for the same period of 2017.

Gross production of Cold Lake bitumen averaged 133,000 barrels per day
in the second quarter, compared to 160,000 barrels per day in the same
period last year. Lower volumes were primarily due to planned
maintenance and production timing.

Gross production of Kearl bitumen averaged 180,000 barrels per day in
the second quarter (128,000 barrels Imperial's share), up from 171,000
barrels per day (121,000 barrels Imperial's share) during the second
quarter of 2017. Higher production was mainly the result of mining
optimization, partially offset by planned turnaround activities.

The company's share of gross production from Syncrude averaged 50,000
barrels per day, up from 27,000 barrels per day in the second quarter of
2017. Higher production was due to the absence of the Syncrude Mildred
Lake upgrader fire that occurred in March 2017, partially offset by
planned turnaround activities and a power disruption that occurred on
June 20, 2018, resulting in a complete shutdown of all processing units
for the remainder of the second quarter. Recovery from the power outage
is ongoing with partial production restored in July and return to full
rates anticipated in September.

Downstream net income was $201 million in the second quarter, up from
$78 million in the second quarter of 2017. Earnings increased mainly due
to stronger margins of about $390 million, partially offset by the
impact of increased planned turnaround activity of about $200 million,
and the impact of a stronger Canadian dollar.

Refinery throughput averaged 363,000 barrels per day, up from 358,000
barrels per day in the second quarter of 2017. Capacity utilization
increased to 86 percent from 85 percent in the second quarter of 2017.

Petroleum product sales were 510,000 barrels per day, up from 486,000
barrels per day in the second quarter of 2017. Sales growth continues to
be driven by optimization across the full Downstream value chain, and
the expansion of Imperial's logistics capabilities.

Chemical net income of $78 million in the second quarter matched
best-ever quarterly results. Earnings increased $14 million from the
same period of 2017, benefitting from increased volumes and margins.

Corporate and other expenses were $77 million in the second quarter,
compared to $18 million in the same period of 2017, primarily due to
higher share-based compensation charges. In addition, as part of the
implementation of the Financial Accounting Standards Board's update,
Compensation – Retirement Benefits (Topic 715): Improving the
Presentation of Net Periodic Pension Cost and Net Periodic
Postretirement Benefit Cost
, beginning January 1, 2018, Corporate
and other includes all non-service pension and postretirement benefit
expenses. Prior to 2018, the majority of these costs were allocated to
the operating segments.

Cash flow generated from operating activities was $859 million in the
second quarter, an increase of $367 million from the corresponding
period in 2017, reflecting higher earnings.

Investing activities used net cash of $379 million in the second
quarter, compared with $281 million used in the same period of 2017.

Cash used in financing activities was $1,032 million in the second
quarter, compared with $260 million used in the second quarter of 2017.
Dividends paid in the second quarter of 2018 were $132 million. The per
share dividend paid in the second quarter was $0.16, up from $0.15 in
the same period of 2017. During the second quarter, the company
purchased about 21.4 million shares for $893 million.

The company's cash balance was $873 million at June 30, 2018, versus
$623 million at the end of second quarter 2017.

On April 27, 2018, the company announced by news release that it had
received final approval from the Toronto Stock Exchange for an amendment
to its normal course issuer bid to increase the number of common shares
that it may purchase. Under the amendment, the number of common shares
eligible for purchase increased to a maximum of 42,326,545 common shares
during the period June 27, 2017 to June 26, 2018.

On June 22, 2018, the company announced by news release that it had
received final approval from the Toronto Stock Exchange for a new normal
course issuer bid and will continue its existing share purchase program.
The program enables the company to purchase up to a maximum of
40,391,196 common shares during the period June 27, 2018 to June 26,
2019. This maximum includes shares purchased under the normal course
issuer bid and from Exxon Mobil Corporation concurrent with, but outside
of the normal course issuer bid. As in the past, Exxon Mobil Corporation
has advised the company that it intends to participate to maintain its
ownership percentage at approximately 69.6 percent. The program will end
should the company purchase the maximum allowable number of shares, or
on June 26, 2019. The company currently anticipates exercising its share
purchases uniformly over the duration of the program. Purchase plans may
be modified at any time without prior notice.

Six months highlights

  • Net income of $712 million, up from net income of $256 million in the
    prior year.
  • Net income per share on a diluted basis was $0.86, up from net income
    per share of $0.30 in 2017.
  • Cash flow generated from operating activities was $1,844 million, up
    from $846 million in 2017.
  • Gross oil-equivalent production averaged 353,000 barrels per day,
    compared to 354,000 barrels per day in 2017.
  • Refinery throughput averaged 386,000 barrels per day, up from 378,000
    barrels per day in 2017.
  • Returned $1.4 billion to shareholders through share purchases and
    dividends.
  • Per share dividends declared during the first six months totalled
    $0.35, up $0.04 per share from 2017.
  • Record first half Chemical net income of $151 million.

Six months 2018 vs. six months 2017

Net income in the first six months of 2018 was $712 million, or $0.86
per share on a diluted basis, an increase of $456 million compared to a
net income of $256 million or $0.30 per share in the first six months of
2017.

Upstream recorded a net loss of $50 million in the first six months of
2018, compared to a net loss of $287 million from the same period of
2017. Improved results reflect the impact of higher Canadian crude oil
realizations of about $350 million, partially offset by the impact of
higher operating costs of about $50 million mainly associated with
planned turnarounds. Results also reflect the impact of higher royalties
and the strengthening of the Canadian dollar compared to the prior year.

West Texas Intermediate averaged US$65.44 per barrel in the first six
months of 2018, up from US$49.96 per barrel in the prior year. Western
Canada Select averaged US$43.74 per barrel and US$37.22 per barrel
respectively for the same periods. The WTI / WCS differential widened to
approximately US$22 per barrel in the first six months of 2018, from
approximately US$13 per barrel in the same period of 2017.

The Canadian dollar averaged US$0.78 in the first six months of 2018, an
increase of about US$0.03 from the same period of 2017.

Imperial's average Canadian dollar realizations for bitumen and
synthetic crudes increased generally in line with the North American
benchmarks, adjusted for changes in the exchange rate and transportation
costs. Bitumen realizations averaged $41.84 per barrel for the first six
months of 2018, an increase of $4.63 per barrel versus 2017. Synthetic
crude realizations averaged $81.24 per barrel, an increase of $14.24 per
barrel from the same period of 2017.

Gross production of Cold Lake bitumen averaged 143,000 barrels per day
in the first six months of 2018, compared to 159,000 barrels per day
from the same period of 2017. Lower volumes were primarily due to
planned maintenance and production timing.

Gross production of Kearl bitumen averaged 181,000 barrels per day in
the first six months of 2018 (128,000 barrels Imperial's share) up from
177,000 barrels per day (125,000 barrels Imperial's share) from the same
period of 2017.

During the first six months of 2018, the company's share of gross
production from Syncrude averaged 57,000 barrels per day, up from 46,000
barrels per day from the same period of 2017. Higher production was due
to the absence of the impact associated with the March 2017 fire at the
Syncrude Mildred Lake upgrader, partially offset by planned turnaround
activities, and a power disruption that occurred on June 20, 2018,
resulting in a complete shutdown of all processing units for the
remainder of the second quarter. Recovery from the power outage is
ongoing with partial production restored in July and return to full
rates anticipated in September.

Downstream net income was $722 million, an increase of $264 million
versus the prior year. Higher earnings reflect stronger margins of about
$690 million, partially offset by the impact of increased planned
turnaround activity of about $200 million, the impact of a stronger
Canadian dollar of about $60 million and the absence of the $151 million
gain on the sale of a surplus property in 2017.

Refinery throughput averaged 386,000 barrels per day in the first six
months of 2018, up from 378,000 barrels per day from the same period of
2017. Capacity utilization increased to 91 percent from 90 percent in
the same period of 2017.

Petroleum product sales were 494,000 barrels per day in the first six
months of 2018, up from 486,000 barrels per day from the same period of
2017. Sales growth continues to be driven by optimization across the
full Downstream value chain, and the expansion of Imperial's logistics
capabilities.

Chemical net income was $151 million, up from $109 million in the first
half of 2017, primarily due to higher margins and volumes.

Corporate and other expenses were $111 million for the first six months
of 2018, compared to $24 million in the same period of 2017, primarily
due to higher share-based compensation charges. In addition, beginning
January 1, 2018, Corporate and other includes all non-service pension
and postretirement benefit expenses. Prior to 2018, the majority of
these costs were allocated to the operating segments.

Cash flow generated from operating activities was $1,844 million in the
first six months of 2018, compared with $846 million from the same
period of 2017, reflecting higher earnings and working capital effects.

Investing activities used net cash of $744 million in the first six
months of 2018, compared with $220 million used in the same period of
2017, reflecting higher additions to property, plant and equipment, and
lower proceeds from asset sales.

Cash used in financing activities was $1,422 million in the first six
months of 2018, compared with $394 million used in the same period of
2017. Dividends paid in the first six months of 2018 were $266 million.
The per share dividend paid in the first six months of 2018 was $0.32,
up from $0.30 from the same period of 2017. During the first six months
of 2018, the company purchased about 28.6 million shares for $1,143
million, including shares purchased from Exxon Mobil Corporation.

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 and margin
impacts; limitations on transportation for accessing markets; political
or regulatory events, including changes in law or government policy;
applicable royalty rates and tax laws; the receipt, in a timely manner,
of regulatory and third-party approvals; third-party opposition to
operations and projects; environmental risks inherent in oil and gas
exploration and production activities; environmental regulation,
including climate change and greenhouse gas restrictions; currency
exchange rates; availability and allocation of capital; performance of
third-party service providers; unanticipated operational disruptions;
management effectiveness; commercial negotiations; project management
and schedules; response to unexpected technological developments;
operational hazards and risks; disaster response preparedness; the
ability to develop or acquire additional reserves; 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.

In this report all dollar amounts are expressed in Canadian dollars
unless otherwise stated. This report should be read in conjunction with
Imperial's most recent Form 10-K. Note that numbers may not add due to
rounding.

The term "project" as used in this report can refer to a variety of
different activities and does not necessarily have the same meaning as
in any government payment transparency reports.

 
    Attachment I
   
 
Second Quarter Six Months
millions of Canadian dollars, unless noted   2018   2017   2018   2017
 
Net Income (loss) (U.S. GAAP)
Total revenues and other income 9,543 7,033 17,477 14,189
Total expenses   9,279   7,158     16,516   13,894
Income (loss) before income taxes 264 (125 ) 961 295
Income taxes   68   (48 )   249   39
Net income (loss)   196   (77 )   712   256
 
Net income (loss) per common share (dollars) 0.24 (0.09 ) 0.86 0.30
Net income (loss) per common share - assuming dilution (dollars) 0.24 (0.09 ) 0.86 0.30
 
Other Financial Data
Gain (loss) on asset sales, after-tax 8 28 15 186
Total assets at June 30 41,390 41,105
 
Total debt at June 30 5,194 5,222
Interest coverage ratio - earnings basis (times covered) 11.8 26.3
 
Other long-term obligations at June 30 3,943 3,678
 
Shareholders' equity at June 30 23,765 25,000
Capital employed at June 30 28,978 30,240
Return on average capital employed (percent) (a) 3.4 9.0
 
Dividends declared on common stock
Total 155 136 287 263
Per common share (dollars) 0.19 0.16 0.35 0.31
 
Millions of common shares outstanding
At June 30 802.7 844.3
Average - assuming dilution 818.8 849.9 825.2 850.1

 

(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.
 
Attachment II
 
 
  Second Quarter   Six Months
millions of Canadian dollars   2018   2017   2018   2017
   
Total cash and cash equivalents at period end 873 623 873 623
 
Net income (loss) 196 (77 ) 712 256
Adjustments for non-cash items:
Depreciation and depletion 358 352 735 744
(Gain) loss on asset sales (9 ) (31 ) (19 ) (213 )
Deferred income taxes and other 24 (37 ) 209 163
Changes in operating assets and liabilities   290     285     207     (104 )
Cash flows from (used in) operating activities   859     492     1,844     846  
 
Cash flows from (used in) investing activities (379 ) (281 ) (744 ) (220 )
Proceeds associated with asset sales 9 39 21 222
 
Cash flows from (used in) financing activities (1,032 ) (260 ) (1,422 ) (394 )
                         
 

Attachment III

   
Second Quarter Six Months
millions of Canadian dollars   2018   2017   2018   2017
   
Net income (loss) (U.S. GAAP)
Upstream (6 ) (201 ) (50 ) (287 )
Downstream 201 78 722 458
Chemical 78 64 151 109
Corporate and other   (77 )   (18 )   (111 )   (24 )
Net income (loss)   196     (77 )   712     256  
 
Revenues and other income
Upstream 2,971 2,081 5,618 4,415
Downstream 7,221 5,193 13,212 10,667
Chemical 402 349 779 690
Eliminations / Corporate and other   (1,051 )   (590 )   (2,132 )   (1,583 )
Revenues and other income   9,543     7,033     17,477     14,189  
 
Purchases of crude oil and products
Upstream 1,573 1,026 2,947 2,142
Downstream 5,803 4,014 10,097 8,023
Chemical 216 193 418 394
Eliminations   (1,055 )   (591 )   (2,145 ) (1,584 )
Purchases of crude oil and products   6,537     4,642     11,317     8,975  
 
Production and manufacturing expenses
Upstream 1,106 1,051 2,118 2,024
Downstream 488 426 856 775
Chemical 52 48 103 101
Eliminations   -     -     -   -  
Production and manufacturing expenses   1,646     1,525     3,077     2,900  
 
Capital and exploration expenditures
Upstream 183 91 389 194
Downstream 88 39 145 73
Chemical 7 3 11 7
Corporate and other   6     10     13     22  
Capital and exploration expenditures   284     143     558     296  
 
Exploration expenses charged to income included above 1 - 9 22
                         
 

Attachment IV

   
 
Operating statistics Second Quarter Six Months
    2018   2017   2018   2017
   
Gross crude oil and natural gas liquids (NGL) production
(thousands of barrels per day)
Cold Lake 133 160 143 159
Kearl 128 121 128 125
Syncrude 50 27 57 46
Conventional   3   3   4   4
Total crude oil production 314 311 332 334
NGLs available for sale   1   1   1   1
Total crude oil and NGL production   315   312   333   335
 
Gross natural gas production (millions of cubic feet per day) 128 116 123 116
 
Gross oil-equivalent production (a) 336 331 353 354
(thousands of oil-equivalent barrels per day)
 
Net crude oil and NGL production (thousands of barrels per
day)
Cold Lake 104 132 116 129
Kearl 122 118 123 122
Syncrude 46 25 53 43
Conventional   3   3   4   4
Total crude oil production 275 278 296 298
NGLs available for sale   1   1   1   1
Total crude oil and NGL production   276   279   297   299
 
Net natural gas production (millions of cubic feet per day) 122 105 119 106
 
Net oil-equivalent production (a) 296 297 317 317
(thousands of oil-equivalent barrels per day)
 
Cold Lake blend sales (thousands of barrels per day) 182 209 200 215
Kearl blend sales (thousands of barrels per day) 171 161 182 166
NGL sales (thousands of barrels per day) 4 6 5 6
 
Average realizations (Canadian dollars)
Bitumen (per barrel) 48.90 38.22 41.84 37.21
Synthetic oil (per barrel) 86.31 65.07 81.24 67.00
Conventional crude oil (per barrel) 74.55 51.62 69.00 52.39
NGL (per barrel) 35.30 27.83 40.08 28.54
Natural gas (per thousand cubic feet) 2.01 3.05 2.46 3.18
 
Refinery throughput (thousands of barrels per day) 363 358 386 378
Refinery capacity utilization (percent) 86 85 91 90
 
Petroleum product sales (thousands of barrels per day)
Gasolines 259 257 249 250
Heating, diesel and jet fuels 178 175 182 182
Heavy fuel oils 31 19 24 19
Lube oils and other products   42   35   39   35
Net petroleum products sales   510   486   494   486
 
Petrochemical sales (thousands of tonnes) 217 201 418 394
(a)   Gas converted to oil-equivalent at six million cubic feet per one
thousand barrels.
 
Attachment V
 
 

 

 

 

 

Net income (loss) (U.S. GAAP)

millions of Canadian dollars

 

Net income (loss) per
common share - diluted

dollars

   
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
Fourth Quarter   1,444     1.70  
Year   2,165     2.55  
 
2017
First Quarter 333 0.39
Second Quarter (77 ) (0.09 )
Third Quarter 371 0.44
Fourth Quarter   (137 )   (0.16 )
Year   490     0.58  
 
2018
First Quarter 516 0.62
Second Quarter   196     0.24  
Year   712     0.86  
 

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, 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.

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