Husky Builds Momentum in the First Quarter of 2013

Husky Builds Momentum in the First Quarter of 2013 
CALGARY, ALBERTA -- (Marketwired) -- 05/07/13 -- Husky Energy
(TSX:HSE) continued consistent execution across all business segments
as the flexibility of its focused integration strategy delivered
strong cash flow and net earnings in the first quarter. 
"We are achieving important operational milestones as we deliver on
our business plan, including the sustained high performance of our
heavy oil thermal projects," said CEO Asim Ghosh. "We are making
great progress on the Liwan Gas Project in the Asia Pacific Region,
with the topsides module set for installation on the jacket in the
South China Sea." 
Cash flow from operations was approximately $1.3 billion, compared to
$1.2 billion the previous year. Net earnings of $535 million were
achieved despite continuing pressure on heavy oil differentials that
saw average benchmark prices for Lloydminster heavy crude fall 22
percent from the fourth quarter of 2012.  
Total Upstream production averaged approximately 321,000 barrels of
oil equivalent per day (boe/day) with continued Downstream
reliability contributing to average throughputs of 327,000 barrels
per day (bbls/day) at the Company's refineries and upgrader. 
"Our upgrading and refining assets continue to diminish volatility in
earnings and cash flow by enabling the capture of world pricing for
our Western Canada production," said Ghosh. 
Performance Highlights Include: 

--  Cash flow from operations in the first quarter was up approximately
    eight percent at $1.3 billion, or $1.30 per share (diluted), compared
    with approximately $1.2 billion, or $1.20 per share (diluted) in 2012. 
--  Net earnings were $535 million, or $0.54 per share (diluted), compared
    to $591 million, or $0.60 per share (diluted) in the first quarter of
    2012, reflecting lower crude prices. 
--  Total Upstream production was 321,000 boe/day, up from 320,000 boe/day
    in the first quarter of 2012, with production weighted 72 percent
    towards oil and liquids compared to 69 percent in the first quarter of
--  Topsides for the Liwan Gas Project in the Asia Pacific Region have been
    loaded out, with installation scheduled for the second quarter and first
    gas anticipated in the late 2013/early 2014 timeframe. 
--  Phase 1 of the Sunrise Energy Project is approximately two-thirds
    complete with first production on track for 2014. 
--  Filed regulatory application for a 3,000 bbls/day bitumen carbonate
    pilot at Saleski. 
--  Construction is approximately 55 percent complete on the 3,500 bbls/day
    Sandall heavy oil thermal project, with planned startup in 2014. 
--  Development drilling has commenced at the South White Rose extension in
    the Atlantic Region for planned first production in 2014. 
--  Completed Front-End Engineering Design (FEED) for the West White Rose
--  A 20,000 bbls/day kerosene hydrotreater has started operations at the
    Lima Refinery in Ohio to provide additional distillate capacity and
    increased flexibility between on-road diesel and jet fuel production. 
FINANCIAL AND OPERATIONAL HIGHLIGHTS                                        
                                                Three Months Ended          
                                            Mar 31       Dec 31       Mar 31
                                              2013         2012         2012
1) Daily Production, before royalties                                       
  Total Equivalent Production                                               
   (mboe/day)                                  321          319          320
  Crude Oil and NGLs (mbbls/day)               231          232          222
  Natural Gas (mmcf/day)                       537          524          588
2) Total Upstream Netback ($/boe) (1)        31.78        35.99        43.00
3) Refinery and Upgrader Throughput                                         
 (mbbls/day)                                   327          335          324
4) Cash Flow from Operations(2) (Cdn                                        
 $ millions)                                 1,283        1,414        1,172
  Per Common Share - Basic ($/share)          1.31         1.44         1.21
  Per Common Share - Diluted                                                
   ($/share)                                  1.30         1.44         1.20
5) Net Earnings (Cdn $ millions)               535          474          591
  Per Common Share - Basic ($/share)          0.54         0.48         0.61
  Per Common Share - Diluted                                                
   ($/share)                                  0.54         0.48         0.60
6) Adjusted Net Earnings(2) (Cdn $                                          
 millions)                                     547          487          566
  Per Common Share - Basic ($/share)          0.56         0.50         0.59
  Per Common Share - Diluted                                                
   ($/share)                                  0.56         0.50         0.58
7) Capital Investment, including                                            
 acquisitions (Cdn $ millions)               1,066        1,473        1,015
8) Dividend                                                                 
  Per Common Share ($/share)                  0.30         0.30         0.30
(1) Upstream Netback includes results from Upstream Exploration and         
    Production and excludes Upstream Infrastructure and Marketing.          
(2) Cash Flow from Operations and Adjusted Net Earnings are non-GAAP        
    measures. Refer to the Q1 MD&A, Section 11 for reconciliation.          

First quarter production of 321,000 boe/day reflected increased heavy
oil production, offset by a planned reduction in dry gas production
and reduced volumes from the partner-operated Terra Nova facility,
which has returned to production following its 2012 turnaround. 
The Company's average realized pricing for its crude oil, natural gas
liquids and bitumen in the first quarter was $68.32 per barrel,
compared to $87.11 per barrel in the first quarter of 2012. U.S.
realized refining margins averaged U.S. $20.47 per barrel compared to
U.S. $14.14 per barrel in the same period in 2012.  
"The industry has been challenged by volatile commodity price and
location differentials, however as part of our focused integration
strategy we have made strategic investments in our Downstream
infrastructure that allow us to diminish the impact of market
changes," said CFO Alister Cowan.  

--  Heavy Oil 

The Company continued to rejuvenate its Heavy Oil business with a
growing focus on thermal projects. 
Total production from heavy oil and thermal projects over the quarter
was about 122,000 bbls/day compared to approximately 106,000 bbls/day
in the first quarter of 2012. Total thermal developments, including
Tucker, produced about 48,000 bbls/day, up from 30,000 bbls/day a
year ago.  
Combined average volumes of approximately 18,000 boe/day were
maintained at the Pikes Peak South and Paradise Hill thermal
projects, ahead of their 11,500 bbls/day total planned design rates. 
Construction on the 3,500 bbls/day Sandall thermal development is now
approximately 55 percent complete, with initial drilling underway and
first production planned in 2014. 
Initial site work continued at the 10,000 bbls/day commercial thermal
project at Rush Lake, which remains on track for first oil in 2015.
The first single well pair pilot continues to produce and progress is
being made towards startup of a second well pair, scheduled for the
second quarter of 2013. 
Thirty-eight horizontal wells were drilled in the first quarter out
of a planned 140-well program for 2013, along with 55 Cold Heavy Oil
Production with Sand (CHOPS) wells out of a planned 200-well program. 

--  Western Canada 

The Company continued laying the foundation for the transformation of
its Western Canada business with its ongoing shift towards oil and
liquids-rich resource plays. 
Oil Resource Plays 
A total of 45 horizontal wells (gross) were drilled on five oil
resource plays in the Bakken, Lower Shaunavon, Viking, Cardium and at
Rainbow Muskwa in the first quarter. 
Two vertical wells drilled in 2012 at the Slater River Canol play in
the Northwest Territories were completed and tested during the first
quarter. Results are being evaluated and community consultations are
underway for a proposed 2013/2014 program.  
Approximately half of a 40-kilometre all-season access road was built
during the 2012-2013 winter program, with operations scheduled to
resume in the third quarter. 
Gas Resource Plays 
Ten liquids-rich wells were drilled at the Ansell liquids-rich gas
play, with 12 gas wells completed by the end of the first quarter.
Production at Ansell reached more than 14,000 boe/day in the first

--  Asia Pacific Region 

The Liwan Gas Project in the South China Sea continues to advance as
scheduled towards first gas in the late 2013/early 2014 timeframe.
Overall, approximately 85 percent of the project was complete by the
end of the first quarter. 
The 30,000-metric-tonne topsides portion of the offshore central
platform, the largest ever to be built in Asia, was loaded out on a
barge in mid-April and is set for installation onto its jacket in the
second quarter.  
The final Liwan 3-1 production well has been completed and offshore
pipe installation continues. Construction on the gas plant, including
the control and administrative buildings, is progressing with 10
liquids storage tanks in place.   
Offshore Indonesia, two shallow water gas developments in the Madura
Strait are being progressed.  
The development plan for the combined MDA/MBH field received
regulatory approval in the first quarter. Work on the BD field was
advanced with the evaluation of tender bids for a Floating
Production, Storage and Offloading (FPSO) vessel and related
infrastructure contracts.  
Four new gas discoveries made offshore Indonesia in 2012 continue to
be evaluated for commercial development. 

--  Oil Sands 

The first phase of the Sunrise Energy Project is advancing towards
first production in 2014 and is approximately two-thirds complete. 
The Central Processing Facility is progressing with all critical
equipment and modules in place for the first of two processing
plants. Field facilities are being finalized with all well pads and
pipelines scheduled for completion later this year. 
Early engineering work on the next phase of the 200,000 bbls/day
(100,000 bbls/day net) development is continuing. 
A regulatory application for a 3,000 bbls/day bitumen carbonate pilot
at Saleski has been filed. Husky's total best estimate contingent
resource holdings in its emerging oil sands portfolio, which includes
approximately 15 properties, is 11.4 billion barrels, of which
approximately 10 billion barrels have been attributed to the Saleski

--  Atlantic Region 

Husky achieved a significant milestone in the first quarter when it
reached a landmark 200 million barrels of total oil production from
the White Rose field, reflecting consistent execution over the past
eight years of operations by meeting the target originally set for
the entire life of the project. 
At the North Amethyst field, drilling began on a fourth water
injection well that is expected to be brought into service in the
third quarter of 2013. The Company's application to develop the
deeper Hibernia-level formation at North Amethyst is undergoing
regulatory review. 
Development drilling has started on the first gas injection well at
the South White Rose field. Production from South White Rose will be
tied back to the SeaRose FPSO with anticipated first production in
FEED for the West White Rose project was completed during the
quarter. The development application is currently being prepared for
The partner-operated Harpoon exploration well located near the Mizzen
discovery in the Flemish Pass has been spud and drilling is
continuing. Husky holds a 35 percent working interest in Harpoon. 
A 20,000 bbls/day kerosene hydrotreater commenced operations in
mid-April at the Lima Refinery in Ohio. The hydrotreater gives the
refinery greater flexibility to swing between on-road diesel and jet
fuel production to take advantage of market conditions while also
increasing distillate capacity. 
The partner-operated Toledo, Ohio refinery has commenced operating a
new reformer unit designed to increase efficiency and reduce costs
while allowing the Company to produce low-vapour pressure gasoline. 
Husky's Board of Directors has declared a quarterly dividend of $0.30
(Canadian) per share on its common shares for the three-month period
ending March 31, 2013. The dividend will be payable on July 2, 2013
to shareholders of record at the close of business on May 30, 2013. 
A regular quarterly dividend on the 4.45 percent Cumulative
Redeemable Preferred Shares, Series 1 (the "Series 1 Preferred
Shares") will be paid for the period April 1, 2013 to June 30, 2013.
The dividend of $0.27813 per Series 1 Preferred Share will be payable
on July 2, 2013 to holders of record at the close of business on May
30, 2013. 
A conference call will be held on Tuesday, May 7 at 8 a.m. Mountain
Time (10 a.m. Eastern Time) to discuss Husky's first quarter results.
To listen live, please call one of the following numbers: 

Canada and U.S. Toll Free:    1-800-319-4610 
Outside Canada and U.S.:      1-604-638-5340 

CEO Asim Ghosh, COO Rob Peabody, CFO Alister Cowan and Senior
Downstream VP Bob Baird will participate in the call. To listen to a
recording of the call, available at 10 a.m. Mountain Time on May 7,
please call one of the following numbers: 

Canada and U.S. Toll Free:    1-800-319-6413 
Outside Canada and U.S.:      1-604-638-9010 
Passcode:                     2658 followed by the # sign 
Duration:                     Available until June 7, 2013

Following the call, Husky will hold its Annual Meeting of
Shareholders at 10:30 a.m. (Mountain Time) at the TELUS Spark Centre
in Calgary, Alberta. To listen live to a webcast of the annual
meeting, follow the links on  
Audio webcasts of the conference call and the meeting will be
available for approximately 90 days at under
Investor Relations. 
Husky Energy is one of Canada's largest integrated energy companies.
It is headquartered in Calgary, Alberta, Canada and is publicly
traded on the Toronto Stock Exchange under the symbol HSE and
HSE.PR.A. More information is available at 
Certain statements in this press release are forward-looking
statements and information (collectively "forward-looking
statements"), within the meaning of applicable Canadian securities
legislation, Section 21E of the United States Securities Exchange Act
of 1934, as amended, and Section 27A of the United States Securities
Act of 1933, as amended. The forward-looking statements contained in
this news release are forward-looking and not historical facts.  
Such forward-looking statements are based on the Company's current
expectations, estimates, projections and assumptions that were made
by the Company in light of its experience and its perception of
historical trends. Further, such forward-looking statements are
subject to risks, uncertainties and other factors, some of which are
beyond the Company's control and difficult to predict. Accordingly,
these factors could cause actual results or outcomes to differ
materially from those expressed or projected in the forward-looking
Some of the forward-looking statements and information may be
identified by statements that express, or involve discussions as to,
expectations, beliefs, plans, objectives, assumptions or future
events or performance (often, but not always, through the use of
words or phrases such as "will likely result", "are expected to",
"will continue", "is anticipated", "is targeting", "estimated",
"intend", "plan", "projection", "could", "aim", "vision", "goals",
"objective", "target", "schedules" and "outlook"). In particular,
forward-looking statements in this news release include, but are not
limited to, references to:  

--  with respect to the Company's Asia Pacific region: installation schedule
    of the topsides of the platform at the Company's Liwan Gas Project;
    planned timing of first production from the Company's Liwan Gas Project;
    and anticipated timing of first gas from the Company's Madura Strait
--  with respect to the Company's Atlantic Region: planned timing of first
    production at the South White Rose extension project; and the planned
    in-service date of a water injection well at the Company's North
    Amethyst field; 
--  with respect to the Company's Oil Sands properties: anticipated timing
    of first production at Phase I of the Company's Sunrise Energy Project;
    projected daily production volumes from the next phase of the Company's
    Sunrise Energy Project and the bitumen carbonate pilot at the Company's
    Saleski project; and anticipated timing of completion of well pads and
    pipelines at the Company's Sunrise Energy Project; 
--  with respect to the Company's Heavy Oil properties: scheduled timing of
    first production from the Company's Sandall heavy oil thermal
    development project; anticipated timing of first production at the
    Company's Rush Lake pilot and commercial projects; and the Company's
    2013 drilling program for both horizontal wells and CHOPS wells; and 
--  with respect to the Company's Western Canadian oil and gas resource
    plays: planned timing of proposed 2013/2014 program and resumption of
    road construction at the Company's Slater River Canol Shale project. 

Although the Company believes that the expectations reflected by the
forward-looking statements presented in this news release are
reasonable, the Company's forward-looking statements have been based
on assumptions and factors concerning future events that may prove to
be inaccurate. Those assumptions and factors are based on information
currently available to the Company about itself and the businesses in
which it operates. Information used in developing forward-looking
statements has been acquired from various sources including
third-party consultants, suppliers, regulators and other sources. 
Because actual results or outcomes could differ materially from those
expressed in any forward-looking statements, investors should not
place undue reliance on any such forward-looking statements. By their
nature, forward-looking statements involve numerous assumptions,
inherent risks and uncertainties, both general and specific, which
contribute to the possibility that the predicted outcomes will not
occur. Some of these risks, uncertainties and other factors are
similar to those faced by other oil and gas companies and some are
unique to Husky. 
The Company's Annual Information Form for the year ended December 31,
2012 and other documents filed with securities regulatory authorities
(accessible through the SEDAR website and the EDGAR
website describe the risks, material assumptions and
other factors that could influence actual results and are
incorporated herein by reference.  
Any forward-looking statement speaks only as of the date on which
such statement is made, and, except as required by applicable
securities laws, the Company undertakes no obligation to update any
forward-looking statement to reflect events or circumstances after
the date on which such statement is made or to reflect the occurrence
of unanticipated events. New factors emerge from time to time, and it
is not possible for management to predict all of such factors and to
assess in advance the impact of each such factor on the Company's
business or the extent to which any factor, or combination of
factors, may cause actual results to differ materially from those
contained in any forward-looking statement. The impact of any one
factor on a particular forward-looking statement is not determinable
with certainty as such factors are dependent upon other factors, and
the Company's course of action would depend upon its assessment of
the future considering all information then available. 
Disclosure of Oil and Gas Information 
The Company uses the terms barrels of oil equivalent ("boe"), which
is calculated on an energy equivalence basis whereby one barrel of
crude oil is equivalent to six thousand cubic feet of natural gas.
Readers are cautioned that the term boe may be misleading,
particularly if used in isolation. This measure is primarily
applicable at the burner tip and does not represent value equivalence
at the wellhead. 
The Upstream netback per barrel of oil equivalent was determined by
taking the Upstream Exploration and Production netback (price
received less royalties, operating cost and transportation) and
dividing it by gross production for the respective period. The
results from Upstream Infrastructure and Marketing are excluded.
Please refer to Note 1 of the Company's Condensed Interim
Consolidated Financial Statements for the period ended March 31,
Unless otherwise specified, resources estimates represent Husky's
share and are given with an effective date of Dec. 31, 2012. 
The Company has disclosed best-estimate contingent resources in this
document. Contingent resources are those quantities of petroleum
estimated, as of a given date, to be potentially recoverable from
known accumulations using established technology or technology under
development, but which are not currently considered to be
commercially recoverable due to one or more contingencies.
Contingencies may include factors such as economic, legal,
environmental, political and regulatory matters, or a lack of
markets. There is no certainty that it will be commercially viable to
produce any portion of the contingent resources. 
The Company has disclosed best-estimate contingent resources of 11.4
billion barrels of bitumen for our emerging oil sands portfolio. Of
the total, 10.1 billion barrels is economic at year-end 2012.
Contingent resources are reported as the working interest volumes and
Husky's working interest is 100 percent in all properties except
Athabasca South, which is 50 percent working interest. The properties
are located in the Athabasca, Peace River and Cold Lake region of
Best estimate as it relates to resources is considered to be the best
estimate of the quantity that will actually be recovered. It is
equally likely that the actual remaining quantities recovered will be
greater or less than the best estimate. Estimates of contingent
resources have not been adjusted for risk based on the chance of
development. There is no certainty as to the timing of such
development. For movement of resources to reserves categories, all
projects must have an economic depletion plan and may require, among
other things: (i) additional delineation drilling and/or new
technology for unrisked contingent resources; (ii) regulatory
approvals; and (iii) Company approvals to proceed with development. 
Specific contingencies preventing the classification of contingent
resources at the Company's emerging oil sands properties as reserves
include further reservoir studies, delineation drilling, facility
design, preparation of firm development plans, regulatory
applications and Company approvals. Development is also contingent
upon successful application of SAGD and/or Cyclic Steam Stimulation
(CSS) technology in carbonate reservoirs at Saleski, which is
currently under active development. Positive and negative factors
relevant to the estimate of oil sands resources include a higher
level of uncertainty in the estimates as a result of lower core-hole
drilling density. 
Note to U.S. Readers  
The Company reports its reserves and resources information in
accordance with Canadian practices and specifically in accordance
with National Instrument 51-101, "Standards of Disclosure for Oil and
Gas Disclosure," adopted by the Canadian securities regulators.
Because the Company is permitted to prepare its reserves and
resources information in accordance with Canadian disclosure
requirements, it uses certain terms in this presentation, such as
"contingent resources," that U.S. oil and gas companies generally do
not include or may be prohibited from including in their filings with
the Securities and Exchange Commission.
Husky Energy Inc. - Investor Inquiries:
Rob McInnis
Manager, Investor Relations
Husky Energy Inc. - Media Inquiries:
Mel Duvall
Manager, Media & Issues
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