Page 20 - AIF - English

NARRATIVE DESCRIPTION OF SUNCOR’S BUSINESSES

Current development plans for Terra Nova include a regarding reservoir capability are resolved. Production from

production well and a water injection well that the the HSEU is not expected to reach higher rates until 2015
company anticipates will add production and mitigate when several planned water injection wells are completed.

natural declines from the reservoir. In addition, in 2014, the
company plans to perform maintenance on several White Rose and the White Rose Extensions

production wells and to reinstate a second flowline to a White Rose is approximately 350 km southeast of
subsea drill centre.
St. John’s. Operated by Husky Oil Operations Limited,

Field production is transported by shuttle tanker from the White Rose uses a FPSO vessel and has gross production
capacity of 140 mbbls/d (net 39 mbbls/d to Suncor) and oil
FPSO and either delivered directly to customers (if tanker
schedules permit) or to the Newfoundland transshipment storage capacity of 940 mbbls. Actual annual production
levels are lower than production capacity, reflecting current
terminal in Placentia Bay, where it is subsequently loaded
onto tankers for transport to markets in Eastern Canada or reservoir capability, including natural declines, gas and
water injection and production limits, and asset and facility
the U.S. Suncor has a 14% ownership interest in the
transshipment facility and is part of a group of companies reliability. Production from White Rose began in
November 2005. At December 31, 2013, there were
that share the operation of marine transportation assets for
East Coast Canada.
33 wells in operation: 15 oil production wells, 15 water
injection wells and three gas storage wells. In 2013,

Hibernia and the Hibernia Southern
Suncor’s share of White Rose production averaged
15 mbbls/d (2012 – 12 mbbls/d). White Rose uses the same
Extension Unit (HSEU)
transshipment terminal and the same system of shuttle
The Hibernia oilfield, encompassing the Hibernia and Ben
Nevis Avalon reservoirs, is approximately 315 km southeast tankers that are used for Hibernia and Terra Nova.

of St. John’s and was the first field to be developed in the In 2007, the White Rose co-venturers signed an agreement
Jeanne d’Arc Basin. Operated by Hibernia Management with the Province of Newfoundland and Labrador for the

and Development Company Ltd., an ExxonMobil-managed development of the White Rose Extensions, which include
company, the production system is a fixed GBS that sits on the South White Rose Extension, North Amethyst and West

the ocean floor, and has gross production capacity of
White Rose satellite fields. In May 2010, first oil was
230 mbbls/d (net 46 mbbls/d to Suncor) and oil storage achieved in North Amethyst, and development drilling is

capacity of 1,300 mbbls. Actual production levels are ongoing. Development of the West White Rose field has
lower, reflecting current reservoir capability, including been divided into two stages. The first stage was approved

natural declines, gas and water injection and production in 2010 and first oil was achieved in 2011.
limits, and asset and facility reliability. Hibernia commenced
In October 2013, the co-owners reached an agreement
production in November 1997. At December 31, 2013, with the Government of Newfoundland and Labrador
there were 62 wells in operation: 37 oil production wells,
which resulted in amendments to the terms of the 2007
14 single-zone water injection wells, six dual-zone water White Rose Expansion Project Framework Agreement,
injection wells and five gas injection wells. In 2013,
enabling the second stage development of West White
Suncor’s share of Hibernia production averaged 27 mbbls/d Rose using a Wellhead Platform. Detailed engineering
(2012 – 26 mbbls/d). Hibernia uses the same transshipment
design for this project is currently underway and sanction is
terminal and similar system of shuttle tankers that are used planned for the second half of 2014. Development of the
for Terra Nova.
South White Rose Extension began in 2013 with the
In 2010, final agreements were signed between the installation of subsea gas injection infrastructure. Oil

Hibernia co-venturers and the Government of production and water injection infrastructure will be
Newfoundland and Labrador that established the fiscal, installed in 2014, and first oil for the South White Rose

equity and operational principles for the development of Extension is expected in late 2014 or early 2015.
the HSEU. During 2011, the first two development wells

were completed from the GBS platform and are producing Hebron
oil. The third production well has been drilled and will Discovered in 1980, the Hebron oilfield is located 340 km

commence oil production in the first quarter of 2014. southeast of St. John’s. The project is operated by
Current development plans include drilling up to two ExxonMobil Canada Properties. On December 31, 2012,

additional production wells from the GBS platform and six the Hebron co-owners announced project sanction.
water injection wells in a subsea, excavated drill centre. Development of the Hebron project includes the

Subsea infrastructure was installed in late 2013 and drilling construction of a concrete GBS that supports an integrated
of the first subsea water injection well began in early 2014. topsides deck to be used for production, drilling and

The number of production and injection wells required may accommodations. Development plans include 1,200 mbbls
be revised as the development proceeds and uncertainties
of oil storage capacity and 52 well slots with a gross oil

18 SUNCOR ENERGY INC. ANNUAL INFORMATION FORM 2014