Producing Projects

HIBERNIA

Status: In production

First oil:  17 November 1997

Field Location: Grand Banks, 315 km (196 mi) east-southeast of St. John's, NL

Discovery date: 1979

Operator:
Hibernia Management and Development Company Ltd.

Project participants:
- ExxonMobil Canada Properties (33.125%)
- Chevron Canada Resources (28.875%)
- Petro-Canada Hibernia Partnership (20%)
- Canada Hibernia Holding Corp. (8.5%)
- Murphy Atlantic Offshore Oil (6.5%)
- StatoilHydro Canada Ltd. (5%)

Hibernia major contractors:
- Schlumberger
- Noble Drilling (Canada) Ltd.
- PSN
- East Coast Tubulars Ltd.
- Baker Petrolite
- A. Harvey & Company Ltd.
- Maersk Company Canada Ltd./Seabase
- Cougar Helicopters Inc.
- Crosbie Salamis Ltd.

Water depth: 80 m (262 ft)

Discovered recoverable reserves*:
Oil - 1.2 million bbl
Natural gas - 1.7 tcf
Natural gas liquids - 202 million bbl
*Source – CNLOPB

Production life: 20 years (approximate) beyond 2020

Mode of development:
- Gravity Base Structure (GBS) supporting drilling, production and accommodation facilities
- Storage capacity - 1.3 million bbl
- Subsea export line to two offshore loading systems
- Two - 127,000 dwt shuttle tankers
- Onshore transshipment facility
- Hibernia's 2007 production was approximately 140,000 bpd

Production rate: 200,000 bpd capacity


Platform safety features:
The concrete GBS caisson and production platform incorporate a number of significant safety features in their design.  For example, the temporary safe refuge (TSR) area in the M-50 accommodations module provides protected direct access to emergency evacuation systems and provides physical protection for workers against the effects of fire, heat, smoke and gas.

Total project investment:
•    Pre-production capital investment $5.8 billion CDN
•    Expenditures are estimated between $300 - 400 million CDN per year

Canada-NL Benefits:
Employment: Drilling and production phases - up to 800 people onshore and offshore (approximately 90% are Newfoundlanders)

For further information:
Hibernia Management and Development Company Ltd.
100 New Gower St., Suite 1000
St. John's, NL  A1C 6K3
Website:  www.hibernia.ca
Tel: 709-778-7000
Fax: 709-722-0022
Email: hmdc.public.affairs.information@ExxonMobil.com



SABLE OFFSHORE ENERGY PROJECT

Status: In production

First gas: 31 December 1999

Field location: Scotian Shelf, 200 km (124 mi) off eastern coast of NS

Producing fields:
•    Thebaud
•    Venture
•    North Triumph
•    Alma
•    South Venture

Discovery date:
Venture - 1979
Thebaud - 1972

Operator: ExxonMobil Canada

Project participants:
• ExxonMobil Canada (50.8%)
• Shell Canada Energy (31.3%)
• Imperial Oil Resources Limited (9%)
• Pengrowth Corporation (8.4%)        
• Mosbacher Operating Ltd. (0.5%)

Water depth: 20-80 m (65.6 – 262 ft)

Mode of development:
- Central processing platform at Thebaud, with satellite platforms at Venture, North Triumph, Alma and South Venture
- Dedicated accommodation platform at Thebaud
- 200 km (124 mi) of interfield flowlines
- 200 km (124 mi) of gathering lines from Thebaud to the onshore gas plant at Goldboro, NS
- Natural Gas Liquids line from gas plant at Goldboro to fractionation plant at Point Tupper, NS

Normal production rate: more than 400 mcf/day

For further information:
ExxonMobil Canada
Founder's Square
1701 Hollis St., Suite 102
Halifax, NS  B3J 3M8
Tel: 902-490-8900
Fax: 902-496-0958



TERRA NOVA
 
Status: In operation
 
First oil: January 2002
 
Field location: Grand Banks, 350 km (217 mi) east-southeast of St. John's, NL
 
Discovery date: 1984
 
Operator: Petro-Canada
 
Project participants:
• Petro-Canada (33.99%)
• ExxonMobil Canada Properties (22%)
• StatoilHydro Canada Ltd. (15%)
• Husky Oil Operations Ltd. (12.51%)
• Murphy Oil Company Ltd. (12%)
• Mosbacher Operating Ltd. (3.5%)
• Chevron Canada Resources (1%)
 
Water depth: 90-100 m (295 – 328 ft)
 
Discovered recoverable reserves:
Oil - 440 million bbl (operator estimate)
 
Production life:  20 years from first oil
 
Mode of development:
- Steel FPSO (Floating Production Storage and Offloading) vessel
- Design storage capacity - 960,000 bbl
- Subsea wells (producers and injectors) offloading to shuttle tankers
 
Production: 180,000 bpd approved facility capacity
 
Canada – NL Benefits:
Over its life, the Terra Nova development will create significant benefits for Canada generally, and for Newfoundland & Labrador in particular.
 
The successful development of Terra Nova is contributing to the creation of a sustainable offshore oil industry in Newfoundland. Currently, approximately 700 people are employed through Terra Nova, working both onshore in operations support and offshore on the Terra Nova FPSO and supply vessels that provide standby services to the development. More than $700 million was spent in Newfoundland & Labrador in the development of the oil field and over the life of the field Terra Nova will contribute more than $2 billion to the economy.
 
The Terra Nova oil field is designed for the harsh environment of the Grand Banks, which experiences extreme cold, high winds and seas as well as fog, ice and icebergs on a seasonal basis. Petro-Canada, as operator of the Terra Nova project, is proactive in the areas of health and safety of personnel and takes seriously its responsibility to protect the environment in which it operates.
 
For further information:
Petro-Canada
Scotia Centre
235 Water St., Suite 201
St. John's, NL  A1C 1B6
Website: www.petro-canada.ca
Tel: 709-778-3500
Fax: 709-724-2835



WHITE ROSE

Status: In production

First oil:  12 November 2005

Field location: Grand Banks, 350 km (217 mi) east of St John’s, NL

Discovery date: 1984

Operator:  Husky Oil Operations Ltd

Project participants:
- Husky Energy (72.5%)
- Petro-Canada (27.5%)

In December 2007 a Framework Agreement was reached which will provide a 5% equity position in the White Rose satellite expansion for the province’s energy corporation.

Water depth: 125 m (410 ft)

Discovered recoverable resources:
South White Rose: Oil – 200-250 million bbl (operator estimate)

Additional potential resources*:
Natural Gas – 2.7 tcf
Natural Gas Liquids – 96 million bbls
Oil – 80 million bbl
*Source: CNLOPB

Project scope (2009 program):
- The White Rose Oilfield Development Application was approved by the regulators in December 2001 and was sanctioned by the owners in March 2002. Initial development has focused on the South Avalon oil pool which is being developed using an 21-well system tied back to a floating production storage and offloading (FPSO) vessel through a subsea production system. The SeaRose FPSO achieved first oil on November 12, 2005.  Key activities for 2009 will include:
•    Progressing development of the North Amethyst satellite tieback
•    Submission of a development application for the West White Rose satellite tieback
•    Carrying out facilities modifications to the SeaRose FPSO to accommodate production from subsea tiebacks.
•    Maintaining a focus on strong safety and environmental performance

Production rate: 115,000 bpd (avg annual)

Projects Under Development

DEEP PANUKE

Status:  Development

First gas expected: 2010   

Field location: 250 km (155 mi) southeast of Halifax, NS

Operator: EnCana Corporation

Water depth: 45 m (148 ft)

Discovery announced: 2000

Estimated recoverable resources:  ~ 400 bcf – 900 bcf (with a mean ~ 630 bcf sales gas recoverable)

Production life: 8.5 - 17 years (avg ~ 13 years)

Project schedule:
EnCana's Board of Directors sanctioned Deep Panuke for development in October 2007. In November 2007, EnCana announced that it had entered into an agreement with Single Buoy Moorings Inc. (SBM) for the provision and operation of the Deep Panuke production field centre. Regulatory applications for Deep Panuke were filed in 2006, with approvals granted in 2007.
What’s ahead in 2009:
- Shifting project emphasis from engineering to construction activity -PFC
- Pipelay from PFC to landfall
- Complete four production wells and drill one new acid gas injection well
- Flare tower fabrication
- Supply boat construction to begin
- Shorebase up and running

Development planning: No exploration planned for 2009.

Mode of development:
Offshore production and processing.  Subsea pipeline transportation to landfall in Nova Scotia.

Production rate: Design capacity of 300 MMcf/d

For further information:
EnCana Corporation
1701 Hollis St., Suite 700
Halifax, NS  B3J 3M8
Website: www.encana.com
Tel: 902-422-4500
Fax: 902-425-2766
Email: DPinfo@encana.com

Projects in Pre-Development

HEBRON

Status: Pre-development

The Hebron proponents and the Government of Newfoundland and Labrador signed a development agreement on 20 August 2008.

Field location: 350 km (217 mi) offshore NL

Operator: ExxonMobil Oil Canada Properties

Project participants:      
- ExxonMobil Oil Canada Properties (36%)
- Chevron Canada Limited (26.7%)
- Petro-Canada (22.7%)
- StatoilHydro Canada Ltd. (9.7%)
- Nalcor Energy (4.9%)

Water depth: 92 m (302 ft)

Discovery:  1981

Estimated recoverable reserves: 400-700 million bbl (oil - 18° – 25° API)

Production life: 20 – 25 years (est.)

For further information:
ExxonMobil Canada
100 New Gower St., Suite 1000
St. John's, NL  A1B 6K3
Canada
Tel: 709-778-7000
Fax: 709-778-0022
Email: margot.p.bruce-o'connell@exxonmobil.com
Contact: Margot Bruce O'Connell, Public Affairs Manager