Review on Developments in the Jeanne d’Arc Basin · 2018-03-27 · Review of Developments in the...
Transcript of Review on Developments in the Jeanne d’Arc Basin · 2018-03-27 · Review of Developments in the...
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Review of Developments in the Jeanne d’Arc Basin
Jeff O’Keefe P. Eng., P. Geo Director of Resource Management
Chief Conservation Officer [email protected]
www.cnlopb.ca
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Safety Moment
Protection of the environment… and Safety from the environment
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• Overview of Jeanne d’Arc Basin • Current Development Projects - From start to now - Use of technology to increase reserves - Short term and long-term focus
• Upcoming Call for Bids in 2016
Outline
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Jeanne d’Arc Basin Significant Discoveries
Hibernia
Terra
Nova
White Rose/
North Amethyst
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Hibernia Field
Photo Credit: HMDC
Original Sanction 552 million bbls (1991 Development Plan) 83 wells 20 years life First Oil: November 1997 Current (all GBS drilling slots are utilized) 39 Oil Producers 13 Water Injectors 7 Dual Water Injectors 5 Gas Injectors 64 GBS Wells 4 Subsea Water Injectors (HSE) 68 Total Total Development wells drilled 88
Oil Reserves (C-NLOPB): Proven & Probable 1644 MMbbls Cumulative Production Data (as of April 30, 2016) 967 MMbbls Remaining Reserves 677 MMbbls
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Hibernia Field - Extended Reach Drilling
Use of Extended Reach Drilling (ERD) with the drilling of two key wells B-16 36 (OPA1) and B16 56 (OPA2) in the A Block
Photo Credit: SPE/IADC 140318 (2011)
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Hibernia Field – Short-term and Long-term Focus
• Maximize recovery from existing 64 GBS slots
• Start up of gas lift 2016
• Start of Enhanced Oil Recovery
- Water Alternating Gas (WAG) planned for 2017
• Focus on Ben Nevis Avalon (BNA) Reservoir
• Exploitation of Catalina Formation • Possible gas commercialization (2020 beyond )
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Terra Nova Field Original Sanction 405 million bbls (1997 Development Plan) 26 wells 20 years life
First Oil:
January 2002
Currently
17 Oil Producers
10 Water Injectors
3 Gas Injectors
30 Wells
Photo Credit: Suncor Energy
Oil Reserves (C-NLOPB) 2015:
Proven & Probable 506 Million bbls
Cumulative Production
(as of April 30, 2016) 383 million bbls
Remaining Reserves 123 million bbls
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Terra Nova Field – Use of Light Intervention Vessel (LIV)
• Lower operating limits than rigs
• Minimized production impact on adjacent well
• Quick deployment on and off each well
Photo Credit: Helix Well Ops: Skandi Constructor
• Services: - Bore hole surveys/logging - Gas lift valve repair - Perforating/ Re-perforating - Setting/pulling plugs - Zonal isolation
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Terra Nova Field - Short Term and Long Term Potential Focus • Focus on Well Interventions and Infill Opportunities
• Enhance Oil Recovery
- WAG program possible for late 2017
• Possible Exploitation of Far East Area
• Analysis of Potential of Hibernia Formation
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White Rose Field Original Sanction 233 MM bbls (2001 Development Plan) 21 wells 15 year production life
First Oil: November 2005
Current
12 Oil Producers
11 Water Injectors
4 Gas Injectors
27 Wells
Photo Credit: Husky Energy
Reserves: Proven & Probable 404 MMbbls
Production to date
( as of April 30, 2016) 216 MMbbls
Remaining reserves 188 MMbbls
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• Provide dry tree drilling and completions
• Use of existing SeaRose FPSO for processing and storage
• Conductor sharing wellhead technology
• Electronic Submersible Pumps (ESPs) as an artificial lift mechanism
White Rose Field –DPA Wellhead Platform
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White Rose/North Amethyst Field – Short Term and Long Term Potential Focus
• Current Focus on White Rose Southern Extension/North Amethyst
Hibernia well and then West White Rose pool
• Infill opportunities in South Avalon pool
• Possible WAG project for South Avalon pool
• Exploitation of Hibernia Formation
• Possible gas commercialization 12
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Hebron Field
Photo Credit: ExxonMobil
Original Sanction May 2012 First Oil: Expected Q4, 2017 26 Extended Reach Producers 12 Water Injectors 1 Gas Injector 13 Undesignated for Future Resource
Development 52 Well Slots Reserves: Proven & Probable – 707 Million bbls
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Hebron - New/Upgraded Technology
• Internal Shunt Alternate Path (ISAPT) technology sand screens improve gravel packing of cased and open hole completion wells. • Vessel Internal Electrostatic Coalescer (VIEC) help reduce the water-in-oil content of the oil stream exiting the separator.
Photo Credit: ExxonMobil
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Call for Bids Closes November 9, 2016 3 Parcels Total hectares 354,552
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Summary • Over the last twenty years production has exceeded initial expectations
• New technologies have played an important role in maximizing recovery from each
of the fields
• Each of the development projects has potential upside opportunities within their projects
• Call for bids in the Jeanne d’Arc Basin is scheduled for November 2016
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