Current and Future Challenges in Heavy Oil Recovery
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Copyright © SRC 2014 Copyright © SRC 2014 1 Current and Future Challenges in Heavy Oil Recovery Presented by: Mike Crabtree Vice-President, Energy Division Saskatchewan Research Council
Transcript of Current and Future Challenges in Heavy Oil Recovery
Copyright © SRC 2014Copyright © SRC 20141
Current and Future Challenges in Heavy Oil Recovery
Presented by: Mike Crabtree
Vice-President, Energy Division
Saskatchewan Research Council
Copyright © SRC 2014Copyright © SRC 20142
Saskatchewan Research Council (SRC)
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What is Heavy Oil? Hydrocarbon compounds characterized by
long, complex molecules which impart high internal friction
resulting in high viscosity.
Flows very slowly – viscosity 1000 to 300,000 mPa-s (cp) in-
situ
Different or modified EOR processes required for recovery
compared to light and medium oils
Field development requires many wells on close spacing
Heavy Oil – Key Properties & Considerations
Copyright CAPP
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Heavy Oil – Current Challenges
Lower production rates and ultimate recoveries than light oils
Often reservoirs are unconsolidated resulting in sanding problems
Produced oil sells at a discount to light crudes
Crude discount can be cyclic due to changing needs for asphalt
Often reservoirs are cold, < 30°C
Often produced with lots of sand - CHOPS
Vast worldwide resource will require many methods of extraction
Industry focus is still on high value crudes – light/tight
Industry still prefers to in-fill drill than field pilot EOR Processes
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In Situ
Thermal
CSS
SAGD
Thermal-Solvent Hybrid
Electrical Heating
Cold
Primary
EOR
CHOPS
Pressure Depletion
Solvents
ASP Waterflooding
Microbial
In Situ Combustion
Vertical wells, Reservoir Economics, Environmental Footprint, Energy Density
Slow Process - Performance?
Field Application? Kinetics?
Wormhole Structure?
Optimized Pressure
Cycle?
Mechanisms? Cyclic or Continuous, Solvent Costs, Retention and Losses, Optimization?
Optimized Waterfloods?
Mechanisms? Field Applications
Process Performance? Solvent Cost/Losses? Accelerated Production
vs Improved Ultimate Recovery
Heavy Oil – Recovery Processes
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Cyclic Steam Stimulation (CSS)
Process Optimization
Limited Application
Economics
Numerical Simulation
Steam Assisted Gravity Drainage (SAGD)
High Capital Costs
High Water and Energy Use
Environmental Costs
Thick Pay Zone Required
In-Situ Combustion (ISC)
Difficult to maintain stable front
Producing hot oil without stalling in cold reservoir
Chemical reaction modeling
Emulsion treatment
Heavy Oil – Current Commercial Technologies
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Hybrid Thermal-Solvent
Enhanced Viscosity Reduction
Reduced Energy Density
Applicable to Shallow Reservoirs
Accelerated Production or Enhanced Ultimate Recovery?
Field Optimization Ongoing
Electrical Heating
Slow Heating Process
Excessive Current Density/Coking?
No Drive Energy Generated
Requires Electrical Grid or Power Generation Capacity
Field Trials Ongoing
Steam & Solvent Injection
Heavy Oil – ‘Near’ Commercial Technologies
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Inject solvent vapor to reduce oil viscosity
Advantages:
Many applications – thin reservoirs, post-CHOPS
High recovery factors - >90% OOIP in lab
Challenges:
Solvent to Oil Ratio - Economics
Solvent Cost - Solvent Storage and Losses
Low Production Rates
Rate Controlling Mechanism?
Optimization?
Heavy Oil Future - Solvent Injection Processes
VAPEX
SVX
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Alkaline, Surfactant, Polymer (ASP)
Alkaline: Uses natural organic acids in heavy oil to produce in-situ surfactants
Surfactant: Reduces interfacial tension for improving displacement efficiency
Polymer: Mobility control for blocking high water or gas saturation channels leading to improved sweep efficiency
Heavy Oil Future - ASP Waterflooding
Advantages:
Applied in the field
Many polymers and surfactants available
Low capital requirements for existing fields
Challenges:
Cost of Chemicals,
High Temp. limitations
High Salinity limitations
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Heavy Oil Future - Low Salinity Waterflooding
Advantages: Has been applied in field with success
Potentially lower cost than ASP
Challenges: Water Treatment (desalination)
Mechanisms Not Fully Understood
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Microbial Enhanced Oil Recovery (MEOR)
At Least Three Mechanisms
Bio-Blocking: Microbe bodies and secretions act as polymers for blocking high water saturation channels
Bio-Surfactants: Microbes produce in-situ or ex-situ surfactants for interfacial tension reduction
Bio-Clipping: Microbes partially consume hydrocarbon chains and/or clip long chains to reduce molecular weight resulting in viscosity reductions
Heavy Oil Future - Microbial Processes
Challenges:
Cannot tolerate temperatures >~60C
May be difficult to deliver nutrients deep into reservoir
Industry concerns over use of bacteria
SRC’s MEOR Large Core System
Advantages:
Naturally occurring microbes present already
Only require nutrients for exponential growth
Can tailor nutrients for desired microbes
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Cold Heavy Oil Production with Sand (CHOPS)
Method that accelerates recovery of oil from unconsolidated sands by co-producing sand, oil and water.
Production of sand produces “wormholes” which cause extremely high permeability in open and dilated channels.
Challenge:
Design of EOR Processes that take advantage of
Wormholes produced during CHOPS
Wormholes:
Injection-Production Shortcuts or Oil Drainage Conduits?
Management of Conductivity – Partial Collapse Desirable?
How?
Modeling for Post-CHOPS EOR Process and Economics
Evaluation
Heavy Oil - Post-CHOPS EOR
SRC’s Wormhole Simulation
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SRC has ‘Unique Service Offerings’ for the Investigation, Development and
Optimization of a wide range of EOR processes for heavy oil and bitumen
reservoirs
As an independent organization, SRC provides reliable, unbiased, confidential
services
Visit our Web Page at www.src.sk.ca
Best of All – Come visit our facilities in Regina
Summary
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Contact:
Muhammad Imran
Business Unit Manager
EOR Field Development, Energy
Saskatchewan Research Council
129 - 6 Research Drive
Regina, Saskatchewan, Canada, S4S 7J7
Phone: 1-306-798-0521; Email: [email protected]
Thank You
