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Published by은정 어금 Modified over 5 years ago
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Heavy oil recovery by modifying the apparent viscosity of the oil with small amount of the surfactant – No steam or solvent is required
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Heavy Oil in Brine – Control
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Heavy Oil Recovery – 0.1% Surfactant @ Ambient Temperature
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Heavy Oil Core Flood Data
20 40 60 80 100 0.5 1 1.5 2 2.5 PV 6 6.2 6.4 6.6 6.8 7 7.2 7.4 Pressure Pressure, MPa % Oil Oil
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Core Flood Oil Droplet Size Distribution
Volume, % Droplet Size, um
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Presentation Outline B. Cutting Costs Through Chemical Flooding
A. Improving Reservoir Yield Exploring the evolution of chemical EOR Success stories of ASP recovery B. Cutting Costs Through Chemical Flooding New developments of chemical EOR Enhanced secondary recovery Low Concentration SP “Cold” Heavy oil recovery Oil Sand Shale – oil/gas recovery Economics and success of chemical flooding
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30 minutes at ambient temperature
Oil Sand Separation Add the oil sand to 0.1% Surfactant solution Shake the flask 30 minutes at ambient temperature
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Oil Sand Separation Low concentration surfactant required
Can be used at ambient or higher temperature No steam is needed No solvent is needed Can be used as cold reservoir in-situ oil / sand separation or surface oil / sand separation
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Presentation Outline B. Cutting Costs Through Chemical Flooding
A. Improving Reservoir Yield Exploring the evolution of chemical EOR Success stories of ASP recovery B. Cutting Costs Through Chemical Flooding New developments of chemical EOR Enhanced secondary recovery Low Concentration SP “Cold” Heavy oil recovery Oil Sand Shale – oil/gas recovery Economics and success of chemical flooding
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Wettability Alteration
IFT > 1 mN/m 0.1% SS-870 IFT = 10-3 mN/m IFT = 10-1 mN/m
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Micro-Fractures Generation
Different fracturing techniques can be used to encourage the surfactant solution leak off, increase the capillary force, reduce the IFT and alter the wettability
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