Heavy oil recovery by modifying the apparent viscosity of the oil with small amount of the surfactant – No steam or solvent is required

Heavy Oil in Brine – Control

Heavy Oil Recovery – 0.1% Surfactant @ Ambient Temperature

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

Core Flood Oil Droplet Size Distribution Volume, % Droplet Size, um

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

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

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

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

Wettability Alteration IFT > 1 mN/m 0.1% SS-870 IFT = 10-3 mN/m IFT = 10-1 mN/m

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