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A series of SP coreflooding experiments were performed in carbonate cores under reservoir conditions.
Rock-proppant interaction tests were also performed to mimic the proppants' behavior in a rock fracture under reservoir stresses.
The theoretical prediction model of generated CO2 volume under reservoir conditions was deduced from the reaction kinetics.
For this purpose, a setup was designed to visually observe the contact between injected CO2 and heavy oil under reservoir conditions.
The cell can maintain its integrity and causes negligible deformations up to 100 MPa, providing sufficient precision for measuring rock properties and simulating hydraulic fracturing under reservoir conditions.
Pendant and sessile drop tests show that a surfonic copolymer decreases the interfacial tension γfl and increases the contact angle θ under reservoir conditions.
The assembled sample cell allows us to obtain high-resolution images of rock samples during CO2 drainage and brine imbibition under reservoir conditions.
The effect of surfactant presence on the CO2/water and oil/water interfaces under reservoir conditions is measured by using a high pressure, high temperature tensiometer.
Current laboratory based techniques require the use of rock fluid systems that are representative of in situ reservoir wettability and preferably under reservoir conditions of pressure and temperature.
Many attempts at enhancing foam stability under reservoir conditions involve the application of chemical additives which can produce synergistic effect in combination with surfactant.
To identify the actual mechanisms that affect the physical properties of heavy oil during various CO2 injection strategies, the behavior of CO2 and heavy oil was visually investigated under reservoir conditions.
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