Health, safety and risk within the Kuwait Oil Company context

P of CO2 and hydrocarbon (HC) gas injection into a heavy crude oil was investigated at high pressure/temperature condition, using high permeable well-sorted original reservoir sandstone. Complete series of PVT and slime tube tests were followed by vertical and horizontal gas floods to study the impact of injection rate, injectant type and reservoir pressure. Dimensional analysis was performed to study the involved mechanism and forces. Sometimes direct injection of CO2 may not be practically and economically possible. In addition, in plans for CO2 storage, CO2 as a free phase in a reservoir is coupled with a significant leakage risk that prevents the scenario of direct injection. Therefore, in the second part, the enhancement of heavy oil recovery was tested by the carbonated water injection. The results of the first part of core flooding experiments demonstrated that gravity and solubility are the most effective mechanisms in oil recovery. The reduction in oil recovery in horizontal flooding for HC gas injection is higher due to the smaller difference between the densities of CO2 and oil compared to HC gas/oil systems. Furthermore, a small increase of oil recovery after breakthrough (BT) during N2 injection proves the importance of the solubility mechanism. Therefore, In this case, more precise analysis could be performed by applying the dissolution number instead of capillary and/or bond number. For the second part of the experiments, the results obtained demonstrate that the capability of carbonated water to enhance oil recovery for both secondary and tertiary flooding is significantly greater than that for water flooding. The creation of a low resistance flow channel and low oil recovery in water flooding is compensated by CO2 diffusion and subsequent viscosity reduction and oil swelling in heavy oils.