We use physical simulation experiment and nuclear magnetic resonance methods to investigate crude oil distribution after immiscible CO2 flooding schemes in tight sandstone cores. Experimental results indicate that water-wet cores lead to the highest final recovery factor in comparison with intermediate wet cores and weak oil-wet cores, and the recovery oil difference in clay micropore is mainly because of the heterogeneity, and the difference in medium pore and large pore is affected by asphaltene precipitation phenomenon. Therefore, it is important to enhance the recovery in the clay micropores and reduce the impact of cores permeability reduction caused by asphaltene precipitation. Based on this investigation on the residual oil saturation in pore throats, immiscible CO2 flooding can be a potential method to improve recovery efficiency in tight oil reservoir.