Natural gas is a significant fuel source in the contemporary world, exhibiting both the high energy content associated with petroleum fuels and a potentially lower environmental impact attributable to reduced emissions. Pressure reduction during production leads to the coexistence of liquid and gas near the wellbore due to reaching the dew point causing liquid blockage around the wellbore region and significantly decreasing the gas and condensate extraction volume from a condensate reservoir. Knowing the amount of the trapped phase and mechanisms of trapping is crucial in the proper designing of recovery projects. Different trapping models that represent the relationship between initial and residual saturations were evaluated and proposed a suitable model for different types of rock and fluid. The accuracy of each model was evaluated by different experimental data, and the model parameters were fitted by curve fitting. Results showed that the Spiteri et al. and Ma and Youngren models could predict residual saturations better than other trapping models. The maximum R2’s of the Spiteri et al. and Ma and Youngren models were 1 and 0.99 for oil/brine systems, and 0.95 and 0.97 for gas-brine fluid pairs, respectively, regardless of the type of porous media. Moreover, new experimental trapping data were obtained for the gas-liquid system, and the effects of various parameters on the residual trapped phase saturation were studied. These two models accurately fitted the Initial-Residual (IR) experimental data of the gas-oil system that were obtained in this study. The effect of various parameters such as initial oil saturation, porosity, interfacial tension, flow rates, capillary numbers, and porous medium types on trapping in an unconsolidated sand pack was experimentally studied. The results imply that in the water-wet sand pack, the residual saturation increased by increasing the initial saturation and interfacial tension. However, increasing the porosity, mobility of th