Carbon dioxide (CO 2 ) injection in shale and coal seam gas reservoirs has become one of the most popular ways to promote methane (CH 4 ) production. However, geological factors affecting the CO 2 enhanced gas recovery (CO 2 -EGR) projects have not been studied in great depth, including underground moisture, subsurface water salinity, and other gases accompanying CH 4 . Thus, a hybrid methodology of molecular dynamics (MD) and grand canonical Monte Carlo (GCMC) simulation is employed to reveal the gas adsorption and displacement mechanisms at a fundamental molecular level. This study generates a type II-D kerogen matrix as the adsorbent. The simulation environment includes 0−5 wt % moisture content, 0−6 mol/L NaCl saline, and 0− 5 wt % C 2 H 6 for up to 30 MPa at 308, 338, and 368 K. The impressions of moisture, C 2 H 6 , and salinity on gas adsorption and competitive adsorption characteristics are analyzed and discussed. On the basis of the simulation results, the preloaded H 2 O molecules negatively influence CH 4 adsorption, leading to a 44.9% reduction at 5 wt % moisture content. Additionally, 6 mol/L NaCl within 5 wt % moisture content exhibits a further 9.8% reduction on the basis of the moisture effect. C 2 H 6 presents a more noticeable negative impact, of which 5 wt % results in a 73.2% reduction in CH 4 adsorption. Moreover, the competitive process indicator, preferential selectivity S CO 2 /CH 4 , is analyzed and discussed in the presence of the mentioned factors. Moisture positively influences S CO 2 /CH 4 , salinity promotes S CO 2 /CH 4 , and C 2 H 6 develops S CO 2 /CH 4 . These factors would encourage the displacement processes of CH 4 by CO 2 injection. This study provides essential information for better gas resource estimation and gas recovery improvement in unconventional systems.