Abstract
CO 2 emissions are a global issue that many countries face.In handling this issue, one of them is by utilizing energy resources to cover CO 2 emissions.However, among the many methods used to absorb CO 2 , one of the most effective is a process by injecting CO 2 into the earth layer that also known as carbon sequestration, which is one of the most effective ways to reduce CO2 emissions.CO 2 injection into gas reservoirs not only benefits CO 2 gas storage but can also increase gas production in carboniferous sandstone reservoirs, a process known as Enhanced Gas Recovery (EGR).Operating the CO 2 EGR variable, namely the mass flow rate of CO 2 injection, CO 2 injection temperature, and CO 2 injection pressure, can condition the optimal recovery value.The Beggs-Brill method is used for modeling the CO 2 EGR injection pressure drop in production and injection wells, while the Darcy equation is used in the reservoir.Heat transfer equations are used to model temperature gradients in production wells, injection wells, and reservoirs.When the injection well and production well model is compared to the PIPESIM software simulation, the pressure and temperature gradient for injection wll model have average errors of 0.364% and 0.754%, respectively.The validation results in production wells have a mean error of 0.871% for the pressure gradient model and 0.334% for the temperature gradient model.Meanwhile, when the reservoir compared to the COMSOL Multiphysics software simulation, the mean error for pressure and temperature gradient models is 0.0897% and 0.0106%, respectively.According to the modeling, the amount of CO 2 stored in the reservoir is 21.134 tons per day and can be absorbed by 80.36%.GA produced the best optimization results on the three variables, increasing profits from 5998.