Reservoir Temperature and Pressure Impacts on Oil Recovery Factor of Enhanced Oil Recovery during Methane-rich, Propane-rich, and Carbon Dioxide Gas Injections

This study investigated the impact of reservoir temperature and pressure on Enhanced Oil Recovery (EOR) using methane-rich gas, propane-rich gas, and CO₂ gas injections. A comprehensive experimental design was employed, involving 27 core samples used in a core flooding apparatus, and with varying temperatures (100^OF, 150^OF, and 200^OF) and pressures (1500 psi, 2500 psi, and 3500 psi). the results showed that CO₂ injection yielded the highest oil recovery factors, ranging from 18% to 35%, followed by Propane-rich gas injection (12% to 28%) and methane-rich gas injection (10% to 25%). Lower temperatures and higher pressures were found to improve oil recovery factors for all gas injection methods. The optimum conditions for CO₂ injection were 100^oF and 3500 psi, resulting in a recovery factor of 35%. The verdicts of this experiment offer substantial understandings into the optimum conditions for maximizing oil recovery using natural gas injection and highlight significance of considering reservoir temperature and pressure in EOR operations.

Keywords: CO2 gas, Enhanced Oil Recovery, Methane-rich gas, Propane-rich gas, Recovery factor