CO2 Enhanced Gas Recovery and Geologic Sequestration in Condensate Reservoir: A Simulation Study of the Effects of Injection Pressure on Condensate Recovery from Reservoir and CO2 Storage Efficiency

Suitability of depleted gas reservoirs for geological CO2 storage: A simulation study

“…It is a major tool used for compositional modeling of enhanced recovery processes and CO 2 storage. As mentioned earlier, injection after field depletion is the best scenario to sequester CO 2 with a better residual recovery . Hence, simulation was run for a long‐term storage to investigate the compositional impact of different gas types on the storage of depleted gas reservoirs.…”

“…There have been many studies carried out to show the potential of injecting CO 2 into dry gas and condensate gas reservoirs using numerical modeling techniques. According to these studies, the success of a CO 2 storage practice is linked to the injection strategy, reservoir characteristics, and operational parameters.…”

“…They concluded that CO 2 sinks into the bottom of the gas cap and stores permanently when gas recovery by CO 2 displacement and condensate revaporization processes take place. Narinesingh and Alexander showed that the injection pressure increases in high‐condensate recoveries due to the re‐vaporization of the condensate drop‐out. According to Yuan et al ., a fast condensate recovery and CO 2 storage can be achieved by combining the processes of enhanced recovery and storage at the early stage of the field development.…”

“…4,5 For instance, the Gorgon Carbon Dioxide Injection project in Australia has been initiated and is in its construction phase for the deployment of CO 2 in a gas field. 6 There have been many studies carried out to show the potential of injecting CO 2 into dry gas [7][8][9][10][11][12][13][14][15] and condensate gas reservoirs 4,[16][17][18][19] using numerical modeling techniques. According to these studies, the success of a CO 2 storage practice is linked to the injection strategy, reservoir characteristics, and operational parameters.…”

Prevention of Seabed Subsidence of Class-1 Gas Hydrate Deposits via CO2-EGR: A Numerical Study with Coupled Geomechanics-Hydrate Reaction-Multiphase Fluid Flow Model

“…However, the risks of damage to the surrounding formation and gas leakage during production limits the production rate and overall amount of gas produced. In order to avoid hydrate dissociation and the weakening of the overlying formation, the injection of CO 2 into a reservoir to maintain the hydrate layer pressure has been proposed [19,20]. By injecting CO 2 , the reservoir is repressurized and the contained oil and gas will be displaced [21][22][23][24][25].…”