Abstract: A method for treating a basaltic formation includes providing a CO2-rich fluid in the basaltic formation, generating one or more metal ions from a metal ion source in the basaltic formation with the CO2-rich fluid, providing heat from a thermogenic reaction between a first salt solution and a second salt solution in the basaltic formation, and enhancing a reaction between the one or more metal ions and the CO2-rich fluid with the heat, thereby treating the basaltic formation. A system for treating a basaltic formation including a metal ion source includes a CO2-rich fluid that includes a source of carbon dioxide dissolved in a first aqueous fluid, a first salt solution that includes a first thermogenic agent dissolved in a second aqueous fluid, and a second salt solution that includes a second thermogenic agent dissolved in a third aqueous fluid.

Abstract: Described is a method for enhanced carbon dioxide (CO2) sequestration in geological formations. The method includes dissolving CO2 in a low salinity fluid to form a CO2-brine solution. The low salinity fluid includes sodium (Na+) ions and sulfate (SO42?) ions. The CO2-brine solution is injected into a geological formation, and the CO2 reacts with the geological formation to produce solid carbonate minerals for CO2 sequestration.

Abstract: A method for increasing CO2 sequestration efficiency in depleted reservoirs using a CO2 thickener is provided. The method may include the steps of introducing a thickened CO2 mixture into the depleted reservoir, where the thickened CO2 mixture comprises a mixture of CO2 and a CO2 thickener. The method may include using CO2 is in a liquid or supercritical state upon introduction into the depleted reservoir. The method may also include the step of using a CO2 thickener comprising a methyl acrylate-based copolymer, a CO2 solvent, and a solvent.

Abstract: A method for increasing CO2 sequestration efficiency in depleted reservoirs by increasing injectivity is provided. This method includes the steps of introducing a surfactant solution into an upper portion of the reservoir through an injection well and introducing CO2 to a lower portion through another injection well such that the CO2 and surfactant solution migrate away from the wells and intimately intermingle to form CO2-based foam in situ. The surfactant solution and CO2 may also be introduced through the same injection well, where the surfactant solution is introduced to an upper portion of the reservoir and the CO2 is introduced into a lower portion. The pressure may be maintained at a value less than the fracture pressure of the reservoir utilizing a pressure relief well.

Abstract: A method for increasing CO2 sequestration efficiency in depleted reservoirs by increasing injectivity is provided. This method includes the steps of introducing a surfactant solution into an upper portion of the reservoir through an injection well and introducing CO2 to a lower portion through another injection well such that the CO2 and surfactant solution migrate away from the wells and intimately intermingle to form CO2-based foam in situ. The surfactant solution and CO2 may also be introduced through the same injection well, where the surfactant solution is introduced to an upper portion of the reservoir and the CO2 is introduced into a lower portion. The pressure may be maintained at a value less than the fracture pressure of the reservoir utilizing a pressure relief well.