In Salah CO2 injection modeling: A preliminary approach to predict short term reservoir behavior

Abstract

International audienceA short term performance assessment methodology under development and validation at the In Salah CO2 storage site is presented. The progressive approach first concludes of the necessity to consider a dual media reservoir system at Krechba to fit with gas reservoir production, CO2 injection and CO2 breakthrough at an old appraisal well (Kb-5). To improve gas migration prediction while also considering the geomechanical behavior of the site, an extended geomodel has been developed. Fluid pressure simulation results representative of the dual media reservoir model and of the simple medium upper layer ones (up to the water table) are used to initiate the geomechanical modeling. Comparison of the preliminary geomechanical simulation results assuming a poro-elastic behavior and InSAR satellite surface displacement data are coherent and in the same order of magnitude (∼20 millimeters at maximum displacement)

Vertically integrated models for coupled two‐phase flow and geomechanics in porous media

“…[], Preisig and Prévost [], and Deflandre et al . [], compared to the critical point of CO 2 at 31°C and 7.4 MPa [ Lide , ]). Second, mutual dissolution of the phases is ignored.…”

Modeling CO2plume migration based on calibration of injection and post-injection pressure response at the AEP Mountaineer Project

“…Also worth noting here is the fact that previous work on model calibration has utilized both manual and automated calibration approaches. In manual calibration, parameters affecting the performance metrics of interest are adjusted by the modeler until a satisfactory ‘match’ is obtained.…”

“…Delfandre et al used a dual media model to history match pressure evolution and observed CO 2 breakthrough at an old appraisal well located close to one of the CO 2 injection wells in the Krebcha field of the In Salah Gas Project in Algeria. They used a fracture network characterized by long fractures and faults spaced 1000–2000 m apart in order to match pressure response and breakthrough times.…”

Geological Model of a Storage Complex for a CO2 Storage Operation in a Naturally-Fractured Carbonate Formation

“…This paper presents the main features of the geological model of the storage complex with its stratigraphic and petrophysical properties. The characterization workflow applied to fractured sandstone formations at In-Salah [8] is transposed to naturally fractured carbonate. These reservoirs are particularly challenging to handle because of their high level of heterogeneity that conditions the reservoir behaviour during the injection.…”