Carbonate reservoir are associated with various porosity types e.g., moldic, vuggy, fenestral, intergranular, intercryatalline, skeletal, stylolitic, fracture etc. Flow characters associated with different porosity types vary extensively. Therefore, characterization of carbonate reservoir warrants identification and quantification of distribution of different porosity types in the carbonate body. In this paper a robust algorithm has been developed by integrating Differential Effective Medium Theory and Self Consistence Approximation Theory to predict porosity partition in carbonate reservoir. Application of this algorithm in a carbonate reservoir from Mumbai Offshore Basin yield porosity partition logs that is in tune of the geological understanding and information obtained from core/SEM/petrographic images. This algorithm takes mineral volumes from processed well log and travel time from sonic log as the input, which are readily available for almost all the wells.
Presentation Date: Wednesday, September 27, 2017
Start Time: 1:50 PM
Location: 351D
Presentation Type: ORAL
