Characterization of fluid flow using borehole and core geophysical measurements in carbonate reservoirs remains challenging due to the lack of universally applicable petrophysical relationships. This study quantifies pore structure (i.e., porosity, pore size distribution, and surface area-to-volume ratio), and its influence on the permeability in carbonate reservoir rocks using integrated low-field nuclear magnetic resonance (NMR) and the spectral induced polarization (SIP) method. Three geologically classified groups of carbonate cores have been used to link geophysical responses with lithofacies. The µCT imaging and thin section petrographical analysis were performed to verify texture and pore structure of carbonate rocks. Established relationships between pore structure parameters and T2 distribution,, imaginary part of conductivity (s) are examined on our carbonate samples. Our results suggest that relationships derived from sandstones cannot be directly applied in carbonates. The introduction of priori parameters accounting mineralogy like formation factor () should be considered.
Presentation Date: Tuesday, September 26, 2017
Start Time: 4:20 PM
Presentation Type: ORAL