Mineralogy, Porosity and Water Saturation From Simultaneous Impedance Inversion in a Turbiditic Oil Reservoir
We find that in a siliciclastic oil system, the seismic-scale P- and S-wave impedances and bulk density obtained from simultaneous impedance inversion uniquely depend each on a different linear combination of the total porosity, clay content, and water saturation. This implies that if the pore fluids are known, we can resolve these seismically derived properties for porosity, clay content, and water saturation. Key to such interpretation is rock physics diagnostics that provides a theoretical rock physics model to quantitatively explain well data by relating P- and S-wave impedances to porosity, clay content, and pore fluid. The well data conditioned according to this model serve as input to simultaneous impedance inversion. We give an example of such rock-physics-based interpretation of seismically derived impedances for rock properties based on well and seismic data from an offshore turbiditic oil field.
AAPG Datapages/Search and Discovery Article #90291 ©2017 AAPG Annual Convention and Exhibition, Houston, Texas, April 2-5, 2017