Model-based prediction of porosity and reservoir quality from P- and S-wave data

Details Model-based prediction of porosity and reservoir quality from P- and S-wave data Model-based prediction of porosity and reservoir quality from P- and S-wave data

Oct 2003

adsabs.harvard.edu/cgi-bin/nph-data_query?bibcode=2003georl..30tsde4s&link_type=abstract

Geophysical Research Letters, Volume 30, Issue 20, pp. SDE 4-1, CiteID 2029, DOI 10.1029/2003GL018450

Statistics

Computation

Exploration Geophysics: Computational Methods, Seismic, Exploration Geophysics: General Or Miscellaneous, Exploration Geophysics: Seismic Methods (3025)

Scientific paper

We present a deterministic methodology for mapping the lithology, pore fluid, and porosity from seismic data. The input is the P- and S-wave data volumes that may come, e.g., from acoustic and elastic inversion or cross-well measurements. The output is the pore fluid type (hydrocarbon versus water), total porosity, and clay content. The key element of this methodology is a site-specific rock physics model that provides the needed transforms from the elastic rock properties to the reservoir properties. This model is established by comparing model-based predictions, such as impedance versus porosity, to the relations present in well log data. Once selected, the model is used to identify the presence of hydrocarbons from a combination of the P-wave impedance and Poisson's ratio. Then the P-wave impedance is used to map porosity and clay content assuming that a deterministic relation exists between the latter two properties. All deterministic equations are calibrated at a well and then are applied to upscaled well log data to confirm their validity at the seismic scale. This methodology is applied to log data from a fluvial environment. The results indicate that the relative error in porosity determination is 14%, which is acceptable for reservoir characterization purposes.

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