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Chapter from:
AAPG Memoir 71 : Reservoir Characterization-Recent Advances
Edited by Richard A. Schatzinger and John F. Jordan
Copyright 
1999 by The American Association of
Petroleum Geologists. All rights reserved.
Memoir 71, Chapter 14: Extracting Maximum Petrophysical and Geological Information From a
Limited Reservoir Database , by Maqsood Ali, Adwait Chawathe, Ahmed Ouenes, Martha
Cather, and William Weiss , Pages 191 - 208
Chapter 14
Extracting Maximum Petrophysical and Geological
Information From a Limited Reservoir Database
 Maqsood Ali
Schlumberger-GeoQuest
Denver, Colorado, U.S.A.
Adwait Chawathe
Chevron Research Tech Company
La Habra, California, U.S.A.
Ahmed Ouenes
Reservoir Characterization Research and Consulting
Denver, Colorado, U.S.A.
Martha Cather
William Weiss
New Mexico Petroleum Recovery Research Center
Socorro, New Mexico, U.S.A.
ABSTRACT
The characterization of old fields lacking sufficient core and log data is a
challenging task. This paper describes a methodology that uses both new and conventional
tools to build a reliable reservoir model for the Sulimar Queen field. At the fine scale,
permeability measured on a fine grid with a minipermeameter was used in conjunction with
the petrographic data collected on multiple thin sections. The use of regression analysis
and a newly developed fuzzy logic algorithm led to the identification of key petrographic
elements that control permeability. At the log scale, old gamma ray logs were first
rescaled/calibrated throughout the entire field for consistency and reliability using only
four modern logs. Using data from one cored well and the rescaled gamma ray logs,
correlations among core porosity, permeability, total water content, and gamma ray were
developed to complete the small-scale characterization. At the reservoir scale, outcrop
data and the rescaled gamma logs were used to define the reservoir structure over an area
of 10 mi2 (26 km2) where only 36 wells were available. Given the
structure, the rescaled gamma ray logs were used to build the reservoir volume by
identifying the flow units and their continuity. Finally, history-matching results
constrained to the primary production
