Integrating Plug to Well-Scale Petrophysics with Detailed Sedimentology to Quantify Fracture, Vug, and Matrix Properties in Carbonate Reservoirs


Kansas Geological Survey
Open-file Report 99-47

Integrating Plug to Well-Scale Petrophysics with Detailed Sedimentology to Quantify Fracture, Vug, and Matrix Properties in Carbonate Reservoirs:
An Example from the Arbuckle Group, Kansas


Alan P. Byrnes, Evan K. Franseen, and D. Mark Steinhauff*
Kansas Geological Survey, 1930 Constant Ave., Lawrence, KS 66047
*Present Address: Exxon Exploration Company, Houston, TX


Purpose

To develop a model for quantifying the relative contribution of matrix, vug, and fracture flow in thin-bedded cyclic carbonate systems

Introduction

Arbuckle reservoirs represent an enormous resource of post-waterflood trapped oil. Before these can be successfully CO2 flooded it is necessary to fully understand the distribution of porosity, permeability, and saturation. Production is often attributed to karst-related vuggy porosity and fracturing but integration of lithofacies with petrophysical properties indicates that only certain lithofacies are reservoir rocks and that some lithofacies do not exhibit reservoir properties even when they have extensive vuggy porosity. Differences between core and DST permeabilities may be explained by differences in flow-model assumptions and data averaging methods.

Implications

Original depositional facies and relatively early diagenetic events had a significant influence on present reservoir characteristics. Later dissolution from karst, fracturing, and/or structural influences are locally important but may not always be the primary control on favorable reservoir properties. Results and methods of this study provide:

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Last updated November 2002
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