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Book Chapter

Sequence-Stratigraphic, Petrophysical, and Multicomponent Seismic Analysis of a Shelf-Margin Reservoir: San Andres Formation (Permian), Vacuum Field, New Mexico, United States

By
Matthew J. Pranter
Matthew J. Pranter
Colorado School of Mines, Golden, Colorado, U.S.A.
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Neil F. Hurley
Neil F. Hurley
Colorado School of Mines, Golden, Colorado, U.S.A.
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Thomas L. Davis
Thomas L. Davis
Colorado School of Mines, Golden, Colorado, U.S.A.
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Published:
January 01, 2004

Abstract

This chapter describes an integrated approach to reservoir characterization and three-dimensional (3-D) geologic modeling of the San Andres Formation at Vacuum field, New Mexico, United States. We present techniques to identify significant heterogeneities within a carbonate reservoir using stratigraphic, petrophysical, and 3-D multicomponent seismic data. This integrated approach provides a detailed static description of reservoir heterogeneity and improved delineation of the reservoir framework in terms of flow units.

We use a petrophysics-based method to identify hydraulic flow units within a sequence-stratigraphic framework. Flow units are characterized within high-frequency carbonate sequences through analysis of the vertical variation of flow (kh) and storage capacity (ϕh) and pore-throat radius (R35) associated with successions of subtidal, intertidal, and supratidal rocks. Pore-throat radii from cored wells are used to modify the empirically derived Winland equation to estimate values of pore-throat radius in non-cored wells. Flow profiles, constructed from log porosities and neural-network permeabilities, are correlated and used to build a 3-D geologic-model framework.

Characterization of both matrix and fracture properties within a reservoir is possible using 3-D multicomponent seismic data and wire-line logs. Compressional- and shear-wave amplitude attributes together provide more accurate porosity estimates than those determined from compressional-wave data alone. Shear-wave anisotropy measurements provide information about inferred fracture density and orientation that can be used to modify permeability models to account for regions with open fractures.

Because of this study, reservoir-simulation models that incorporate modified permeability distributions more accurately account for unexpected early CO2-breakthrough times observed in the field. In addition, flow-simulation results indicate that the need to upscale the geologic model was significantly reduced or eliminated by describing flow units using the combined sequence-stratigraphic- and petrophysics-based method.

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Contents

AAPG Memoir

Seismic Imaging of Carbonate Reservoirs and Systems

Gregor P. Eberli
Gregor P. Eberli
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Jose Luis Masaferro
Jose Luis Masaferro
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J. F. “Rick” Sarg
J. F. “Rick” Sarg
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American Association of Petroleum Geologists
Volume
81
ISBN electronic:
9781629810058
Publication date:
January 01, 2004

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