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Book Chapter

Geological Controls on Matrix Permeability of the Eagle Ford Shale (Cretaceous), South Texas, U.S.A.

By
Tobi H. Kosanke
Tobi H. Kosanke
Marathon Oil Company, 5555 San Felipe St., Houston, Texas 77056, U.S.A. (e-mail: info@crazykfarm.com)
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Anne Warren
Anne Warren
Marathon Oil Company, 5555 San Felipe St., Houston, Texas 77056, U.S.A. (e-mail: info@crazykfarm.com)
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Published:
January 01, 2016

Abstract

Permeability measurements made using innovative techniques on 36 intact samples from five wells in south Texas provide the basis for a dual-porosity reservoir simulation model for the Eagle Ford Shale (Upper Cretaceous). In the model, matrix storage feeds a network of progressively larger natural and induced fractures that carry hydrocarbons to the wellbore. The Eagle Ford consists almost entirely of interbedded marl and limestone. Across these rock types, permeability increases with increasing calcite content. The limestones are more permeable than the marls due to the presence of fractures. Permeability also increases with the degree of lamination but the mechanism is unclear. Finely laminated marls are more permeable than marls without any lamination. Scanning electron microscope microscopy shows that all of the intergranular pores in the Eagle Ford are lined or filled with solid hydrocarbon identified as both bitumen and pyrobitumen by visual kerogen analysis and solvent extraction. The bitumen is porous, but permeability is not related directly to the total organic carbon content.

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Contents

AAPG Memoir

The Eagle Ford Shale: A Renaissance in U.S. Oil Production

John Breyer
John Breyer
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American Association of Petroleum Geologists
Volume
110
ISBN electronic:
9781629812748
Publication date:
January 01, 2016

References

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