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Abstract

AAPG Bulletin, V. 91, No. 4 (April 2007), P. 603-622.

Copyright copy2007. The American Association of Petroleum Geologists. All rights reserved.

DOI:10.1306/11010606061

Natural fractures in the Barnett Shale and their importance for hydraulic fracture treatments

Julia F. W. Gale,1 Robert M. Reed,2 Jon Holder3

1Bureau of Economic Geology, Jackson School of Geosciences, University of Texas at Austin, J. J. Pickle Research Campus, Building 130, 10100 Burnet Road, Austin, Texas 78758-4445; [email protected]
2Bureau of Economic Geology, Jackson School of Geosciences, University of Texas at Austin, J. J. Pickle Research Campus, Building 130, 10100 Burnet Road, Austin, Texas 78758-4445
3Department of Petroleum and Geosystems Engineering, University of Texas at Austin, Austin, Texas

ABSTRACT

Gas production from the Barnett Shale relies on hydraulic fracture stimulation. Natural opening-mode fractures reactivate during stimulation and enhance efficiency by widening the treatment zone. Knowledge of both the present-day maximum horizontal stress, which controls the direction of hydraulic fracture propagation, and the geometry of the natural fracture system, which we discuss here, is therefore necessary for effective hydraulic fracture treatment design.

We characterized natural fractures in four Barnett Shale cores in terms of orientation, size, and sealing properties. We measured a mechanical rock property, the subcritical crack index, which governs fracture pattern development. Natural fractures are common, narrow (lt0.05 mm; lt0.002 in.), sealed with calcite, and present in en echelon arrays. Individual fractures have high length/width aspect ratios (gt1000:1). They are steep (gt75deg), and the dominant trend is west-northwest. Other sets trend north-south. The narrow fractures are sealed and cannot contribute to reservoir storage or enhance permeability, but the population may follow a power-law size distribution where the largest fractures are open. The subcritical crack index for the Barnett Shale is high, indicating fracture clustering, and we suggest that large open fractures exist in clusters spaced several hundred feet apart. These fracture clusters may enhance permeability locally, but they may be problematic for hydraulic fracture treatments. The smaller sealed fractures act as planes of weakness and reactivate during hydraulic fracture treatments. Because the maximum horizontal stress trends northeast-southwest and is nearly normal to the dominant natural fractures, reactivation widens the treatment zone along multiple strands.

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