--> Abstract: Relationship of Tectonic Style to the Occurrence and Distribution of Fracture Porosity, by K. J. Weber and U. O. Freyer; #91012 (1992).
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ABSTRACT: Relationship of Tectonic Style to the Occurrence and Distribution of Previous HitFractureNext Hit Porosity

WEBER, K. J., and U. O. FREYER, Shell Internationale Petroleum Maatschappij B.V., The Hague, Netherlands

Previous HitFractureNext Hit porosity is still the most elusive of reservoir parameters. Modern borehole wall imaging tools and cores can provide Previous HitfractureNext Hit orientation, spacing and rough estimates of Previous HitfractureNext Hit widths. Previous HitFractureNext Hit distribution models in combination with well test Previous HitanalysisNext Hit can lead to semiquantitative estimates of the permeability, porosity, and connectivity of the Previous HitfractureNext Hit system.

Studies of outcrops of fractured formations are mainly of interest to establish the Previous HitfractureNext Hit distribution and to reconstruct the development and relative age of the various Previous HitfractureNext Hit systems. This information can be applied to model the Previous HitfractureNext Hit distribution in analogous field structures in combination with the well data. Some of the most reliable Previous HitfractureNext Hit porosity estimates are derived from long-term production data and careful monitoring of hydrocarbon-water contacts.

Literature on fractured reservoirs contains little reliable data on Previous HitfractureNext Hit porosity. A survey of worldwide literature has provided a limited number of well-documented cases from which realistic ranges of Previous HitfractureNext Hit porosity in various tectonic regimes have been derived. Thrust structures and structures formed by strike-slip faulting dominate the scene. Even in strongly folded reservoirs the Previous HitfractureNext Hit porosity rarely surpasses 0.2% of rock bulk volume unless leaching has enhanced Previous HitfractureNext Hit width.

Previous HitFractureNext Hit porosity is often overestimated by a factor of 10 or more. This is mainly caused by the often spectacular well productivities in fractured reservoirs. Previous HitFractureNext Hit systems with an overall porosity of only 0.01% of rock bulk volume can yield sustained well productivities of several thousands of barrels. Minor Previous HitfractureTop porosity related to extension faulting is often responsible for the economic production of tight gas fields.

 

AAPG Search and Discovery Article #91012©1992 AAPG Annual Meeting, Calgary, Alberta, Canada, June 22-25, 1992 (2009)