Tight gas sands permeability estimation from mercury injection capillary pressure and nuclear magnetic resonance data
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There are several methods to estimate permeability from pore throat sizes and NMR T2 relaxation time. Although most of the methods are well-established and work well for conventional reservoirs they fail to estimate permeability for tight gas sands. The aim of this study was to establish relationships between permeability and pore throat sizes, derived from mercury injection analysis, and NMR T2 relaxation time. Regression analysis was used to achieve a set of relationships between dry gas permeability, porosity and pore throat sizes for 50 tight gas sand samples. Unlike for normal sandstone, pore throat radii corresponding to a mercury saturation of 10% (r10) is the best permeability predictor for tight gas sands. For tight gas sands, NMR T2 relaxation spectra fall on the shorter values corresponding to the smaller pores. This is because pore spaces are significantly reduced both in size and volume due to extensive compaction and cementation. This study shows that using NMR T2peak and multi-regression analysis, permeability can be estimated with high accuracy even in rocks with substantially constricted pore throats.
NOTICE: this is the author’s version of a work that was accepted for publication in Journal of Petroleum Science and Engineering. Changes resulting from the publishing process, such as peer review, editing, corrections, structural formatting, and other quality control mechanisms may not be reflected in this document. Changes may have been made to this work since it was submitted for publication. A definitive version was subsequently published in Journal of Petroleum Science and Engineering, Vol. 88-89 (2012). DOI: 10.1016/j.petrol.2011.12.014
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