Dynamic permeability response and stress sensitivity of tight sandstone reservoirs: insights from pore structure and predictive modeling

Abstract

This study examines permeability response to pore structure evolution under effective stress in six sandstone reservoirs of varying physical properties, using CTS, SEM, QEMSCAN, DP-NMR, fractal theory, and pore compression theory. The sandstones comprise quartz (82.56%), rock fragments (7.60%), clay minerals (5.66%), siliceous (0.1%–4.3%, avg. 2.21%), and carbonate (0.05%–6.95%, avg. 1.8%) cements, with intergranular pores, micropores, and minor intragranular dissolution pores. Stress sensitivity increases from Type I to III: large pores exhibit the highest sensitivity in Types I and III (compressibility: 0.011 and 0.005 MPa⁻¹), while small pores dominate in Type II (0.008 MPa⁻¹). Fractal dimensions of small/total pores (DS, DT) decrease in Types I/III, whereas in Type II, DT increases and DS first decreases then increases due to clay minerals; large pore fractal dimension (DL) increases modestly across all types. Permeability stress sensitivity is controlled by large pore volume changes, which correlate exponentially with effective stress. A predictive permeability model based on pore volume stress-strain theory provides theoretical guidance for hydrocarbon production.

Graphical abstract

Keywords

tight sandstone reservoir / pore stress-strain / heterogeneity / compressibility coefficient / permeability

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