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Study on the Fluid-Solid Coupling Seepage of the Deep Tight Reservoir Based on 3D Digital Core Modeling
1 PetroChina Tarim Oilfield Company, Korla, 841000, China
2 CNPC R&D Center for Ultra-Deep Complex Reservoir Exploration and Development, Korla, 841000, China
3 National Key Laboratory of Deep Oil and Gas, China University of Petroleum (East China), Qingdao, 266580, China
4 Structure and Shipping Department, Offshore Oil Engineering (Qingdao) Co., Ltd., Qingdao, 266520, China
* Corresponding Authors: Haijun Yang. Email: ; Jing Li. Email:
Energy Engineering 2025, 122(2), 537-560. https://doi.org/10.32604/ee.2024.058747
Received 19 September 2024; Accepted 04 December 2024; Issue published 31 January 2025
Abstract
Deep tight reservoirs exhibit complex stress and seepage fields due to varying pore structures, thus the seepage characteristics are significant for enhancing oil production. This study conducted triaxial compression and permeability tests to investigate the mechanical and seepage properties of tight sandstone. A digital core of tight sandstone was built using Computed Tomography (CT) scanning, which was divided into matrix and pore phases by a pore equivalent diameter threshold. A fluid-solid coupling model was established to investigate the seepage characteristics at micro-scale. The results showed that increasing the confining pressure decreased porosity, permeability, and flow velocity, with the pore phase becoming the dominant seepage channel. Cracks and large pores closed first under increasing pressure, resulted in a steep drop in permeability. However, permeability slightly decreased under high confining pressure, which followed a first-order exponential function. Flow velocity increased with seepage pressure. And the damage mainly occurred in stress-concentration regions under low seepage pressure. Seepage behavior followed linear Darcy flow, the damage emerged at seepage entrances under high pressure, which decreased rock elastic modulus and significantly increased permeability.Keywords
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