Modelagem computacional multiescala de reservatórios não convencionais de gás em folhelhos

• Autor(a) principal: Pereira, Patrícia de Araújo
• Data de Publicação: 2015
• Tipo de documento: Tese
• Idioma: por
• Título da fonte: Biblioteca Digital de Teses e Dissertações do LNCC
• Texto Completo: https://tede.lncc.br/handle/tede/235
• topic: Fenômenos de transporte; Transport phenomena; CNPQ::CIENCIAS EXATAS E DA TERRA::FISICA::AREAS CLASSICAS DE FENOMENOLOGIA E SUAS APLICACOES

In this work a new multiscale computational model is developed to describe with accuracy the hydrodynamics in shale gas reservoirs. The multiscale model is constructed exploring the multimodal shale pore size distribution characterized by three distinct levels of porosity (nanopores, micropores and fractures) and four di erent length scales: nano, micro, meso and macro. At the nanoscale, gas adsorption in the organic matter is modeled using the Thermodynamics of Inhomogeneous Gases. Adsorbed gas and nanopres are homogenized forming the organic aggregates, which together with the inorganic phase (clay, calcite, quartz) and micropores constitute the porous medium at the microscale. Micropores are considered partially saturated by immobile water with dissolved and free gas movement ruled by Fickian di usion and Darcy's ow with higher apparent permeability induced by the slippage mechanism at the pore wall and Knudsen di usion. Mass exchange between free and dissolved gas phases is computed invoking local thermodynamical equilibrium with equality between gas fugacities in both phases. At the mesoscale, the multiphase system is treated as an overlaying continuum, forming the shale matrix, where ow takes place towards the hydraulic fracture network. The coupling between gas ow in shale matrix and fractures gives rise to the mesoscopic model. In order to construct the macroscopic model, information from the ner scales is transfered to coarser scales through a formal homogenization procedure based on asymptotic expansions together with a reduced dimension technique, where fractures are treated as (n􀀀1)-interfaces (n = 2; 3), with average properties computed accross fracture aperture. Such development leads to a macroscopic model characterized by a new pressure equation in the shale matrix coupled through a source term with the hydrodynamics of gas ow in the hydraulic fractures. Nano and micro models are explored to numerically reconstruct constitutive laws for the e ective parameters on the new pressure equation: hydraulic conductivity and storativity coe cient, the latter dependent on TOC (total organic content), water saturation, nano and micro porosities. The macroscopic model is discretized by the fi nite element method and numerical simulations of gas recovery processes using input data from existing formations are presented and compared with results found in the literature.