Xavier Junior, Milton MoraisKiam, Thiago Noboru Leite2021-09-232021-09-232021-09-20KIAM, Thiago Noboru Leite. Análise de permeabilidade e porosidade em modelo 3D a partir de simulação numérica. 2021. 62f. Trabalho de conclusão de curso (Graduação em Geofísica), Departamento de Geofísica, Universidade Federal do Rio Grande do Norte, Natal, 2021.https://repositorio.ufrn.br/handle/123456789/37987The natural resource reservoirs usually present a high degree of morphological heterogeneity. The risk of destructive processes during laboratory analysis, as well as the logistical and financial difficulty in obtaining and replacing reservoir samples, has led the scientific community to invest in less invasive and more cost-effective techniques. Thus, in order to overcome these challenges, computational petrophysics emerges as an approach for digital analysis and simulation of physical properties in porous systems to estimate parameters and preserve the integrity of analyzed samples. The purpose of this work is to simulate the fluid flow in a laminar regime on an artificial rock and to estimate porosity and permeability from X-ray microtomography images of the sample. The work started by using the Simpleware software for segmenting the X-ray image sequence of a cylindrical sample constituted by the sintering of glass spheres, with a voxel resolution of 0.019751 mm. Aiming to reduce computation time, the sample was cut in the shape of a parallelepiped with dimensions of 13.8257x13.8257x0.217261 mm³. A threshold value was adopted following the Otsu method in order to distinguish pores from the grain phase. The mesh was elaborated in coarse size, containing a total of 27482 nodes. Then, the file was imported into Comsol Multiphysics software, which uses the Finite Element Method (FEM) to perform numerical simulations. The single-phase fluid utilized has characteristics similar to water, with density and dynamic viscosity respectively equal to 1000 kg/m³ and 0.001 Pa.s. A difference of 0.005 Pa in fluid pressure was applied to the model and the absolute porosity and permeability values reached 9.67% and 8.16 x 10-10 m², respectively. These results demonstrate that the employed technique is satisfactory and shows promise for use in the development of future work applied to natural rocks, given that digitally obtained parameters are compatible with laboratory petrophysical measurements.Attribution-NoDerivs 3.0 Brazilhttp://creativecommons.org/licenses/by-nd/3.0/br/Petrofísica computacionalSegmentaçãoSimulação numéricaPetrofísicaPorosidadePermeabilidadeComputational petrophysicsNumerical SimulationSegmentationPetrophysicsPorosityPermeabilitybachelorThesis