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Formation damage remains a critical challenge in reservoir characterization and flow assurance, as physical and chemical interactions between injected fluids and rock matrices can significantly alter pore structure and permeability. In this study, X-ray micro-computed tomography (microCT) is employed as a non-destructive three-dimensional imaging technique to evaluate formation damage in reservoir rock samples, providing direct visualization and quantitative assessment of pore-scale alterations.
MicroCT analyses were conducted on rock plugs subjected to controlled damage-inducing processes, allowing direct comparison between pre- and post-damage states. The methodology integrates high-resolution 3D imaging with image processing and segmentation workflows to quantify changes in porosity distribution, pore connectivity, and solid-fluid interfaces. Complementary mineralogical information was used to support interpretation of damage mechanisms associated with fines migration and mineral-fluid interactions.
The results demonstrate that microCT enables spatially resolved identification of damage features that are not accessible through conventional bulk measurements alone. Significant modifications in pore throat geometry and local connectivity were observed, highlighting the heterogeneous nature of formation damage and its dependence on lithology and mineralogical composition. The three-dimensional datasets further reveal preferential zones of damage development, emphasizing the importance of volumetric analysis for reliable interpretation.
This work highlights the potential of microCT as a powerful tool for formation damage studies, offering a robust workflow for experimental evaluation of pore-scale processes in reservoir rocks. The approach provides practical insights for laboratory testing, digital rock analysis, and the interpretation of damage mechanisms relevant to subsurface energy applications.

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