Multiscale Micro-CT Imaging from Core to Pore

Traditional methods for characterizing rocks often rely on destructive sectioning or offer only 2D data, making it difficult to extract accurate petrophysical or structural information. By contrast, multiscale micro-CT imaging provides a non-invasive alternative that overcomes several key limitations:

Loss of Pore Structure Resolution: Low-resolution, large scale CT scans (on medical CT systems)  often miss critical heterogeneities that influence flow and trapping.

Scale Mismatch: Large-scale CT scans don’t resolve micropores well, while high-resolution scans may lack full-sample context.

Inaccurate Porosity Estimation: Bulk porosity measurements from gravimetric methods overlook local variations and true pore geometry.

Destructive Analysis Risks: Cutting or polishing samples can alter fracture networks, induce sample disintegration, or redistribute fine materials.

Multiscale micro-CT imaging provides the spatially resolved, 3D data needed to analyze entire cores and fine pore structures with confidence.

TESCAN’s multiscale imaging workflow brings together wide-field and high-resolution micro-CT scanning, to capture reservoir cores at multiple resolutions—all without cutting the sample.

 Key Steps in the Workflow:

This multiscale workflow gives reservoir engineers a robust, non-destructive way to extract high-quality data for EOR planning and digital rock physics.

Multiscale Imaging Across Core Dimensions

Wide-field Micro-CT imaging reaches spatial resolutions down to a few micrometers, while high-resolution Micro-CT pushes that boundary further into the sub-micron range.

• Core-to-Pore Connectivity: Study the links between large-scale geological features and pore-scale transport processes.

• Fracture Flow Characterization: Analyze how fluids move between fractures and surrounding matrix materials at multiple scales.

• Porosity and Capillary Pressure Calculations: Use grayscale segmentation to determine pore volume and simulate fluid behavior through the rock.

• Integration into Reservoir Simulation: Feed these datasets into relative permeability models, saturation curves, and digital rock typing workflows.

By aligning data across scales, engineers gain a more complete understanding of reservoir behavior under real-world flow conditions.

Reservoir Characterization

Visualize lithological variation, sedimentary layering, and pore morphology across entire core plugs. High-resolution images support accurate digital rock typing, especially in light oil reserves.

Pore Network Modeling

Extract 3D pore structures at micron resolution from core fragments or drill cuttings. Create models that retain key flow characteristics for realistic simulations.

Enhanced Oil Recovery (EOR)

Monitor chemical movement and oil displacement during flooding experiments. See how surfactants or polymers affect residual oil and flow paths.

Fracture Mapping

Measure fracture aperture, density, and connectivity to evaluate flow potential in tight or naturally fractured reservoirs.

Core Integrity Assessment

Examine the internal structure of cores non-destructively, preserving them for physical testing or long-term archiving.

These use cases show how multiscale micro-CT imaging delivers vital insights into pore structure, petrophysical behavior, and subsurface fluid dynamics.