DigitalROCK - Pore-Scale Simulation

Powered by SIMULIA’s best-in-class Lattice Boltzmann physics, DigitalROCK® provides the first reliable, predictive technology for digital pore-scale simulation of relative permeability. The ability to accurately simulate two-phase flow, such as oil and water, through reservoir rock was co-developed and extensively validated with oil and gas industry leaders. Electric vehicle manufacturers and other major users of batteries can also benefit from using DigitalROCK to characterize the microstructure of the battery cell.

Available as a web-based application on the cloud, the streamlined DigitalROCK workflow goes from image to results easily and efficiently. Simulation enables unprecedented access to data for the engineers who need it. The user interface is easy and intuitive, and cloud delivery avoids infrastructure, hardware, and IT issues to minimize up-front expenses.

DigitalROCK Features & Benefits

The fastest path from rock to results, the DigitalROCK approach starts by imaging a sample - whether whole core, sidewall/rotary core, or even cuttings. After uploading the image and running selected analyses, users navigate easily through the results to see computed petrophysical properties and 3D visualizations. These results include:

Pore space analysis - Porosity, connected porosity, and pore size distribution.
MICP curves - Digital version of the standard Mercury Injection Capillary Pressure (MICP) test, essential for core analysis.
Absolute permeability - Evaluate porosity-permeability trend; perform multi-directional analysis to evaluate anisotropy.
Relative permeability - Key reservoir model input characterizing multi-phase flow; indicates residual (trapped) oil.
Capillary desaturation - Reveals flow conditions required for secondary or tertiary oil recovery.

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