Energy Ventures' portfolio company Ingrain is advancing the upstream industry by analyzing critical flow factors including porosity and permeability digitally. This means faster and more accurate results than those achieved through traditional core analysis. Download this white paper to learn more about how their work applies specifically to carbonates.

Mostyn Wall,* Joe Cartwright,* Richard Davies† and Andrew McGrandle‡
(* Cardiff University, † University of Durham ‡ ARKeX Ltd)
Published in Basin Research (2009)

The nano-CT scanners at Ingrain can resolve features as small as internal micrite pores as such features become salient for computing the physical properties of carbonate.

Ingrain's technology leads the industry in providing advanced rock properties analysis for shale, carbonates, tight gas sands and oil sands.

Ingrain complements and vastly expands laboratory permeability data sets by numerically simulating fluid flow through a direct digital representation of a real pore space obtained by high-resolution 3D imaging.

Ingrain determines elastic moduli by simulating a static deformation experiment on a 3D digital rock sample.

Ingrain uses the finite element method (FEM) to solve the Laplace equation for the electric potential field inside a digital sample for a specified potential difference at the boundaries.

Ingrain uses proprietary image-processing algorithms for statistical analysis and image segmentation to determine porosity.

Relative permeability is the ratio of effective permeability of a particular fluid at a particular saturation to the absolute permeability of that fluid at total saturation.

P Houghton, D Bate, M Davies, J. M. Lumley
(ARKeX Ltd)