■ An upscaling-downscaling technique was developed in-house to speed up the modelling of flow and transport in uncertain porous media,
■ Multiscale modelling of heat transfer in fractured systems,
■ Upscaling of transport properties from pore scale simulation.

■ Hydrogen production through combination of steam methane reforming (SMR) and water gas shift (WGS),
■ Through an NDA with METHARC, a concept of in-situ hydrogen production from natural gas reservoirs has been verified using computer programming of reactions in catalyst-coated membranes similar to Cloete et al, but at reservoir pressure and temperature.

■ Use of Probabilistic Collocation Method (PCM) to efficiently quantify parametric uncertainty. The method has been utilised in the context of CO₂ residual trapping estimation. The result is comparable to Monte Carlo simulations (MCS) that is inefficient and requires an order of magnitude more function evaluation.


■ Surrogate response surfaces are utilised to find best well/wells location to maximise residual trapping of CO₂.

The current research in this area include modelling of:
■ Convective dissolution using in-house developed codes,

■ Convective dissolution of CO₂ coupled with geochemistry,
■ Diffusion-enhanced hydrocarbon recovery from fractured porous media using Schlumberger ECLIPSE reservoir simulator,
■ CO₂-enhanced geothermal heat recovery using Schlumberger ECLIPSE reservoir simulator.
■ CO₂ injection scenarios for the North Sea reservoirs.

The group has expertise is modelling heat flow in:
■ Hot sedimentary aquifers using Schlumberger ECLIPSE reservoir simulator.
■ Fractured geothermal system using in-house developed codes.
■ CO₂ plume geothermal: utilisation of CO₂ to extract heat from the geothermal reservoirs.

■ In-house code development for natural, surfactant-enhanced, and bio- remediation of NAPL and DNAPL in porous media supported by EP/R009678/1 Multiscale modelling of miscible interfaces: Application on surfactant-enhanced aquifer remediation. Publications from this research are listed here. Dr Morteza Aminnaji worked on this project in 2018-2020.

■ Biofilm development using pore network modelling.

■ In-house code development (pore network modelling) for flow of fluid in triple- and quadruple-porous systems including tight rocks (shale).

■ Combination of machine learning and numerical simulations to accelerate modelling of the fluid flow through micro-structured materials.

■ Data augmentation for the segmentation of placental histological images for an automated morphological characterization of inter-villous space to make bio-markers.

In-house code development for modelling rock matrix acidizing:
■ Wormhole development under two-phase flow conditions,
■ Wormhole development under spatially correlated permeability,
■ A project was conducted for TotalEnergies to determine the efficiency of perforated acidizing.