EGU21-7738, updated on 04 Mar 2021
https://doi.org/10.5194/egusphere-egu21-7738
EGU General Assembly 2021
© Author(s) 2021. This work is distributed under
the Creative Commons Attribution 4.0 License.

Compositional simulation of hydrogen storage in a depleted gas field

Jonathan Scafidi1, Laurent Schirrer2, Isabelle Vervoort2, and Niklas Heinemann1
Jonathan Scafidi et al.
  • 1The University of Edinburgh, School of Geosciences, Edinburgh, United Kingdom (jonathan.scafidi@ed.ac.uk)
  • 2Hydrenor, Centurion Court, N Esplanade W, Aberdeen, AB11 5QH, United Kingdom

UK natural gas demand is 2-4 times that of electricity and characterised by seasonal differences in demand of almost triple in the winter with larger spikes during extreme cold weather events. This makes any decarbonisation effort reliant on its ability to handle these large changes in demand. Conversion of the gas supply to hydrogen is the most promising solution. To facilitate this, large-scale underground storage will be required in the order of 150 TWh or 40 days’ worth of supply.

Subsurface gas storage in porous rocks requires a proportion of the gas to remain in the reservoir to maintain the pressure required for the minimum economic flow rate from the wells. This is called the cushion gas requirement. In the case of a hydrogen storage reservoir the use of a cheaper cushion gas, such as CO2 or N2, is the subject of much research.

We investigate the possibility of using natural gas within a partially depleted gas reservoir as cushion gas. We will present the results of a compositional simulation of seasonal hydrogen storage over a 20 year period in a closed reservoir. The study shows that natural gas has potential as a cushion gas, in this case achieving greater than 95% hydrogen recovery factors with minimal amounts of mixing in the reservoir. Use of natural gas as cushion gas also reduces the risk of water coning which can lead to loss of hydrogen.

Although these results are promising, the study highlights several key areas that need further investigation to improve the reliability of future simulations. These include defining relative permeability curves for hydrogen, refinement of how simulators handle viscosity equations, and a greater understanding of hydrogen well engineering. All of these factors will influence estimates of the hydrogen capacity of a porous rock reservoir.

How to cite: Scafidi, J., Schirrer, L., Vervoort, I., and Heinemann, N.: Compositional simulation of hydrogen storage in a depleted gas field, EGU General Assembly 2021, online, 19–30 Apr 2021, EGU21-7738, https://doi.org/10.5194/egusphere-egu21-7738, 2021.

Corresponding presentation materials formerly uploaded have been withdrawn.