Toward a Fundamental Understanding of Geological Hydrogen Storage

Abstract

Geological H 2 storage plays a central role to enable the successful transition to the renewable H 2 economy and achieve net-zero emission in the atmosphere. Depleted oil and gas reservoirs are already explored with extensive reservoir and operational data. However, residual hydrocarbons can mix with injected H 2 in the reservoirs. Furthermore, low density and high diffusivity of H 2 may establish H 2 leakage from the reservoirs via fault pathways. Interestingly, H 2 can be consumed by microorganisms, which results in pore-network precipitation, plugging, and partial permeability impairment. Therefore, stored H 2 may be lost in the formations if the storage scenario is not planned cautiously. While salt caverns are safe and commercially proven geo-rock for H 2 storage, they have low-storage capacity compared to depleted gas reservoirs. Moreover, salt structures (e.g., domel, bedded) and microorganisms activities in the salt cavern are limiting factors, which can influence the storage process. Accordingly, we discuss challenges and future perspectives of hydrogen storage in different geological settings. We also highlight geographical limitations with diverse microbial communities and theoretical understanding of abiotic transformation (in terms of rock's minerals, i.e., mica and calcite) for geological H 2 storage. Regarding the fundamental behavior of H 2 in the geological settings, it is less soluble in formation water; therefore, it may achieve less solubility trapping compared to CO 2 and CH 4 . Furthermore, H 2 gas could attain higher capillary entrance pressures in porous media over CH 4 and CO 2 due to higher interfacial tension. Additionally, the low viscosity of H 2 may facilitate its injection and production but H 2 may establish the secondary trapping and viscous fingering. Thus, this review documents a blend of key information for the amendment of subsurface H 2 storage at the industrial scale.

Relative Permeability of Hydrogen and Aqueous Brines in Sandstones and Carbonates at Reservoir Conditions

“…Renewable energy resources (solar, wind, biomass, and waves) are considerably affected by the seasonal fluctuation of atmospheric parameters (e.g., temperature, sunshine, and wind force), which when coupled with changing energy demand, can lead to renewable energy excesses or deficits (Abe et al., 2019). As such, it will not be possible to balance the supply with demand of a wholly renewable energy system without large‐scale storage (Aftab et al., 2022; Muhammed et al., 2022; Osman et al., 2021). Energy storage solutions ensure efficiency, flexibility, and security of the energy system.…”

Geological Hydrogen Storage: Geochemical Reactivity of Hydrogen with Sandstone Reservoirs

“…Additional experience of geological gas storage in porous rocks has been gained through the commercial operation of over 670 natural gas storage sites and over 30 carbon dioxide storage sites. 6 − 8 Published studies consider geological hydrogen storage to be technically feasible; however, several reviews have identified challenges which must be addressed to prove the safe containment and necessary recovery efficiencies of hydrogen in porous reservoirs. 3 , 9 − 13 The major barriers currently restricting the development of hydrogen storage are the following: (i) Hydrogen is characterized by a lower viscosity and higher mobility than natural gas and carbon dioxide.…”

Investigation of Using Various Quantities of Steelmaking Waste for Scavenging Hydrogen Sulfide in Drilling Fluids

“…The rheology measurements (Figure 3) revealed that the base mud had an AV value of 18.7 cP, a PV of 8.8 cP, and a Figure 2: The H 2 S concentration in the outlet gas stream as a function of time. 4 Geofluids YP of 14.4 lb/100 ft 2 . The TRZM exhibited higher AV, PV, and YP values of 21 cP, 10 cP, and 17.9 lb/100 ft 2 , respectively.…”

“…The presence of hydrogen sulfide (H 2 S) gas is a frequent problem encountered when drilling subsurface hydrocarbon formations. This gas is naturally found in oil and gas reservoirs and is formed either by geological or microbiological processes [1][2][3][4]. H 2 S invades the drilling system through either invading formations containing H 2 S-contaminated fluids, the metabolism of sulfate-reducing bacteria that survive in anaerobic conditions, or the thermal degradation of sulfur-containing drilling fluid additives [5][6][7][8].…”