Role of Cushion Gas on Underground Hydrogen Storage in Depleted Oil Reservoirs

Kanaani, Mahdi; Sedaee, Behnam; Asadian-Pakfar, Mojtaba

doi:10.1016/j.est.2021.103783

Cited by 144 publications

(58 citation statements)

References 16 publications

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“…Relative permeability is a crucial input parameter for the UHS numerical modeling at field scale (Kanaani et al., 2022; Lysyy et al., 2021; Wang et al., 2022). Laboratory gas‐water relative permeability curves often have low endpoint gas saturations (<65%) and relative permeabilities (<40%) due to the rock heterogeneity, capillary end effects, gravity segregation, and/or maximum experimental capillary pressure (Krevor et al., 2012; Muller, 2011).…”

Section: Introductionmentioning

confidence: 99%

Hydrogen Relative Permeability Hysteresis in Underground Storage

Lysyy

Føyen

Johannesen

et al. 2022

Geophysical Research Letters

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Hydrogen (H 2 ) will play a key role in low-carbon energy transitions, and it is vital to implement hydrogen storage technologies to enable its safe and economic use at industrial scale. Underground hydrogen storage (UHS) in porous media such as aquifers, depleted hydrocarbon fields, and coal seams has been proposed as widely available long-term and large-scale storage options (Iglauer et al., 2021;Muhammed et al., 2022). As for underground natural gas storage (UGS), UHS involves cyclic gas injection at peak supply (known as cushion gas) and withdrawal at peak demand (working gas). Despite the increasing attention to the topic worldwide, the fundamentals of multiphase hydrogen flow in porous media are still not well described. In particular, relative permeability hysteresis has not been addressed, although its impact has been previously assessed for UGS and CO 2 storage (Colonna et al., 1972;Juanes et al., 2006). The cyclic nature of the UHS suggests that distinct relative permeability functions must be implemented for hydrogen injection (drainage) and withdrawal (imbibition).Relative permeability is a crucial input parameter for the UHS numerical modeling at field scale (Kanaani et al., 2022;Lysyy et al., 2021;Wang et al., 2022). Laboratory gas-water relative permeability curves often have low endpoint gas saturations (<65%) and relative permeabilities (<40%) due to the rock heterogeneity, capillary end effects, gravity segregation, and/or maximum experimental capillary pressure (Krevor et al., 2012;Muller, 2011). Numerical and/or analytical methods are therefore required to validate and extrapolate relative permeabilities in a wider saturation range.Hydrogen-water relative permeability measurements are scarce in the open literature. Steady state drainage experiments resulted in low endpoint gas saturation (∼60%) and relative permeability (∼4%) (Yekta et al., 2018). The authors used experimental capillary pressure to analytically expand the relative permeability curves to higher

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Section: Introductionmentioning

confidence: 99%

Hydrogen Relative Permeability Hysteresis in Underground Storage

Lysyy

Føyen

Johannesen

et al. 2022

Geophysical Research Letters

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“…For example, the hydrogen diffusion has low medium risk on caprock sealing capacity due to the limited distance of upward migration [81]. However, it may affect the purity of stored hydrogen and reproduction efficiency through the mixing with cushion gas [79,256],…”

Section: Implications Challenges and Future Workmentioning

confidence: 99%

Storage Integrity during Underground Hydrogen Storage in Depleted Gas Reservoirs

Zeng¹,

Sarmadivaleh²,

Saeedi³

et al. 2022

Preprint

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The transition of energy from fossil fuels to renewable energy particularly hydrogen is becoming the centre of decarbonization and roadmap to achieve net-zero carbon emission. To meet the requirement of large-scale hydrogen storage as a key part of hydrogen supply chain, underground hydrogen storage can be the ultimate solution to economically store hydrogen thus meet global energy demand. Compared to other types of subsurface storage sites such as salt caverns and aquifers which are limited to geographical locations, depleted gas reservoirs have been raising more interest because of the wider distribution and higher storage capacity. However, safely storing and cycling of hydrogen in depleted gas reservoirs requires caprock, reservoir and wellbore to remain high stability and integrity. Nevertheless, current research on storage integrity during underground hydrogen in depleted gas reservoirs is still scarce and non-systemic. We therefore reviewed the major challenges on storage integrity associated with geochemical reactions, microbial activities, faults and fractures and hydrogen cycling perspectives. The processes and impacts of abiotic and biotic mineral dissolution/precipitation, faults and fracture reactivation and propagation in caprock and host-rock, wellbore instability due to cement degradation and casing corrosion, stress change during hydrogen cycling, etc. on storage integrity were comprehensive reviewed and analysed. Furthermore, a technical screening tool with consideration of controlling variables, risks and consequences on storage integrity was developed to identify the potential risks associated with storage integrity. Lastly, knowledge gaps together with feasible methods and pathways have been identified to mitigate the risks and thus enables large-scale underground hydrogen storage.

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“…5−7 Also, there are many similarities between underground hydrogen storage and underground natural gas storage (UGS). 5,8 Therefore, a UHS project can often benefit from the lessons from UGS projects in terms of storage site selection, storage techniques, monitoring, and even the number and composition of injection/withdrawal cycles. The UHS process is also impacted by risks that threaten the quality of UGS operations.…”

Section: Introductionmentioning

confidence: 99%

“…Several types of hydrogen storage are being considered, including porous rocks (depleted natural gas and oil reserves and aquifers) and artificial underground spaces (salt caverns and disused mine workings) . In addition to their known geological structure, the intact compactness and integrity of the source rocks, and the preexistence of surface facilities, the depleted hydrocarbon reserves are the best choice for large-scale UHS. − Also, there are many similarities between underground hydrogen storage and underground natural gas storage (UGS). , Therefore, a UHS project can often benefit from the lessons from UGS projects in terms of storage site selection, storage techniques, monitoring, and even the number and composition of injection/withdrawal cycles. The UHS process is also impacted by risks that threaten the quality of UGS operations.…”

Section: Introductionmentioning

confidence: 99%

“…However, the impact of geomechanics on the quality and quantity of UHS operations in depleted reservoirs has not been studied like some other parameters, such as wettability − and interfacial tension . Studies of underground hydrogen gas storage in depleted reservoirs and saline aquifers have focused more on modeling fluid dynamics in porous media. ,,− Depleted gas reservoirs for underground hydrogen storage have attracted more attention. However, depleted oil reservoirs should not be neglected for hydrogen storage due to their wide distribution around the world and high storage capacity.…”

Section: Introductionmentioning

confidence: 99%

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Impact of Dilation and Irreversible Compaction on Underground Hydrogen Storage in Depleted Hydrocarbon Reservoirs

Kanaani

Sedaee

2022

Energy Fuels

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Underground hydrogen gas storage (UHS) at depleted hydrocarbon reservoirs may balance energy production/ consumption during seasons by utilizing the capability of hydrogen gas. The geomechanical behavior of the reservoir rock during UHS operation cycles is an effective parameter of the overall quality and quantity of this operation. This study investigated the impact of rock geomechanical behavior on the quality and quantity of UHS operation performance in a depleted oil reservoir. Three geomechanical behaviors, namely, elastic deformation, irreversible compaction of rock, and dilation−recompaction, form the basis of this study. We numerically investigated how these cases affect wellbore injectability, hydrogen recovery, production of in situ reservoir fluids, and the number of hydrogen injection/production wells. Based on the results of this study, the performance of wells during the injection of hydrogen in the dilation case was better than in other cases. After 10 cycles, 87% of the designed cumulative volume of hydrogen was injected into the reservoir. Though the irreversible compaction case injected the least cumulative hydrogen, it generated the highest hydrogen recovery during annual cycles and at the end of UHS operation (93%). The production of nonhydrogen fluids is known as a problem in UHS operations in depleted hydrocarbon reservoirs. After 10 cycles of hydrogen injection and production and 3 years of prolonged production, the dilation case produced less water and oil overall than other cases. Also, fewer wells are required to achieve the designed injection amount in the dilation case compared to base and irreversible compaction cases. Therefore, the costs associated with hydrogen injection and production wells in reservoirs with geomechanical dilation behavior are lower.

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Role of Cushion Gas on Underground Hydrogen Storage in Depleted Oil Reservoirs

Cited by 144 publications

References 16 publications

Hydrogen Relative Permeability Hysteresis in Underground Storage

Hydrogen Relative Permeability Hysteresis in Underground Storage

Storage Integrity during Underground Hydrogen Storage in Depleted Gas Reservoirs

Impact of Dilation and Irreversible Compaction on Underground Hydrogen Storage in Depleted Hydrocarbon Reservoirs

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