Hystorm – Clean offshore energy by hydrogen storage in petroleum reservoirs

Clean offshore energy by hydrogen storage in petroleum reservoirs.

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About the project

In the Hystorm project, we study whether energy, in the form of hydrogen (H2), can be stored safely underground in depleted oil and gas reservoirs offshore Norway. This opens for a clean energy supply platform and a renewable offshore future for the country.

About Hystorm Research Group

Objectives

The multi-disciplinary research team will perform fundamental studies to assess the feasibility of using depleted hydrocarbon reservoirs on the Norwegian Continental Shelf as storage sites for high-purity hydrogen. The multi-disciplinary research team will perform fundamental studies to assess the feasibility of using depleted hydrocarbon reservoirs on the Norwegian Continental Shelf as storage sites for high-purity hydrogen.

Financing

The HYSTORM project (grant number 315804) is awarded funding from the Research Council of Norway under the PETROMAKS2 Program (Large Program for Petroleum Research) for four years (2021-2024).

Cooperation

The main project is lead by Pierre Cerasi, SINTEF, Trondheim. The project is a cooperation between several researchers from the institutions below:

Masoudi, Mohammad; Hassanpouryouzband, Aliakbar; Hellevang, Helge & Haszeldine, R. Stuart (2024). Lined rock caverns: A hydrogen storage solution. Journal of Energy Storage. ISSN 2352-152X. 84. doi: 10.1016/j.est.2024.110927.
Betken, Benjamin; Austegard, Anders; Finotti, Francesco; Caccamo, Chiara; Stang, Hans Georg Jacob & Khosravi, Bahareh [Show all 7 contributors for this article] (2024). Measurements of the Viscosity of Hydrogen and a (Hydrogen + Methane) Mixture with a Two-Capillary Viscometer. International journal of thermophysics. ISSN 0195-928X. 45(4). doi: 10.1007/s10765-023-03328-6. Full text in Research Archive Show summary
Measurements of the viscosity of pure hydrogen and a binary (hydrogen + methane) mixture with a nominal composition 90 mol % hydrogen are presented. The measurements were conducted with a two-capillary viscometer relative to helium along three isotherms of (298.15, 323.15, and 348.15) K and at pressures of up to 18 MPa. Expanded relative combined uncertainties in viscosity range from (0.65 to 2.7) % (k = 2) for the hydrogen data, and from (0.91 to 3.2) % (k = 2) for the (hydrogen + methane) data. The viscosity data are compared to experimental literature data and viscosity correlations implemented in the NIST REFPROP v10.0 database. Good agreement between this work’s data, literature data, and the viscosity correlation was achieved for pure hydrogen. The (hydrogen + methane) mixture was compared to the Extended Corresponding States (ECS) model implemented in REFPROP v10.0. Relative deviations between the experimental data and the ECS model exceed the experimental uncertainty and were found to exhibit a positive trend with increasing density and a weakly pronounced negative trend with increasing temperature. No experimental literature data are available at overlapping state regions. Nonetheless, deviations to the ECS model imply reasonable consistency of this work’s data and literature data. In addition to experimental viscosities, experimental zero-density viscosity ratios of the fluids under investigation and helium are reported. Fairly good agreement within the experimental uncertainty of this work with a highly accurate literature value and a value obtained from accurate ab initio calculated data was achieved for hydrogen.
Emmel, Benjamin; Bjørkvik, Bård Johan Arnt; Føyen, Tore Lyngås; Cerasi, Pierre & Stroisz, Anna Magdalena (2023). Evaluating the hydrogen storage potential of shut down oil and gas fields along the Norwegian continental shelf. International Journal of Hydrogen Energy. ISSN 0360-3199. 48(63), p. 24385–24400. doi: 10.1016/j.ijhydene.2023.03.138. Full text in Research Archive
Zonetti, Simone; Dupuy, Bastien; Emmel, Benjamin & Romdhane, Mohamed Anouar (2023). Monitoring casing corrosion of legacy wells using CSEM: implications for large-scale energy and CO2 storage projects in shut-down hydrocarbon fields. The Leading Edge. ISSN 1070-485X. 42(12), p. 808–816. doi: 10.1190/tle42120808.1. Full text in Research Archive
Hellevang, Helge; Nooraiepour, Mohammad & Masoudi, Mohammad (2023). Mineral nucleation and growth in porous and fractured media. Goldschmidt Conference Abstracts. Show summary
Early simulation works on carbonization during CO2 storage overpredicted the amount and rate of mineral formation because of unrealistic growth models based on transition state theory (TST), where surface areas for growth were assumed to be present from day one. Inspired by [1], we made our first nucleation-growth model a decade ago [2], providing a zero-dimensional averaged kinetic nucleation-growth model for the continuum scale. This model provided some information on lag time for the onset of mineral growth, which is essential to understand why the lack of mineralization in short-term laboratory experiments cannot be extrapolated in time. The continuum-scale models, however, lack the potential to predict how the pore space geometries change and, thereby, how the permeability-porosity relationship changes in complex ways. Recent efforts have been to implement mineral nucleation and crystal growth in pore-scale models, using classical nucleation theory (CNT) and statistically derived expressions for the induction time of the formation of stable growing crystallites. In the new expressions, the probability of creating a crystallite at each surface site (solid surface area in the pore space) is estimated based on a normal distribution centered around the mean induction time value [τ] (symmetric between t= 0 and 2τ). This has been implemented and tested in 2D pore-scale models, showing strong mutual relations and impacts of transport and crystallization in porous media [3-4]. Another emerging field for nucleation-growth research is how the number of crystallites (or aggregates) and their spatial distribution control the evolution of porosity-permeability relations. 2D nucleation-growth Monte Carlo-type pore-scale RTMs show that the permeability-porosity relationship and the associated uncertainty depend on the number of crystallites (Figs. 1, 2). The relationship evolves predictably if the number of crystallites is small or large. If, on the other hand, the number of crystals is in an intermediate range, the permeability-porosity dynamics vary stochastically and are highly uncertain.

View all works in Cristin

Masoudi, Mohammad & Hellevang, Helge (2023). Near injector salt scale buildup in CCS due to CO2 plume drying of aquifer.
Masoudi, Mohammad (2023). Estimating Hydrogen Sorption Capacity of clay-rich Caprocks.
Masoudi, Mohammad; Nooraiepour, Mohammad & Hellevang, Helge (2023). Assessment of hydrogen uptake ability of clay-rich caprocks.
Masoudi, Mohammad; Nooraiepour, Mohammad & Hellevang, Helge (2023). How does probabilistic nucleation control the spatiotemporal distribution of minerals in porous media?
Masoudi, Mohammad; Ahmed, Elyes; Raynaud, Xavier Marcel & Hellevang, Helge (2023). Is salt precipitation an issue during geological storage of hydrogen in saline aquifers? from thermodynamic perspective using PC-SAFT EoS.
Ringstad, Cathrine (2022). Energy storage panel discussion.
Ringstad, Cathrine; Cerasi, Pierre; Suire, Matthieu; Xie, Xiyang & Emmel, Benjamin Udo (2022). HyStorm - avoiding leakage through effective reservoir management.
Suire, Matthieu; Xie, Xiyang & Cerasi, Pierre (2022). Periodic Storage of Hydrogen in Sandstone Reservoirs in the Norwegian offshore – Geomechanical Analysis.
Stroisz, Anna Magdalena; Føyen, Tore Lyngås; Emmel, Benjamin Udo; Bhuiyan, Mohammad Hossain & Cerasi, Pierre (2022). Impact of hydrogen on rock strength and ultrasonic velocity.
Emmel, Benjamin Udo; Stroisz, Anna Magdalena; Føyen, Tore Lyngås; Bjørkvik, Bård Johan Arnt & Cerasi, Pierre (2022). From HYSTORM to HY4GET- Hydrogen storage projects at SINTEF - Applied Geoscience.