Simulations of CO 2  storage in aquifer models with top surface morphology and transition zones

Shariatipour, Seyed M.; Pickup, Gillian Elizabeth; Mackay, Eric James

doi:10.1016/j.ijggc.2016.06.016

Cited by 26 publications

(25 citation statements)

References 27 publications

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“…However, the amount of dissolved CO2 in brine for 0.01 is lower than the ratio of 1 before the injection stops and then increases after shut-in. Since the results we achieved are not in agreement with the results by former researchers for pre-shut-in duration [24], (Fig. 8).…”

Section: Resultscontrasting

confidence: 93%

“…In contrast, in deeper aquifers both temperature and the salinity increase and thus the dissolution of CO2 in formation brine decreases. However, it should be noted that aquifers with greater depth are considered to be interesting sinks for CO2 storage because they are safer and the geothermal energy can be also utilized alongside the CCS [22,23,24]. One of the main objectives of this study is to determine the CO2 storage efficiency that is known to be dependent on different factors which can be categorised as: 1) Characteristics of the target aquifer for storage such as porosity, permeability, temperature, pressure, etc; 2) Characteristics of CO2 storage operation such as injection rate, number of wells, etc; 3) Constraints used in the injection process, such as maximum bottom hole pressure and the definitions used to calculate the volume of rock which is considered for CO2 storage [25].…”

Section: Model Descriptionmentioning

confidence: 99%

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Investigating the Impact of Aquifer Parameters on Carbon Dioxide Dissolution in Saline Aquifers

Abbaszadeh¹,

Shariatipour²

2018

Preprint

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CO2 injection into geological formations is considered one way of mitigating the increasing levels of carbon dioxide concentrations in the atmosphere and its effect on and global warming. In regard to sequestering carbon underground, different countries have conducted projects at commercial scale or pilot scale and some have plans to develop potential formations for carbon dioxide storage. In this study, pure CO2 injection is examined on a model with the properties of bunter sandstone and then sensitivity analyses were conducted for some of the important parameters. The results of this study show that the extent to which CO2 has been convected in the porous media in the reservoir plays a vital role in improving the CO2 dissolution in brine and safety of its long term storage. We conclude that heterogeneity plays a crucial role on the saturation distribution and can increase or decrease the amount of dissolved CO2 in water. Furthermore, the value of absolute permeability controls the effect of the Kv/Kh ratio on the CO2 dissolution in brine. In other words, as the value of vertical and horizontal permeability decreases (i.e. tight reservoirs) the impact of Kv/Kh ratio on the dissolved CO2 in brine becomes more prominent. Additionally, reservoir engineering parameters, such as well location, injection rate and scenarios, also have a high impact on the amount of dissolved CO2.

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Section: Resultscontrasting

confidence: 93%

Section: Model Descriptionmentioning

confidence: 99%

Investigating the Impact of Aquifer Parameters on Carbon Dioxide Dissolution in Saline Aquifers

Abbaszadeh¹,

Shariatipour²

2018

Preprint

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“…The MMG, which overlies potential CO2 storage formations such as the Sherwood Sandstone Group and its North Sea equivalent, the Bunter Sandstone Formation (Noy et al, 2012;Williams et al, 2018), equally serves as a good example here. At the reservoir/seal interface, transitional lithologies commonly exist between the Sherwood Sandstone and the Mercia Mudstone (Newell and Shariatipour, 2016;Seedhouse and Racey, 1997;Shariatipour et al, 2016b). This lithology is characterised by interbedded claystone, siltstones and medium-to fine-grained sandstones of approximately equal proportions (Hobbs et al, 2002).…”

Section: 3mentioning

confidence: 99%

Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Onoja

Williams

Vosper

et al. 2019

International Journal of Greenhouse Gas Control

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Numerical models of geologic carbon sequestration (GCS) in saline aquifers use multiphase fluid flow-characteristic curves (relative permeability and capillary pressure) to represent the interactions of the non-wetting CO2 and the wetting brine. Relative permeability data for many sedimentary formations is very scarce, resulting in the utilisation of mathematical correlations to generate the fluid flow characteristics in these formations. The flow models are essential for the prediction of CO2 storage capacity and trapping mechanisms in the geological media. The observation of pressure dissipation across the storage and sealing formations is relevant for storage capacity and geomechanical analysis during CO2 injection. This paper evaluates the relevance of representing relative permeability variations in the sealing formation when modelling geological CO2 sequestration processes. Here we concentrate on gradational changes in the lower part of the caprock, particularly how they affect pressure evolution within the entire sealing formation when duly represented by relative permeability functions. The results demonstrate the importance of accounting for pore size variations in the mathematical model adopted to generate the characteristic curves for GCS analysis. Gradational changes at the base of the caprock influence the magnitude of pressure that propagates vertically into the caprock from the aquifer, especially at the critical zone (i.e. the region overlying the CO2 plume accumulating at the reservoir-seal interface). A higher degree of overpressure and CO2 storage capacity was observed at the base of caprocks that showed gradation. These results illustrate the need to obtain reliable relative permeability functions for GCS, beyond just permeability and porosity data. The study provides a formative principle for geomechanical simulations that study the possibility of pressure-induced caprock failure during CO2 sequestration.

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“…Aquifer permeability and formation dip were shown to be the main parameters affecting the storage efficiency 57 . Later in another study, 58 the effect of tilt, rugosity and permeability anisotropy on CO 2 storage migration and trapping in a saline aquifer was investigated. The effect of the domain between the aquifer and the caprock (transition zone) on the CO 2 dissolution and movement was considered in the study.…”

Section: Introductionmentioning

confidence: 99%

Analysing the role of caprock morphology on history matching of Sleipner CO₂ plume using an optimisation method

Ahmadinia

Shariatipour

2020

Greenhouse Gases

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Geological carbon storage is a promising solution to reduce the CO2 concentration in the atmosphere to ameliorate the effects of global warming from the greenhouse effect. Among feasible storage options, deep saline aquifers are believed to have the largest storage capacity for the gas collected from industrial processes. The first CO2 storage project at a commercial scale in a saline aquifer is in the Sleipner field of the Utsira storage formation in Norway. The long ongoing storage operation in the Sleipner field has been the subject of several past studies attempting to recreate the observed injected CO2 plume migration behaviour. History matching is a method to adjust the input parameters of the model in a way to minimise the mismatch between the simulated and the actual production data in reservoir engineering and applicable to carbon sequestration. Typical parameters adjusted in history matching are porosity, absolute and relative permeability data. In this study, we used an adjoint‐based optimisation tool and showed the importance of caprock morphology in finding an accurate plume match. Using a set of synthetic models, we initially minimised the mismatch between the observed and simulated CO2 plume outline by modifying the caprock topographical details. After testing the optimisation tool on the synthetic models, we applied the methodology to the Sleipner benchmark 2019 model and improved the plume match by locally adjusting caprock elevation within seismic detection limits. We subsequently improved the match by calibrating porosity, permeability, CO2 density and injection rate together in an experiment in which we calibrated all the parameters, including the caprock morphology, to find a better match. The results showed an improvement of around 8% (compared with the original model) in the plume match resulting from an average absolute elevation change of 3.23 m in the model while keeping the other parameters constant. Calibrating the porosity, permeability, CO2 density and injection rate resulted in a 5% improvement in the match, and once caprock morphology was included in the optimisation process, the match improvement increased by 16%. We changed the caprock elevation within a range lower than the seismic detection limit, and results showed that even a few metres variations in the elevation have significant impacts on the plume migration and trapping mechanism in the Sleipner model. The method presented in this work results in a better match than the original seismic data for the Sleipner model. © 2020 The Authors. Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons, Ltd.

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Simulations of CO 2 storage in aquifer models with top surface morphology and transition zones

Cited by 26 publications

References 27 publications

Investigating the Impact of Aquifer Parameters on Carbon Dioxide Dissolution in Saline Aquifers

Investigating the Impact of Aquifer Parameters on Carbon Dioxide Dissolution in Saline Aquifers

Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Analysing the role of caprock morphology on history matching of Sleipner CO₂ plume using an optimisation method

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Simulations of CO 2 storage in aquifer models with top surface morphology and transition zones

Cited by 26 publications

References 27 publications

Investigating the Impact of Aquifer Parameters on Carbon Dioxide Dissolution in Saline Aquifers

Investigating the Impact of Aquifer Parameters on Carbon Dioxide Dissolution in Saline Aquifers

Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Analysing the role of caprock morphology on history matching of Sleipner CO2 plume using an optimisation method

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Analysing the role of caprock morphology on history matching of Sleipner CO₂ plume using an optimisation method