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A simulation study of the effect of trapping model, geological heterogeneity and injection strategies on CO2 trapping
Uppsala University, Disciplinary Domain of Science and Technology, Earth Sciences, Department of Earth Sciences, LUVAL.
Uppsala University, Disciplinary Domain of Science and Technology, Earth Sciences, Department of Earth Sciences, LUVAL.
Uppsala University, Disciplinary Domain of Science and Technology, Earth Sciences, Department of Earth Sciences, LUVAL. Univ Calif Berkeley, Lawrence Berkeley Natl Lab, Energy Geosci Div, 1 Cyclotron Rd, Berkeley, CA 94720 USA..
Uppsala University, Disciplinary Domain of Science and Technology, Earth Sciences, Department of Earth Sciences, LUVAL.
2016 (English)In: International Journal of Greenhouse Gas Control, ISSN 1750-5836, E-ISSN 1878-0148, Vol. 52, 52-72 p.Article in journal (Refereed) Published
Abstract [en]

Industrial CO2 emissions to the atmosphere can be reduced through geological storage, where the gas is injected into the subsurface and trapped by several mechanisms. Residual and solubility trapping are two important processes providing trapping, and their effectiveness ultimately determines the feasibility of geological storage. By means of numerical modeling, a systematic analysis was made concerning the factors potentially affecting trapping, to guide the planned injection experiments at the Heletz test injection site. The effect of enhanced-trapping injection strategies along with the role of geological heterogeneity and the choice of trapping model (TM) were evaluated. The results showed that adding chase-fluid stages to a conventional CO2 injection enhanced the trapping. Taking into account the geological heterogeneity decreased trapping, as this retarded the buoyant migration, resulting in less imbibition and residual trapping. The choice of TM was significant, with the simplified Land TM producing the highest trapping, and the Aissaoui TM the lowest. The results stress the importance of using an appropriate TM as well as heterogeneity model for the site in question for any predictive modeling of CO2 sequestration, as different assumptions may lead to significant discrepancies in the predicted trapping.

Place, publisher, year, edition, pages
2016. Vol. 52, 52-72 p.
Keyword [en]
CCS, Capillary trapping, Hysteresis, Injection strategies, Residual trapping, Solubility trapping
National Category
Earth and Related Environmental Sciences
Identifiers
URN: urn:nbn:se:uu:diva-303260DOI: 10.1016/j.ijggc.2016.06.020ISI: 000381728300006OAI: oai:DiVA.org:uu-303260DiVA: diva2:971497
Funder
EU, FP7, Seventh Framework Programme, 227286; 309067
Available from: 2016-09-16 Created: 2016-09-15 Last updated: 2017-08-15Bibliographically approved
In thesis
1. Modeling of geohydrological processes in geological CO2 storage – with focus on residual trapping
Open this publication in new window or tab >>Modeling of geohydrological processes in geological CO2 storage – with focus on residual trapping
2017 (English)Doctoral thesis, comprehensive summary (Other academic)
Abstract [en]

Geological storage of carbon dioxide (CO2) in deep saline aquifers is one approach to mitigate release from large point sources to the atmosphere. Understanding of in-situ processes providing trapping is important to the development of realistic models and the planning of future storage projects. This thesis covers both field- and pore-scale numerical modeling studies of such geohydrological processes, with focus on residual trapping. The setting is a CO2-injection experiment at the Heletz test site, conducted within the frame of the EU FP7 MUSTANG and TRUST projects.

The objectives of the thesis are to develop and analyze alternative experimental characterization test sequences for determining in-situ residual CO2 saturation (Sgr), as well as to analyze the impact of the injection strategy on trapping, the effect of model assumptions (coupled wellbore-reservoir flow, geological heterogeneity, trapping model) on the predicted trapping, and to develop a pore-network model (PNM) for simulating and analyzing pore-scale mechanisms.

The results include a comparison of alternative characterization test sequences for estimating Sgr. The estimates were retrieved through parameter estimation. The effect on the estimate of including various data sets was determined. A new method, using withdrawal and an indicator-tracer, for obtaining a residual zone in-situ was also introduced.

Simulations were made of the CO2 partitioning between layers in a multi-layered formation, and parameters influencing this were identified. The results showed the importance of accounting for coupled wellbore-reservoir flow in simulations of such scenarios.

Simulations also showed that adding chase-fluid stages after a conventional CO2 injection enhances the (residual and dissolution) trapping. Including geological heterogeneity generally decreased the estimated trapping. The choice of trapping model may largely effect the quantity of the predicted residual trapping (although most of them produced similar results). The use of an appropriate trapping model and description of geological heterogeneity for a site when simulating CO2 sequestration is vital, as different assumptions may give significant discrepancies in predicted trapping.

The result also includes a PNM code, for multiphase quasi-static flow and trapping in porous materials. It was used to investigate trapping and obtain an estimated trapping (IR) curve for Heletz sandstone.

Place, publisher, year, edition, pages
Uppsala: Acta Universitatis Upsaliensis, 2017. 96 p.
Series
Digital Comprehensive Summaries of Uppsala Dissertations from the Faculty of Science and Technology, ISSN 1651-6214 ; 1540
Keyword
capillary trapping, CCS, characterization test, CO2, injection design, pore-network model
National Category
Earth and Related Environmental Sciences
Research subject
Hydrology
Identifiers
urn:nbn:se:uu:diva-327994 (URN)978-91-513-0031-3 (ISBN)
Public defence
2017-09-29, Hambergsalen, Geocentrum, Villavägen 16, Uppsala, 10:00 (English)
Opponent
Supervisors
Available from: 2017-09-06 Created: 2017-08-15 Last updated: 2017-09-08

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