Chromatographic partitioning of impurities (H2S) contained in a CO2 stream injected into a deep saline aquifer: Part 2. Effects of flow conditions

Bachu, Stefan; Pooladi‐Darvish, Mehran; Hong, Huifang

doi:10.1016/j.ijggc.2009.01.002

Cited by 28 publications

(22 citation statements)

References 13 publications

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“…These were not obtained from the study of Xu et al [2007] because injected H 2 S is in the aqueous phase. Compared to the previous 1-D model [e.g., Knauss et al, 2005;Xu et al, 2007;Bachu and Bennion, 2009;Bachu et al, 2009b], the current 2-D radial flow model allows us to study buoyancy forces that would tend to drive the gas mixture toward the top of the formation, to track transport and dissolution of CO 2 and H 2 S at the front of the gas plume, and to investigate variations of physical and chemical processes over a vertical cross section.…”

Section: Sandstone Formationmentioning

confidence: 99%

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Modeling of fate and transport of coinjection of H₂S with CO₂in deep saline formations

Zhang¹,

Xu²,

Li³

2011

J. Geophys. Res.

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[1] The geological storage of CO 2 in deep saline formations is increasingly seen as a viable strategy to reduce the release of greenhouse gases into the atmosphere. However, costs of capture and compression of CO 2 from industrial waste streams containing small quantities of sulfur and nitrogen compounds such as SO 2 , H 2 S, and N 2 are very expensive. Therefore, studies on the coinjection of CO 2 containing other acid gases from industrial emissions are very important. In this paper, numerical simulations were performed to study the coinjection of H 2 S with CO 2 in sandstone and carbonate formations. Results indicate that the preferential dissolution of H 2 S gas (compared with CO 2 gas) into formation water results in the delayed breakthrough of H 2 S gas. Coinjection of H 2 S results in the precipitation of pyrite through interactions between the dissolved H 2 S and Fe 2+ from the dissolution of Fe-bearing minerals. Additional injection of H 2 S reduces the capabilities for solubility and mineral trappings of CO 2 compared to the CO 2 -only case. In comparison to the sandstone (siliciclastic) formation, the carbonate formation is less favorable to the mineral sequestration of CO 2 . In sandstone and carbonate formations, the presence of Fe-bearing siliciclastic and/or carbonate is more favorable to the H 2 S mineral trapping.

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Section: Sandstone Formationmentioning

confidence: 99%

“…The success of these acid-gas injection projects in Canada and the United States [Bachu et al, 2009b] indicates that the coinjection of H 2 S and CO 2 in geological media is a mature and safe technology.…”

Section: Introductionmentioning

confidence: 99%

Modeling of fate and transport of coinjection of H₂S with CO₂in deep saline formations

Zhang¹,

Xu²,

Li³

2011

J. Geophys. Res.

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“…In the present study, the main fluid properties and model parameters (Table 1) are the same as in the simulations of Bachu et al [30]. The simulations of the partitioning behaviour of CO 2 with two or three kinds of impurities are carried out in the tube model filled with quartz representative of the Keg River Formation as that in the experiments of Bachu and Bennion [28].…”

Section: Physical Modelmentioning

confidence: 99%

“…The studies were motivated by a report from a gas plant operator in southern Alberta, Canada: after injecting the mixture of 98% CO 2 and 2% H 2 S into a depleted gas reservoir, pure CO 2 was observed to break through at the producing wells while the breakthrough of the CO 2 -H 2 S mixture was some time later [28,29]. Both experimental and numerical studies have been performed to study the partitioning behaviour of CO 2 and H 2 S in geological formations [28][29][30][31]. The laboratory experiments suggested that the solubility of the contained impurity compared to that of CO 2 played the most important role in the partitioning results of CO 2 and impurity [28,29].…”

Section: Introductionmentioning

confidence: 99%

“…The laboratory experiments suggested that the solubility of the contained impurity compared to that of CO 2 played the most important role in the partitioning results of CO 2 and impurity [28,29]. Numerical results implied that various flow parameters, such as relative permeability, dispersion, injected gas composition and flow direction, had influences on the breakthrough time of the gas phase and the separations between the breakthroughs of CO 2 and the co-injected impurity [29][30][31]. Numerical studies have also been carried out to investigate the migration behaviour of CO 2 -N 2 mixture in the aquifer storage.…”

Section: Introductionmentioning

confidence: 99%

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Numerical investigation of the partitioning phenomenon of carbon dioxide and multiple impurities in deep saline aquifers

Jiang

2017

Applied Energy

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Highlights• The partitioning behaviours of impure CO 2 in geological formations are investigated.• The effects of N 2 , CH 4 or the mixture of N 2 and CH 4 are generally similar.• Less soluble N 2 and CH 4 enhance gas breakthroughs and the partitioning.• More soluble species such as H 2 S dissolves preferentially in the formation brine. AbstractThe partitioning behaviours of CO 2 with three kinds of common impurities, i.e., N 2 , CH 4 and H 2 S, in the formation brine are investigated by numerical simulations. The results indicate that the effects of N 2 , CH 4 or the mixture of N 2 and CH 4 at the same concentrations are generally similar. The leading gas front is usually made up of less soluble impurities, such as N 2 , CH 4 or the mixture of N 2 and CH 4 , while more soluble species such as H 2 S has dissolved preferentially in the formation brine. The separations between different gas species increase as the gas displacement front migrates forwards and contacts more of the aqueous phase. Compared with the partitioning results of the 98% CO 2 and 2% H 2 S mixture, the results indicate that the inclusion of less soluble N 2 and/or CH 4 results in an earlier gas breakthrough and a longer delay between the breakthrough times of CO 2 and H 2 S. The early breakthrough of the gas phase is mainly because that the addition of N 2 and/or CH 4 lowers the viscosity of the gas phase, resulting in a higher gas velocity than that of the CO 2 -H 2 S mixture. Meanwhile, the mobility ratio is higher and the gas mixture contacts the formation brine over a larger area, giving rise to more efficient stripping of the more soluble gas species like H 2 S and thus larger separations. In the meantime, with the same total concentrations of impurities (12%), when 2% H 2 S is contained in the CO 2 streams, gas phase flows slower and thus the breakthrough time is later. Furthermore, the effects on the partitioning phenomenon are weaker with decreasing concentrations of N 2 and/or CH 4 (from 10% to 2%) with fixed concentrations of other impurity like H 2 S (2%). The migration distances and the separations between different gas species change linearly with time on the whole, as confirmed by a simulation in a longer model.

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Modeling the Potential Impacts of CO₂Sequestration on Shallow Groundwater

Zheng

Spycher

2018

Reactive Transport Modeling

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Chromatographic partitioning of impurities (H2S) contained in a CO2 stream injected into a deep saline aquifer: Part 2. Effects of flow conditions

Cited by 28 publications

References 13 publications

Modeling of fate and transport of coinjection of H₂S with CO₂in deep saline formations

Modeling of fate and transport of coinjection of H₂S with CO₂in deep saline formations

Numerical investigation of the partitioning phenomenon of carbon dioxide and multiple impurities in deep saline aquifers

Modeling the Potential Impacts of CO₂Sequestration on Shallow Groundwater

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Chromatographic partitioning of impurities (H2S) contained in a CO2 stream injected into a deep saline aquifer: Part 2. Effects of flow conditions

Cited by 28 publications

References 13 publications

Modeling of fate and transport of coinjection of H2S with CO2in deep saline formations

Modeling of fate and transport of coinjection of H2S with CO2in deep saline formations

Numerical investigation of the partitioning phenomenon of carbon dioxide and multiple impurities in deep saline aquifers

Modeling the Potential Impacts of CO2Sequestration on Shallow Groundwater

Contact Info

Product

Resources

About

Modeling of fate and transport of coinjection of H₂S with CO₂in deep saline formations

Modeling of fate and transport of coinjection of H₂S with CO₂in deep saline formations

Modeling the Potential Impacts of CO₂Sequestration on Shallow Groundwater