CO2-H2O mixtures in the geological sequestration of CO2. II. Partitioning in chloride brines at 12–100°C and up to 600 bar

Spycher, Nicolas; Pruess, Karsten

doi:10.1016/j.gca.2005.01.015

Cited by 484 publications

(356 citation statements)

References 36 publications

Supporting

Mentioning

349

Contrasting

Order By: Relevance

“…The solubility of benzene and CO 2 in water (or brine), on the other hand, is treated with pressure and temperature-dependent equilibrium constants (similar to Henry's coefficients) that rely on experimental data. For CO 2 , aqueous solubilities rely on the solubility model of Spycher and Pruess (2005) (see Appendix A, Section A.1). For benzene, aqueous solubilities are derived using various published data as described in Appendix A, Sections A.2 and A.3.…”

Section: Partitioning Of Benzene Between Co 2 and Watermentioning

confidence: 99%

“…The SoaveRedlich-Kwong option of GASEOS was used, with binary interaction parameters for H 2 S and CO 2 from Walas (1985). The solubility of these gases in water are computed using equilibrium constants (i.e., Henry's law at infinite dilution) and activity coefficients using data from Spycher and Pruess (2005) …”

Section: Calculating the Phase Behavior Of The H 2 S + Co 2 + H 2 O Smentioning

confidence: 99%

“…ECO2N implements the mutual H 2 O-CO 2 solubility model of Spycher et al (2003) and Spycher and Pruess (2005), which was thoroughly tested against a large number of experimental data. To ensure correct implementation of the ECO2N solubility routines into TMVOC_REACT, published CO 2 solubilities in water at two temperatures were compared with values calculated by TMVOC_REACT.…”

Section: Appendix a A1 Solubility Of Co 2 In Water And Brinementioning

confidence: 99%

See 2 more Smart Citations

Modeling Studies on the Transport of Benzene and H2S in CO2-Water Systems

Zheng¹,

Spycher²,

Xu³

et al. 2010

View full text Add to dashboard Cite

Section: Partitioning Of Benzene Between Co 2 and Watermentioning

confidence: 99%

Section: Calculating the Phase Behavior Of The H 2 S + Co 2 + H 2 O Smentioning

confidence: 99%

Section: Appendix a A1 Solubility Of Co 2 In Water And Brinementioning

confidence: 99%

See 1 more Smart Citation

Modeling Studies on the Transport of Benzene and H2S in CO2-Water Systems

Zheng¹,

Spycher²,

Xu³

et al. 2010

View full text Add to dashboard Cite

“…is the phase change term (i.e., CO 2 dissolution into water and water evaporation into CO 2 ) (Spycher and Pruess, 2005) and  is either CO 2 -rich phase, c , or aqueous phase, w .…”

Section: Thermo-hydro-mechanical Mathematical Modelmentioning

confidence: 99%

Long-term thermal effects on injectivity evolution during CO2 storage

Vilarrasa

Rinaldi

Rutqvist

2017

International Journal of Greenhouse Gas Control

View full text Add to dashboard Cite

Carbon dioxide (CO 2 ) is likely to reach the bottom of injection wells at a colder temperature than that of the storage formation, causing cooling of the rock. This cooling, together with overpressure, tends to open up fractures, which may enhance injectivity. We investigate cooling effects on injectivity enhancement by modeling the In Salah CO 2 storage site and a theoretical, long-term injection case. We use stress-dependent permeability functions that predict an increase in permeability as the effective stress acting normal to fractures decreases. Normal effective stress can decrease either due to overpressure or cooling. We calibrate our In Salah model, which includes a fracture zone perpendicular to the well, obtaining a good fitting with the injection pressure measured at KB-502 and the rapid CO 2 breakthrough that occurred at the observation well KB-5 located 2 km away from the injection well. CO 2 preferentially advances through the fracture zone, which becomes two orders of magnitude more permeable than the rest of the reservoir. Nevertheless, the effect of cooling on the long-term injectivity enhancement is limited in pressure dominated storage sites, like at In Salah, because most of the permeability enhancement is due to overpressure. However, thermal effects enhance injectivity in cooling dominated storage sites, which may decrease the injection pressure by 20 %, saving a significant amount of compression energy all over the duration of storage projects. Overall, our simulation results show that cooling has the potential to enhance injectivity in fractured reservoirs.

show abstract

“…Equilibrium constants used for aqueous-aqueous and aqueous-mineral reactions in three examples are taken from Wolery (1992). A new fluid property module, ECO2N, based on work of Spycher and Pruess (2005) was used. This module provides an accurate description of the thermophysical properties of mixtures of water and CO 2 under conditions typically encountered in saline aquifers of interest for CO 2 sequestration (31°C  T  110°C; 73.8 bars < P  600 bars).…”

Section: Introductionmentioning

confidence: 99%

Reactive transport modeling for CO2 geological sequestration

Zheng

Tian

2011

Journal of Petroleum Science and Engineering

View full text Add to dashboard Cite

Abstract. One way to reduce carbon dioxide (CO 2 ) releases to the atmosphere, is to capture it from power plants and then inject it into deep geological formations.Understanding water-gas-mineral reactions is the core of assessing the long term storage and risks in geological sequestration. Because of various limitations of laboratory and field tests, reactive transport modeling has been one important supplementary or independent tool to study the water-gas-mineral reactions at different components of geological sequestration. In this paper, we reviewed the applications of reactive transport modeling to three aspects of CO 2 geological sequestration: the behavior of CO 2 in storage formation, the storage security issues related to caprock integrity or wellbore cement degradation, and the change of the shallow groundwater in response to the potential leakage of CO 2 . Key finding are summarized and further research needs are identified. The lack of the detailed mineralogical composition information at the storage formation, caprock and overlying aquifers is currently the first obstacle for quantitative prediction of geochemical evolution. The thermodynamic properties of relevant minerals under high temperature and pressure have to be refined. Reliable reaction rates of minerals dissolution/precipitation at field are still the bottle neck of the calculating the long term mineral trapping of CO 2 . Issues related to relatively fast reactions such sorption and ion exchange need special attention when the impact of CO 2 leakage on shallow groundwater was evaluated. The role of organic compounds in water-gas-mineral reactions needs further study.2

show abstract

CO2-H2O mixtures in the geological sequestration of CO2. II. Partitioning in chloride brines at 12–100°C and up to 600 bar

Cited by 484 publications

References 36 publications

Modeling Studies on the Transport of Benzene and H2S in CO2-Water Systems

Modeling Studies on the Transport of Benzene and H2S in CO2-Water Systems

Long-term thermal effects on injectivity evolution during CO2 storage

Reactive transport modeling for CO2 geological sequestration

Contact Info

Product

Resources

About