CO2/water interfacial tensions under pressure and temperature conditions of CO2 geological storage

Chiquet, Pierre; Daridon, Jean-Luc; Broseta, Daniel; Thibeau, Sylvain

doi:10.1016/j.enconman.2006.09.011

Cited by 362 publications

(376 citation statements)

References 21 publications

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“…(a) Symbols: this work , T = 293 K; , T = 298 K; , T = 308 K; , T = 323 K; , T = 343 K; , T = 373 K; , T = 398 K; , T = 423 K; , T = 448 K. Curves: ρaq predicted using the EOS of Spycher et al [16], [18] (for saturated phase composition) in place of the Duan et al [14] at the experimental conditions studied in this work. (b) Symbols: , this work; , Chiquet et al [9]; , Yan et al [36]; , Hebach et al [7]; ,Tabasinejad et al [10]; , Yaginuma et al [11]. Curves: ρaq predicted (entirely) with the EOS-CG of Span and co-workers [32] at the experimental conditions studied in this work.…”

Section: Aqueous Phase Of Co2 + H2omentioning

confidence: 99%

Saturated phase densities of (CO 2 + H 2 O) at temperatures from (293 to 450) K and pressures up to 64 MPa

Efika

Hoballah

et al. 2016

The Journal of Chemical Thermodynamics

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An apparatus consisting of an equilibrium cell connected to two vibrating tube densimeters and two syringe pumps was used to measure the saturated phase densities of CO2 + H2O at temperatures from (293 to 450) K and pressures up to 64 MPa, with estimated average standard uncertainties of 1.5 kg·m -3 for the CO2-rich phase and 1.0 kg·m -3 for the aqueous phase. The densimeters were housed in the same thermostat as the equilibrium cell and were calibrated in-situ using pure water, CO2 and helium. Following mixing, samples of each saturated phase were displaced sequentially at constant pressure from the equilibrium cell into the vibrating tube densimeters connected to the top (CO2-rich phase) and bottom (aqueous phase) of the cell. The aqueous phase densities are predicted to within 3 kg·m -3 using empirical models for the phase compositions and partial molar volumes of each . The density of the CO2-rich phase was always within about 8 kg·m -3 of the density for pure CO2 at the same pressure and temperature; the differences were most positive near the critical density, and became negative at temperatures above about 373 K and pressures below about 10 MPa. For this phase, the multi-parameter EOS of Gernert and Span describes the measured densities to within 5 kg·m -3, whereas the computationally-efficient cubic EOS model of Spycher and Pruess [Transport in Porous Media 2010, 82, 173-196], commonly used in simulations of subsurface CO2 sequestration, deviates from the experimental data by a maximum of about 3 kg·m -3.

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Section: Aqueous Phase Of Co2 + H2omentioning

confidence: 99%

Saturated phase densities of (CO 2 + H 2 O) at temperatures from (293 to 450) K and pressures up to 64 MPa

Efika

Hoballah

et al. 2016

The Journal of Chemical Thermodynamics

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“…A key aspect of the behavior of the flow system is two-phase flow of water-CO 2 mixtures in both fractures and matrix rock, driven by externally imposed pressure gradients, as well as by gradients of capillary pressure that evolve in response to increasing gas saturations from CO 2 injection. Information on interfacial tension and capillary pressures between CO 2 and water is available (Bachu and Bennion 2008;Chiquet et al 2007). For the simulations performed here, we base the strength coefficient P 0 of capillary pressure (Table 4) on a CO 2 -water interfacial tension of γ = 0.028 N/m, as measured for T = 50 • C, P = 200 bar (Chiquet et al 2007).…”

Section: Modeling Approachmentioning

confidence: 99%

“…Information on interfacial tension and capillary pressures between CO 2 and water is available (Bachu and Bennion 2008;Chiquet et al 2007). For the simulations performed here, we base the strength coefficient P 0 of capillary pressure (Table 4) on a CO 2 -water interfacial tension of γ = 0.028 N/m, as measured for T = 50 • C, P = 200 bar (Chiquet et al 2007). Due to continuous injection of dry CO 2 , parts of the flow system dry out, necessitating a consistent treatment of capillary pressure for liquid water as liquid saturation S l −→ 0.…”

Section: Modeling Approachmentioning

confidence: 99%

A Phase-Partitioning Model for CO2–Brine Mixtures at Elevated Temperatures and Pressures: Application to CO2-Enhanced Geothermal Systems

2009

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Correlations are presented to compute the mutual solubilities of CO 2 and chloride brines at temperatures 12-300 • C, pressures 1-600 bar (0.1-60 MPa), and salinities 0-6 m NaCl. The formulation is computationally efficient and primarily intended for numerical simulations of CO 2 -water flow in carbon sequestration and geothermal studies. The phase-partitioning model relies on experimental data from literature for phase partitioning between CO 2 and NaCl brines, and extends the previously published correlations to higher temperatures. The model relies on activity coefficients for the H 2 O-rich (aqueous) phase and fugacity coefficients for the CO 2 -rich phase. Activity coefficients are treated using a Margules expression for CO 2 in pure water, and a Pitzer expression for salting-out effects. Fugacity coefficients are computed using a modified Redlich-Kwong equation of state and mixing rules that incorporate asymmetric binary interaction parameters. Parameters for the calculation of activity and fugacity coefficients were fitted to published solubility data over the P-T range of interest. In doing so, mutual solubilities and gas-phase volumetric data are typically reproduced within the scatter of the available data. An example of multiphase flow simulation implementing the mutual solubility model is presented for the case of a hypothetical, enhanced geothermal system where CO 2 is used as the heat extraction fluid. In this simulation, dry supercritical CO 2 at 20 • C is injected into a 200 • C hot-water reservoir. Results show that the injected CO 2 displaces the formation water relatively quickly, but that the produced CO 2 contains significant water for long periods of time. The amount of water in the CO 2 could have implications for reactivity with reservoir rocks and engineered materials.

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“…In order to measure the interfacial properties of the mixtures as those considered in this work, by far the most common technique is the use of pendant drop tensiometry [9,10,11,12,13,14,15,16,17,18,19,20,21]. On the other hand, theoretical descriptions of these mixtures have been made by employing Density Functional Theory (DFT) [13,14,22], Density Gradient Theory (DGT) or Square Gradient Theory (SGT) [23,24,25,26,27,28,29,30,31,32,33,34,35,36,37,38].…”

Section: Introductionmentioning

confidence: 99%

High-pressure densities and interfacial tensions of binary systems containing carbon dioxide+n-alkanes: (n-Dodecane, n-tridecane, n-tetradecane)

Cumicheo

Cartes

Segura

et al. 2014

Fluid Phase Equilibria

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CO2/water interfacial tensions under pressure and temperature conditions of CO2 geological storage

Cited by 362 publications

References 21 publications

Saturated phase densities of (CO 2 + H 2 O) at temperatures from (293 to 450) K and pressures up to 64 MPa

Saturated phase densities of (CO 2 + H 2 O) at temperatures from (293 to 450) K and pressures up to 64 MPa

A Phase-Partitioning Model for CO2–Brine Mixtures at Elevated Temperatures and Pressures: Application to CO2-Enhanced Geothermal Systems

High-pressure densities and interfacial tensions of binary systems containing carbon dioxide+n-alkanes: (n-Dodecane, n-tridecane, n-tetradecane)

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