0
Research Papers: Petroleum Engineering

Correlations of Equilibrium Interfacial Tension Based on Mutual Solubility/Density: Extension to n-Alkane–Water and n-Alkane–CO2 Binary/Ternary Systems and Comparisons With the Parachor Model

[+] Author and Article Information
Zehua Chen

School of Petroleum Engineering,
China University of Petroleum (East China),
Qingdao, Shandong 266580, China;
Petroleum Systems Engineering,
Faculty of Engineering and Applied Science,
University of Regina,
Regina, SK, S4S 0A2, Canada
e-mail: chen240z@uregina.ca

Daoyong Yang

Petroleum Systems Engineering,
Faculty of Engineering and Applied Science,
University of Regina,
Regina, SK, S4S 0A2, Canada
e-mail: tony.yang@uregina.ca

1Corresponding author.

Contributed by the Petroleum Division of ASME for publication in the Journal of Energy Resources Technology. Manuscript received March 11, 2019; final manuscript received May 14, 2019; published online June 5, 2019. Assoc. Editor: Hameed Metghalchi.

J. Energy Resour. Technol 141(12), 122901 (Jun 05, 2019) (12 pages) Paper No: JERT-19-1143; doi: 10.1115/1.4043824 History: Received March 11, 2019; Accepted May 14, 2019

In this study, new and pragmatic interfacial tension (IFT) correlations for n-alkane–water and n-alkane–CO2 systems are developed based on the mutual solubility of the corresponding binary systems and/or density in a pressure range of 0.1–140.0 MPa and temperature range of 283.2–473.2 K. In addition to being more accurate (i.e., the absolute average relative deviation (AARD) is 1.96% for alkane–water systems, while the AARDs for alkane–CO2 systems are 8.52% and 25.40% in the IFT range of >5.0 mN/m and 0.1–5.0 mN/m, respectively) than either the existing correlations or the parachor model (the AARDs for alkane–CO2 systems are 12.78% and 35.15% in the IFT range of >5.0 mN/m and 0.1–5.0 mN/m, respectively), such correlations can be applied to the corresponding ternary systems for an accurate IFT prediction without any mixing rule. Both a higher mutual solubility and a lower density difference between two phases involved can lead to a lower IFT, while pressure and temperature exert effects on IFT mainly through regulating the mutual solubility/density. Without taking effects of mutual solubility into account, the widely used parachor model in chemical and petroleum engineering fails to predict the IFT for CO2/methane–water pair and n-alkane–water pairs, though it yields a rough estimate for the CO2–water and methane–water pair below the CO2 and methane critical pressures of 7.38 and 4.59 MPa, respectively. However, the parachor model at least considers the effects of solubility in the alkane-rich phase to make it much accurate for n-alkane–CO2 systems. For n-alkane–CO2 pairs, the correlations developed in this work are found to be much less sensitive to the liquid density than the parachor model, being more convenient for practical use. In addition, all the IFTs for the CO2–water pair, methane–water pair, and alkane–CO2 pair can be regressed as a function of density difference of a gas–liquid system with a high accuracy at pressures lower than the critical pressures of either CO2 or methane.

FIGURES IN THIS ARTICLE
<>
Copyright © 2019 by ASME
Your Session has timed out. Please sign back in to continue.

References

Yang, D., and Gu, Y., 2003, “Interfacial Phenomena of the Oil-Fluid-Rock Systems in Carbon Dioxide Flooding Reservoirs,” Recent Developments in Colloids & Interface Research, Vol. 1, S. G. Pandalai, ed., Transworld Research Network, Trivandrum, Kerala, India, pp. 115–127.
Yang, D., Tontiwachwuthikul, P., and Gu, Y., 2006, “Dynamic Interfacial Tension Method for Measuring the Gas Diffusion Coefficient and the Interface Mass Transfer Coefficient in a Liquid,” Ind. Eng. Chem. Res., 45(14), pp. 4999–5008. [CrossRef]
Yang, D., Song, C., Zhang, J., Zhang, G., Ji, Y., and Gao, J., 2015, “Performance Evaluation of Injectivity for Water-Alternating-CO2 Processes in Tight Oil Formations,” Fuel, 139, pp. 292–300. [CrossRef]
Alavian, S. A., and Whitson, C. H., 2011, “Numerical Modeling CO2 Injection in a Fractured Chalk Experiment,” J. Pet. Sci. Eng., 77(2), pp. 172–182. [CrossRef]
Li, H., Yang, D., and Tontiwachwuthikul, P., 2012, “Experimental and Theoretical Determination of Equilibrium Interfacial Tension for the Solvent(s)-CO2-Heavy Oil Systems,” Energy Fuels, 26(3), pp. 1776–1786. [CrossRef]
Meybodi, M. K., Daryasafar, A., and Karimi, M., 2016, “Determination of Hydrocarbon-Water Interfacial Tension Using a New Empirical Correlation,” Fluid Phase Equilib., 415, pp. 42–50. [CrossRef]
Shang, Q., Xia, S., Cui, G., Tang, B., and Ma, P., 2017, “Measurement and Correlation of the Interfacial Tension for Paraffin + CO2 and (CO2 + N2) Mixture Gas at Elevated Temperatures and Pressures,” Fluid Phase Equilib., 439, pp. 18–23. [CrossRef]
Chen, Z., and Yang, D., 2018, “Prediction of Equilibrium Interfacial Tension Between CO2 and Water Based on Mutual Solubility,” Ind. Eng. Chem. Res., 57(26), pp. 8740–8749. [CrossRef]
Fan, Z., Yang, D., Chai, D., and Li, X., 2018, “Estimation of Relative Permeability and Capillary Pressure for PUNQ-S3 Model Using a Modified Iterative Ensemble Smoother,” ASME J. Energy Resour. Technol., 141(2), p. 022901. [CrossRef]
Ding, Y., Zheng, S., Meng, X., and Yang, D., 2019, “Low Salinity Hot Water Injection with Addition of Nanoparticles for Enhancing Heavy Oil Recovery,” ASME J. Energy Resour. Technol., 141(7), p. 072904. [CrossRef]
McCaffery, F. G., 1972, “Measurement of Interfacial Tensions and Contact Angles at High Temperature and Pressure,” J. Can. Pet. Tech., 11(3), pp. 26–32. [CrossRef]
Yang, D., and Gu, Y., 2004, “Interfacial Interactions of Crude Oil-Brine-CO2 Systems Under Reservoir Conditions,” Presented at the SPE Annual Technical Conference and Exhibition, Houston, TX, Sept. 26–29, Paper No. SPE 90198-MS.
Yang, D., Tontiwachwuthikul, P., and Gu, Y., 2005, “Interfacial Tensions of the Crude Oil + Reservoir Brine + CO2 Systems at Pressures up to 31 MPa and Temperatures of 27 °C and 58 °C,” J. Chem. Eng. Data, 50(4), pp. 1242–1249. [CrossRef]
Yang, D., and Gu, Y., 2004, “Visualization of Interfacial Interactions of Crude Oil-CO2 Systems Under Reservoir Conditions,” Presented at the 14th SPE/DOE Symposium on Improved Oil Recovery, Tulsa, OK, Apr. 17–21, Paper No. SPE 89366-MS.
Yang, D., and Gu, Y., 2005, “Interfacial Interactions Between Crude Oil and CO2 under Reservoir Conditions,” Pet. Sci. Tech., 23(9), pp. 1099–1112. [CrossRef]
Yang, D., and Gu, Y., 2008, “Determination of Diffusion Coefficients and Interface Mass-Transfer Coefficients of the Crude Oil−CO2 System by Analysis of the Dynamic and Equilibrium Interfacial Tensions,” Ind. Eng. Chem. Res., 47(15), pp. 5447–5455. [CrossRef]
Jaeger, P. T., and Eggers, R., 2012, “Interfacial Properties at Elevated Pressures in Reservoir Systems Containing Compressed or Supercritical Carbon Dioxide,” J. Supercrit. Fluids, 66, pp. 88–85. [CrossRef]
Yang, D., Tontiwachwuthikul, P., and Gu, Y., 2005, “Interfacial Interactions Between Reservoir Brine and CO2 at High Pressures and Elevated Temperatures,” Energy Fuels, 19(1), pp. 216–223. [CrossRef]
Yang, D., Tontiwachwuthikul, P., and Gu, Y., 2005, “Interfacial Tension Phenomenon and Mass Transfer Process in the Reservoir Brine-CO2 System at High Pressures and Elevated Temperatures,” Presented at the International Green Energy Conference (IGEC-1), Waterloo, ON, June 12–16, Paper No. IGEC-1-090.
Longeron, D. G., 1980, “Influence of Very Low Interfacial Tensions on Relative Permeability,” SPE J., 20(5), pp. 391–401.
Asar, H., and Handy, L. L., 1988, “Influence of Interfacial Tension on Gas/Oil Relative Permeability in a Gas-Condensate System,” SPE Res. Eng., 3(1), pp. 257–264. [CrossRef]
Blunt, M. J., 2000, “An Empirical Model for Three-Phase Relative Permeability,” SPE J., 5(4), pp. 435–445. [CrossRef]
Karimaie, H., and Torsæter, O., 2010, “Low IFT Gas-Oil Gravity Drainage in Fractured Carbonate Porous Media,” J. Pet. Sci. Eng., 70(1–2), pp. 67–73. [CrossRef]
Chen, Z., Zhao, X., Wang, Z., and Fu, M., 2015, “A Comparative Study of Inorganic Alkaline/Polymer Flooding and Organic Alkaline/Polymer Flooding for Enhanced Heavy Oil Recovery,” Colloid Surf. A: Physicochem. Eng. Asp., 469, pp. 150–157. [CrossRef]
Chen, Z., and Zhao, X., 2015, “Enhancing Heavy-Oil Recovery by Using Middle Carbon Alcohol-Enhanced Waterflooding, Surfactant Flooding, and Foam Flooding,” Energy Fuels, 29(4), pp. 2153–2161. [CrossRef]
Haniff, M. S., and Pearce, A. J., 1990, “Measuring Interfacial Tensions in a Gas-Condensate System with a Laser-Light-Scattering Technique,” SPE Res. Eng., 5(4), pp. 589–594. [CrossRef]
Cumicheo, C., Cartes, M., Segura, H., Müller, E. A., and Mejía, A., 2014, “High-Pressure Densities and Interfacial Tensions of Binary Systems Containing Carbon Dioxide + n-Alkanes: (n-Dodecane, n-Tridecane, n-Tetradecane),” Fluid Phase Equilib., 380, pp. 390–392. [CrossRef]
Liang, X., Michelsen, M. L., and Kontogeorgis, G. M., 2016, “A Density Gradient Theory Based Method for Surface Tension Calculations,” Fluid Phase Equilib., 428, pp. 153–163. [CrossRef]
Mairhofer, J., and Gross, J., 2018, “Modeling Properties of the One-Dimensional Vapor-Liquid Interface: Application of Classical Density Functional and Density Gradient Theory,” Fluid Phase Equilib., 458, pp. 243–252. [CrossRef]
Almeida, B. S., and Telo da Gama, M. M., 1989, “Surface Tension of Simple Mixtures: Comparison Between Theory and Experiment,” J. Phys. Chem., 93(10), pp. 4132–4138. [CrossRef]
Pereira, L. M. C., Chapoy, A., Burgass, R., and Tohidi, B., 2016, “Measurement and Modelling of High Pressure Density and Interfacial Tension of (Gas + n-Alkane) Binary Mixtures,” J. Chem. Thermodyn., 97, pp. 55–69. [CrossRef]
Zuo, Y.-X., and Stenby, E. H., 1998, “Prediction of Interfacial Tensions of Reservoir Crude Oil and Gas Condensate Systems,” SPE J., 3(2), pp. 134–145. [CrossRef]
Ayatollahi, S., Hemmati-Sarapardeh, A., Roham, M., and Hajirezaie, S., 2016, “A Rigorous Approach for Determining Interfacial Tension and Minimum Miscibility Pressure in Paraffin-CO2 Systems: Application to Gas Injection Processes,” J. Taiwan Inst. Chem. Eng., 63, pp. 107–115. [CrossRef]
Hemmati-Sarapardeh, A., and Mohagheghian, E., 2017, “Modeling Interfacial Tension and Minimum Miscibility Pressure in Paraffin-Nitrogen Systems: Application to Gas Injection Processes,” Fuel, 205, pp. 80–89. [CrossRef]
Ameli, F., Hemmati-Sarapardeh, A., Schaffie, M., Husein, M. M., and Shamshirband, S., 2018, “Modeling Interfacial Tension in N2/n-Alkane Systems Using Corresponding State Theory: Application to Gas Injection Processes,” Fuel, 222, pp. 779–791. [CrossRef]
Liu, Y., Li, H., and Okuno, R., 2016, “Measurements and Modeling of Interfacial Tension for CO2/CH4/Brine Systems under Reservoir Conditions,” Ind. Eng. Chem. Res., 55(48), pp. 12358–12375. [CrossRef]
Sugden, S., 1921, “The Determination of Surface Tension From the Rise in Capillary Tubes,” J. Chem. Soc. Trans., 119, pp. 1483–1492. [CrossRef]
Weinaug, C. F., and Katz, D. L., 1943, “Surface Tension of Methane-Propane Mixtures,” Ind. Eng. Chem., 35(2), pp. 239–246. [CrossRef]
Huygens, R. J. M., Ronde, H., and Hagoort, J., 1996, “Interfacial Tension of Nitrogen/Volatile Oil Systems,” SPE J., 1(2), pp. 125–132. [CrossRef]
Danesh, A., 1998, “PVT and Phase Behaviour of Petroleum Reservoir Fluids,” Ph.D. dissertation, Herriot Watt University, Edinburgh, Scotland.
Firoozabadi, A., and Ramey, H. J., Jr. 1988, “Surface Tension of Water-Hydrocarbon Systems at Reservoir Conditions,” J. Can. Pet. Tech., 27(3), pp. 41–48. [CrossRef]
Bahramian, A., Danesh, A., Gozalpour, F., Tohidi, B., and Todd, A. C., 2007, “Vapor-liquid Interfacial Tension of Water and Hydrocarbon Mixture at High Pressure and High Temperature Conditions,” Fluid Phase Equilib., 252(1–2), pp. 66–73. [CrossRef]
Bahramian, A., 2009, “Mutual Solubility-Interfacial Tension Relationship in Aqueous Binary and Ternary Hydrocarbon Systems,” Fluid Phase Equilib., 285(1–2), pp. 24–29. [CrossRef]
Backes, H. M., Ma, J. J., Bender, E., and Maurer, G., 1990, “Interfacial Tensions in Binary and Ternary Liquid-Liquid Systems,” Chem. Eng. Sci., 45(1), pp. 275–286. [CrossRef]
Bennion, D. B., and Bachu, S., 2008, “A Correlation of the Interfacial Tension Between Supercritical Phase CO2 and Equilibrium Brines as a Function of Salinity, Temperature and Pressure,” Presented at the SPE Annual Technical Conference and Exhibition, Denver, CO, Sept. 21–24, Paper No. SPE 114479-MS.
Kashefi, K., 2012, “Measurement and Modelling of Interfacial Tension and Viscosity of Reservoir Fluids,” Ph.D. dissertation, Heriot-Watt University, Edinburgh, Scotland.
Chen, Z., and Yang, D., 2019, “Correlation/Estimation of Equilibrium Interfacial Tension for Methane/CO2-Water/Brine Systems Based on Mutual Solubility,” Fluid Phase Equilib., 483, pp. 197–208. [CrossRef]
Wiegand, G., and Franck, E. U., 1994, “Interfacial Tension Between Water and Non-Polar Fluids up to 473 K and 2800 bar,” Ber. Bunsenges. Phys. Chem., 98(6), pp. 809–817. [CrossRef]
Cai, B., Yang, J., and Guo, T., 1996, “Interfacial Tension of Hydrocarbon + Water/Brine Systems Under High Pressure,” J. Chem. Eng. Data, 41(3), pp. 493–496. [CrossRef]
Zeppieri, S., Rodríguez, J., and López de Ramos, A. L., 2001, “Interfacial Tension of Alkane + Water Systems,” J. Chem. Eng. Data, 46(5), pp. 1086–1088. [CrossRef]
Michaels, A. S., and Hauser, E. A., 1951, “Interfacial Tension at Elevated Pressure and Temperature. II,” J. Phys. Chem., 55(3), pp. 408–421. [CrossRef]
Harley, Y., and Jennings, J. R., 1967, “The Effect of Temperature and Pressure on the Interfacial Tension of Benzene-Water and Normal Decane-Water,” J. Colloid. Interf. Sci., 24(3), pp. 323–329. [CrossRef]
Gasem, K. A. M., Dickson, K. B., Dulcamara, P. B., Nagarajan, N., and Robinson, R. L., Jr. 1989, “Equilibrium Phase Compositions, Phase Densities, and Interfacial Tensions for CO2 + Hydrocarbon Systems. 5. CO2 + n-Tetradecane,” J. Chem. Eng. Data, 34(2), pp. 191–195. [CrossRef]
Georgiadis, A., Llovell, F., Bismarck, A., Blas, F. J., Galindo, A., Maitland, G. C., Trusler, J. P. M., and Jackson, G., 2010, “Interfacial Tension Measurements and Modelling of (Carbon Dioxide + n-Alkane) and (Carbon Dioxide + Water) Binary Mixtures at Elevated Pressures and Temperatures,” J. Supercrit. Fluids, 55(2), pp. 743–754. [CrossRef]
Hsu, J. J.-C., Nagarajan, N., and Robinson, R. L., Jr. 1985, “Equilibrium Phase Compositions, Phase Densities, and Interfacial Tensions for CO2 + Hydrocarbon Systems. 1. CO2 + n-Butane,” J. Chem. Eng. Data, 30(4), pp. 485–491. [CrossRef]
Jaeger, P. T., Alotaibi, M. B., and Nasr-El-Din, H. A., 2010, “Influence of Compressed Carbon Dioxide on the Capillarity of the Gas-Crude Oil-Reservoir Water System,” J. Chem. Eng. Data, 55(11), pp. 5246–5251. [CrossRef]
Li, N., Zhang, C., Ma, Q., Jiang, L., Xu, Y., Chen, G., Sun, C., and Yang, L., 2017, “Interfacial Tension Measurement and Calculation of (Carbon Dioxide + n-Alkane) Binary Mixtures,” J. Chem. Eng. Data, 62(9), pp. 2861–2871. [CrossRef]
Mejía, A., Cartes, M., Segura, H., and Müller, E. A., 2014, “Use of Equations of State and Coarse Grained Simulations to Complement Experiments: Describing the Interfacial Properties of Carbon Dioxide + Decane and Carbon Dioxide + Eicosane Mixtures,” J. Chem. Eng. Data, 59(10), pp. 2928–2941. [CrossRef]
Nagarajan, N., and Robinson, R. L., Jr. 1986, “Equilibrium Phase Compositions, Phase Densities, and Interfacial Tensions for CO2 + Hydrocarbon Systems. 2. CO2 + n-Decane,” J. Chem. Eng. Data, 31(2), pp. 168–171. [CrossRef]
Nagarajan, N., Gasem, K. A. M., and Robinson, R. L., Jr. 1990, “Equilibrium Phase Compositions, Phase Densities, and Interfacial Tensions for CO2 + Hydrocarbon Systems. 6. CO2 + n-Butane + n-Decane,” J. Chem. Eng. Data, 35(3), pp. 228–231. [CrossRef]
Yang, Z., Li, M., Peng, B., Lin, M., Dong, Z., and Ling, Y., 2014, “Interfacial Tension of CO2 and Organic Liquid Under High Pressure and Temperature,” Chinese J. Chem. Eng., 22(11–12), pp. 1302–1306. [CrossRef]
Zolghadr, A., Escrochi, M., and Ayatollahi, S., 2013, “Temperature and Composition Effect on CO2 Miscibility by Interfacial Tension Measurement,” J. Chem. Eng. Data, 58(5), pp. 1168–1175. [CrossRef]
Niño Amézquita, O. G., Endersa, S., Jaeger, P. T., and Eggers, R., 2010, “Interfacial Properties of Mixtures Containing Supercritical Gases,” J. Supercrit. Fluids, 55(2), pp. 724–734. [CrossRef]
Peng, D. Y., and Robinson, D. B., 1976, “A New-Constant Equation of State,” Ind. Eng. Chem. Fund., 15(1), pp. 59–64. [CrossRef]
Shi, Y., and Yang, D., 2016, “Quantification of a Single Gas Bubble Growth in Solvent(s)-CO2-Heavy Oil Systems with Consideration of Multicomponent Diffusion Under Non-Equilibrium Conditions,” ASME J. Energy Resour. Technol., 139(2), p. 022908. [CrossRef]
Shi, Y., and Yang, D., 2017, “Experimental and Theoretical Quantification of Nonequilibrium Phase Behaviour and Physical Properties of Foamy Oil Under Reservoir Conditions,” ASME J. Energy Resour. Technol., 139(6), p. 062902. [CrossRef]
Zheng, S., and Yang, D., 2016, “Experimental and Theoretical Determination of Diffusion Coefficients of CO2-Heavy Oil Systems by Coupling Heat and Mass Transfer,” J. Energy Resour. Technol., 139(2), p. 022901. [CrossRef]
Chen, Z., and Yang, D., 2017, “Optimization of the Reduced Temperature Associated with Peng-Robinson Equation of State and Soave-Redlich-Kwong Equation of State to Improve Vapor Pressure Prediction for Heavy Hydrocarbon Compounds,” J. Chem. Eng. Data, 62(10), pp. 3488–3500. [CrossRef]
Chen, Z., and Yang, D., 2018, “Determination of Mutual Solubility Between n-Alkanes/n-Alkylbenzenes and Water by Using Peng-Robinson Equation of State with Modified Alpha Functions and Generalized BIP Correlations,” Fluid Phase Equilib., 477, pp. 19–29. [CrossRef]
Chen, Z., and Yang, D., 2018, “Prediction of Phase Behaviour for n-Alkane-CO2-Water Systems with Consideration of Mutual Solubility Using Peng-Robinson Equation of State,” J. Supercrit. Fluids, 138, pp. 174–186. [CrossRef]
Chen, Z., and Yang, D., 2018, “Quantification of Phase Behaviour of Solvents-Heavy Oil Systems in the Presence of Water at High Pressures and Elevated Temperatures,” Fuel, 232, pp. 803–816. [CrossRef]
Li, X., and Yang, D., 2013, “Determination of Mutual Solubility Between CO2 and Water by Using the Peng-Robinson Equation of State with Modified Alpha Function and Binary Interaction Parameter,” Ind. Eng. Chem. Res., 52(38), pp. 13829–13838. [CrossRef]
Peng, D. Y., and Robinson, D. B., 1976, “Two and Three Phase Equilibrium Calculations for Systems Containing Water,” Can. J. Chem. Eng., 54(5), pp. 595–599. [CrossRef]
Søreide, I., and Whitson, C. H., 1992, “Peng-Robinson Predictions for Hydrocarbons, CO2, N2 and H2S with Pure Water and NaCl-Brines,” Fluid Phase Equilib., 77, pp. 217–240. [CrossRef]
Whitson, C. H., and Brule, M. R., 2000, Phase Behavior, Monograph Series, SPE, Richardson, TX.
Kordas, A., Tsoutsouras, K., Stamataki, S., and Tassios, D., 1994, “A Generalized Correlation for the Interaction Coefficients of CO2-Hydrocarbon Binary Mixtures,” Fluid Phase Equilib., 93, pp. 141–166. [CrossRef]
Twu, C. H., and Chan, H.-S., 2009, “Rigorously Universal Methodology of Volume Translation for Cubic Equations of State,” Ind. Eng. Chem. Res., 48(12), pp. 5901–5906. [CrossRef]
Peneloux, A., Rauzy, E., and Freze, R., 1982, “A Consistent Correction for Redlich-Kwong-Soave Volumes,” Fluid Phase Equilib., 8(1), pp. 7–23. [CrossRef]
Miqueu, C., Mendiboure, B., Graciaa, A., and Lachaise, J., 2003, “Modelling of the Surface Tension of Pure Components with the Gradient Theory of Fluid Interfaces: A Simple and Accurate Expression for the Influence Parameters,” Fluid Phase Equilib., 207(1–2), pp. 225–246. [CrossRef]
Chiquet, P., Daridon, J.-L., Broseta, D., and Thibeau, S., 2007, “CO2/Water Interfacial Tensions under Pressure and Temperature Conditions of CO2 Geological Storage,” Energy Convers. Manage., 48(3), pp. 736–744. [CrossRef]
Shaw, D., Maczynski, A., Goral, M., Wisniewska-Goclowska, B., Skrzecz, A., Owczarek, I., Blazej, K., Haulait-Pirson, M.-C., Hefter, G. T., Huyskens, P. L., Kapuku, F., Maczynska, Z., and Szafranski, A., 2006, “IUPAC-NIST Solubility Data Series. 81. Hydrocarbons with Water and Seawater-Revised and Updated. Part 9. C10 Hydrocarbons with Water,” J. Phys. Chem. Ref. Data, 35(1), pp. 93–151. [CrossRef]
Lemmon, E. W., McLinden, M. O., and Friend, D. G., 2012, “Thermophysical Properties of Fluid Systems,” NIST Chemistry WebBook, NIST Standard Reference Database Number 69, P. J. Linstrom, and W. G. Mallard, eds, National Institute of Standards and Technology, Gaithersburg, MD.
Quayle, O. R., 1953, “The Parachors of Organic Compounds. An Interpretation and Catalogue,” Chem. Rev., 53(3), pp. 439–589. [CrossRef]
Donahue, D. J., and Bartell, F. E., 1952, “The Boundary Tension at Water-Organic Liquid Interfaces,” J. Phys. Chem., 56(4), pp. 480–484. [CrossRef]
Sutton, R. P., 2009, “An Improved Model for Water-Hydrocarbon Surface Tension at Reservoir Conditions,” Presented at the SPE Annual Technical Conference and Exhibition, New Orleans, LA, Oct. 4–7, Paper No. SPE 124968-MS.
Kontogeorgis, G. M., Voutsas, E. C., and Yakoumis, I. V., 1996, “An Equation of State for Associating Fluids,” Ind. Eng. Chem. Res., 35(11), pp. 4310–4318. [CrossRef]
Bikkina, P. K., Shoham, O., and Uppaluri, R., 2011, “Equilibrated Interfacial Tension Data of the CO2-Water System at High Pressures and Moderate Temperatures,” J. Chem. Eng. Data, 56(10), pp. 3725–3733. [CrossRef]
Sachs, W., and Meyn, V., 1995, “Pressure and Temperature Dependence of the Surface Tension in the System Natural Gas/Water Principles of Investigation and the First Precise Experimental Data for Pure Methane/Water at 25 °C up to 46.8 MPa,” Colloid Surf. A: Physicochem. Eng. Asp., 94(2–3), pp. 291–301. [CrossRef]
Kato, K., Nagahama, K., and Hirata, M., 1981, “Generalized Interaction Parameters for the Peng-Robinson Equation of State: Carbon Dioxide-n-Paraffin Binary Systems,” Fluid Phase Equilib., 7(3–4), pp. 219–231. [CrossRef]
Vitu, S., Privat, R., Jaubert, J.-N., and Mutelet, F., 2008, “Predicting the Phase Equilibria of CO2 + Hydrocarbon Systems with the PPR78 Model (PR EOS and kij Calculated Through a Group Contribution Method),” J. Supercrit. Fluid, 45(1), pp. 1–26. [CrossRef]
Li, X., Yang, D., Zhang, X., Zhang, G., and Gao, J., 2016, “Binary Interaction Parameters of CO2-Heavy-n-Alkanes Systems by Using Peng-Robinson Equation of State with Modified Alpha Function,” Fluid Phase Equilib., 417, pp. 77–86. [CrossRef]

Figures

Grahic Jump Location
Fig. 1

Measured (275 measured IFTs for binary mixtures in Table 1) and correlated IFTs for n-alkane–water pairs with the correlation developed in this work and other existing correlations, respectively

Grahic Jump Location
Fig. 2

(a) Measured [48] and predicted IFTs for n-hexane–water pair with the correlation developed in this work and (b) predicted mutual solubility under corresponding conditions

Grahic Jump Location
Fig. 3

AARDs of the predicted IFTs for n-alkane–water pairs with a variation of solubility ratio. (All the measured IFTs for binary mixtures in Table 1 are used for calculation. The solubility ratio denotes the ratio of any solubility for the sensitivity analysis to that calculated with the PR EOS.)

Grahic Jump Location
Fig. 4

Variation of IFT for the n-tetradecane-CO2 pair and molar fraction ratios with a pressure at 353.2 K, while the measured data are taken from Li et al. [57]

Grahic Jump Location
Fig. 5

(a) Measured [87] and predicted IFTs for CO2–water pair with Eqs. (1a) and (1b) and the parachor model, (b) measured [88] and predicted IFTs for methane–water pair with Eq. (1c) and the parachor model, (c) four terms in the parachor model for CO2–water systems at 313 K, and (d) mutual solubility and molecular weights of CO2–water systems at 313 K

Grahic Jump Location
Fig. 6

(a) Measured [41] and predicted IFTs for n-decane–water pair with the correlation developed in this work and the parachor model, respectively, (b) four terms in the parachor model at 373.2 K, and (c) mutual solubility and molecular weights at 373.2 K

Grahic Jump Location
Fig. 7

(a) Four terms in the parachor model for n-tridencane–CO2 pair at 353.2 K and (b) mutual solubility and molecular weights under corresponding conditions

Grahic Jump Location
Fig. 8

AARDs of the predicted IFTs between n-decane/n-heptadecane and CO2 with a variation of solubility ratio using (a) the parachor model and (b) the correlations developed in this work, i.e., Eqs. (14a) and (14b). Measured IFTs are taken from Shang et al. [7] and Nagarajan and Robinson [59]. The solubility ratio denotes the ratio of the solubility for the sensitivity analysis to that calculated with PR EOS.

Grahic Jump Location
Fig. 9

(a) AARDs for the predicted IFTs (with the parachor model) between n-decane/n-heptadecane and CO2 with liquid density and (b) AARDs for the predicted IFTs (with the correlations developed in this work, i.e., Eqs. (14a) and (14b)) between n-decane/n-heptadecane and CO2 with liquid density. Measured IFTs are taken from Shang et al. [7] and Nagarajan and Robinson [59].

Tables

Errata

Some tools below are only available to our subscribers or users with an online account.

Related Content

Customize your page view by dragging and repositioning the boxes below.

Related Journal Articles
Related eBook Content
Topic Collections

Sorry! You do not have access to this content. For assistance or to subscribe, please contact us:

  • TELEPHONE: 1-800-843-2763 (Toll-free in the USA)
  • EMAIL: asmedigitalcollection@asme.org
Sign In