Carbon dioxide sequestration in saline formations: Part 2-Review of multiphase flow modeling

Journal of Petroleum Science and Engineering

Volumn 124, Issue , 2014, Pages 381-398

  Cinar, Yildiray ^a   Riaz, Amir ^b  

^a UNIVERSITY OF NEW SOUTH WALES   (Australia)

^b UNIVERSITY OF MARYLAND   (United States)

Author keywords

CO2 sequestration; Experimental studies; Fossil fuels; Greenhouse gas mitigation; Saline formations

Indexed keywords

DIGITAL STORAGE; FLOW CONTROL; FOSSIL FUELS; GREENHOUSE GASES; MULTIPHASE FLOW; UNCERTAINTY ANALYSIS;

CARBON DIOXIDE SEQUESTRATION; EXPERIMENTAL STUDIES; GREENHOUSE GAS MITIGATION; HYDRODYNAMIC INSTABILITIES; MULTI-PHASE FLOW MODELS; MULTI-PHASE FLOW PROPERTIES; RESERVOIR ENGINEERING; SALINE FORMATION;

CARBON DIOXIDE;

CARBON DIOXIDE; CARBON SEQUESTRATION; EXPERIMENTAL STUDY; FLOW MODELING; FOSSIL FUEL; GREENHOUSE GAS; HYDRODYNAMICS; IMMISCIBILITY; MULTIPHASE FLOW; PETROLEUM ENGINEERING; VISCOUS FLOW;

EID: 84918553307     PISSN: 09204105     EISSN: None     Source Type: Journal    
DOI: 10.1016/j.petrol.2014.07.023     Document Type: Review

References (164)

1. 2O-NaCl solutions from -22 to 100°C and from 0.1 to 100MPa. Fluid Phase Equilibria 2010, 295:104-124.
2. 2 in the presence of hydrocarbon surfactants. Fluid Phase Equilib 2007, 257:163-168.
3. 2 injection into saline aquifers. Transp. Porous Media 2010, 84:799-819.
4. 2 storage capacity-combining geology, engineering and economics. Soc. Pet. Eng. Econ. Manag. 2014, 6(1):15-27.
5. Anderson T.B., Jackson R. Fluid mechanical description of fluidized beds. Equations of motion. Ind. Eng. Chem. Fundam. 1967, 6(4):527-539.
6. Aryana S.A., Kovscek A.R. Experiments and analysis of drainage displacement processes relevant to carbon dioxide injection. Phys. Rev. E 2012, 86:066310.
7. Aryana S.A., Kovscek A.R. Nonequilibrium effects and multiphase flow in porous media. Transp. Porous Media 2013, 97(3):373-394.
8. Auriault J., Lewandowska J. On the cross-effects of coupled macroscopic transport-equations in porous-media. Transp. Porous Media 1994, 16(1):31-52.
9. 2 injection in saline aquifers. Energy Procedia 2013, 37:3275-3282.
10. 2 in solution. Energy Convers. Manag 2003, 44(20):3151-3175.
11. 2 in geological media in response to climate change. Environ. Geol. 2003, 44(3):277-289.
12. 2-brine interfacial tension on aquifer pressure, temperature and water salinity. Energy Procedia 2009, 1(1):3157-3164.
13. 2 sequestration capacity in alberta[U+05F3]s oil and gas reservoirs at depletion and the effect of underlying aquifers. J. Can. Pet. Technol. 2003, 42(9):11.
14. 2 at (30-60)°C and (10-20) MPa. J. Chem. Eng. Data 2004, 49:1328-1332.
15. Barenblatt G., Patzek T., Silin D. The mathematical model of nonequilibrium effects in water-oil displacement. Soc. Pet. Eng. J. 2003, 8(4):409-416.
16. Bear J. Dynamics of Fluids in Porous Media 1988, Dover Publications, Mineola, NY.
17. Belgodere, C., Sterpenich, J., Pironon, J., Jobard, E., Randi, A., Birat, J.-P., 2013. CO2 storage from blast furnace in the Triassic sandstones of Lorraine (Eastern Paris Basin, France): An experimental study. Energy Procedia 37, 5315-5322.
18. 2 injected in deep saliner aquifers. Soc. Pet. Eng. 2006, (Richardson, Texas 75080, USA).
19. Bennion, D., Bachu, S., 2010. Drainage and imbibition CO2/brine relative permeability curves at reservoir conditions for carbonate formations. In: Proceedings of the SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers Richardson, Texas 75080, USA.
20. 2 sequestration in deep sedimentary formations. Elements 2008, 4(5):325-331.
21. Bentsen R.G. An investigation into whether the nondiagonal mobility coefficients which arise in coupled, 2-phase flow are equal. Transp. Porous Media 1994, 14(1):23-32.
22. 2-brine systems in sandstone. Int. J. Greenh. Gas Control 2013, 12:478-492.
23. 2-water system at high pressures and moderate temperatures. J. Chem. Eng. Data 2011, 56:3725-3733.
24. 2-water-quartz/calcite systems in the perspective of carbon sequestration. Int. J. Greenh. Gas Control 2011, 5(5):1259-1271.
25. Blunt M., King M.J., Scher H. Simulation and theory of 2-phase flow in porous-media. Phys. Rev. A 1992, 46(12):7680-7699.
26. Blunt M., King P. Scaling structure of viscous fingering. Phys. Rev. A 1988, 37(10):3935-3941.
27. Bo Z., Loggia D., Xiaorong L., Vasseur G., Ping H. Numerical studies of gravity destabilized percolation in 2D porous media. Eur. Phys. J. B 2006, 50(4):631-637.
28. Boulin, P., Bretonnier, P., Vassil, V., Samouillet, A., Fleury, M., Lombard, J., 2011. Entry pressure measurements using three unconventional experimental methods. In: Proceedings of the International Symposium of the Society of Core Analysts, Austin, TX, 18-21 September. Society of Core Analysts, SCA, Fredericton, New Brunswick, E3B 0H8 Canada.
29. Brackbill J.U., Kothe D.B., Zemach C. A continuum method for modeling surface-tension. J. Comput. Phys. 1992, 100(2):335-354.
30. Brenner H. Dispersion resulting from flow through spatially periodic porous-media. Philos. Trans. R. Soc. Lond. A Math. Phys. Eng. Sci. 1980, 297(1430):81-133.
31. Brooks R.H., Corey A.T. Properties of porous media affecting fluid flow. J. Irrig. Drain. Div. Am. Soc. Civil Eng. 1966, 92(IR2):61-88.
32. Burdine N.T. Relative permeability calculations from pore-size distribution data. Trans. AIME Pet. Eng. 1953, 198:71-77.
33. Chalbaud, C., Lombard, J.-M., Martin, F., Robin, M., Bertin, H., Egermann, P., 2007. Two phase flow properties of brine-CO2 systems in a carbonate core: influence of wettability on Pc and kr. In: Proceedings of the SPE/EAGE Reservoir Characterization and Simulation Conference. Society of Petroleum Engineers, SPE, Richardson, Texas 75080, USA.
34. 2 storage in deep saline aquifers. Oil Gas Sci. Technol-Rev. de l[U+05F3]Inst. Fr. Pét. 2010, 65(4):541-555.
35. Chaouche M., Rakotomalala N., Salin D., Xu B., Yortsos Y.C. Invasion percolation in a hydrostatic or permeability gradient-experiments and simulations. Phys. Rev. E 1994, 49((5) Part A):4133-4139.
36. Chen J.D., Wilkinson D. Pore-scale viscous fingering in porous-media. Phys. Rev. Lett. 1985, 55(18):1892-1895.
37. Cheng M., Hua J., Lou J. Simulation of bubble-bubble interaction using a lattice Boltzmann method. Comput. Fluids 2010, 39(2):260-270.
38. Chiquet P., Broseta D., Thibeau S. Wettability alteration of caprock minerals by carbon dioxide. Geofluids 2007, 7(2):112-122.
39. Chuoke R.L., Vanmeurs P., Vanderpoel C. The instability of slow, immiscible, viscous liquid-liquid displacements in permeable media. Trans. AIME 1959, 216:188-194.
40. 2 injection into saline formations. Soc. Pet. Eng. J. 2009, 14(4):588-594.
41. Corey A.T., Brooks R.H. Drainage characteristics of soils. Soil Sci. Soc. Am. J. 1975, 39(2):251-255.
42. 2 storage sites: geochemical modelling of experimental results. Energy Procedia 2013, 37:3699-3710.
43. 2-ECBM Projects. Energy 2005, 30:1031-1952.
44. DeGennes P.G. Theory of slow biphasic flows in porous-media. Physicochem. Hydrodyn. 1983, 4(2):175-185.
45. Delhaye J. Jump conditions and entropy sources in two-phase systems. local instant formulation. Int. J. Multiph. Flow 1974, 1(3):395-409.
46. Desjardins O., Moureau V., Pitsch H. An accurate conservative level set/ghost fluid method for simulating turbulent atomization. J. Comput. Phys. 2008, 227(18):8395-8416.
47. 2/water/glass interface. Langmuir 2006, 22(5):2161-2170.
48. Dullien F., Dong M. Experimental determination of the flow transport coefficients in the coupled equations of two-phase flow in porous media. Transp. Porous Media 1996, 25(1):97-120.
49. Dullien F.A.L. Porous Media Fluid Transport and Pore Structure 1992, Acedemic Press, San Diego, CA.
50. Egermann, P., Chalbaud, C., Duquerroix, J., Le Gallo, Y., 2006. An integrated approach to parameterize reservoir models for CO2 injection in aquifers. In: Proceedings of the SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, SPE, Richardson, Texas 75080, USA.
51. 2 geological storage. Water Resour. Res. 2010, 46(7).
52. Farokhpoor, R., Bjorkvik, B., Lindeberg, E., Torsaeter, O., 2013. CO2 wettability behavior during CO2 sequestration in saline aquifer-an experimental study on minerals representing sandstone and carbonate. Energy Procedia, 37, 5339-5351.
53. 2 disposal for the Gorgon Project. Energy Procedia 2009, 1(1):3031-3038.
54. Foster W.R., McMillen J.M. The equations of motion of fluids in porous media. I. Propagation velocity of pressure pulses. Soc. Pet. Eng. J. SPE 1967, 1762:333-341.
55. 2) system at elevated pressures and temperatures. J. Chem. Eng. Data 2010, 55(10):4168-4175.
56. Goode P.A., Ramakrishnan T. Momentum-transfer across fluid-fluid interfaces in porous-media-a network model. AIChE J. 1993, 39(7):1124-1134.
57. Gray W., Miller C. Thermodynamically constrained averaging theory approach for modeling flow and transport phenomena in porous medium systems. 1. Motivation and overview. Adv. Water Resour. 2005, 28(2):161-180.
58. Gray W.G. Thermodynamics and constitutive theory for multiphase porous-media flow considering internal geometric constraints. Adv. Water Resour. 1999, 22(5):521-547.
59. Gray W.G., Hassanizadeh S.M. Macroscale continuum mechanics for multiphase porous-media flow including phases, interfaces, common lines and common points. Adv. Water Resour. 1998, 21(4):261-281.
60. Grosfils P., Boon J.P. Viscous fingering in miscible, immiscible and reactive fluids. Int. J. Mod. Phys. B 2003, 17(01n02):15-20.
61. Hassanizadeh S.M., Gray W.G. Mechanics and thermodynamics of multiphase flow in porous media including interphase boundaries. Adv. Water Resour. 1990, 13(4):169-186.
62. Hassanizadeh S.M., Gray W.G. Thermodynamic basis of capillary pressure in porous media. Water Resour. Res. 1993, 29(10):3389-3405.
63. Hebach A., Oberlof A., Dahmen N., Kogel A., Ederer H., Dinjus E. Interfacial tension at elevated pressures - measurements and correlations in the water + carbon dioxide system. J. Chem. Eng. Data 2002, 47:1540-1546.
64. 4. Geofluids 2004, 4(1):61-80.
65. Hou S., Shan X., Zou Q., Doolen G.D., Soll W.E. Evaluation of two lattice Boltzmann models for multiphase flows. J. Comput. Phys. 1997, 138(2):695-713.
66. 2O-NaCl systems below 647K. assessment of experimental data and thermodynamic models. Chem. Geol. 2007, 238(3-4):249-267.
67. Huang H., Huang J.-J., Lu X.-Y., Sukop M.C. On simulations of high-density ratio flows using color-gradient multiphase lattice Boltzmann models. Int. J. Mod. Phys. C 2013, 24(4).
68. Huang H., Lu X.-y. Relative permeabilities and coupling effects in steady-state gas-liquid flow in porous media. a lattice Boltzmann study. Phys. Fluids 2009, 21(9).
69. Huang H., Wang L., Lu X.-y. Evaluation of three lattice Boltzmann models for multiphase flows in porous media. Comput. Math. Appl. 2011, 61(12):3606-3617.
70. Hubbert M.K. Darcys law and the field equations of the flow of underground fluids. Trans. AIME 1956, 207(10):223-239.
71. 2 storage site. Energy Procedia 2009, 1(1):2021-2028.
72. Ii S., Sugiyama K., Takeuchi S., Takagi S., Matsumoto Y., Xiao F. An interface capturing method with a continuous function. the THINC method with multi-dimensional reconstruction. J. Comput. Phys. 2012, 231(5):2328-2358.
73. Ishii M., Hibiki T. Thermo-Fluid Dynamics of Two-phase Flow 2011, Springer Science + Business Media, NY 10013, USA.
74. Ji, X., Ji, Y., Xiao, C., 2011. Thermmodynamic and dynamic investigation for CO2 storage in deep saline aquifers. In: World Renewable Energy Congress, Linkoping, Sweden, 8-13 May.
75. Joekar-Niasar V., Hassanizadeh S., Dahle H. Non-equilibrium effects in capillarity and interfacial area in two-phase flow. dynamic pore-network modelling. J. Fluid Mech. 2010, 655(1):38-71.
76. Joekar-Niasar V., Hassanizadeh S.M. Effect of fluids properties on non-equilibrium capillarity effects. dynamic pore-network modeling. Int. J. Multiph. Flow 2011, 37(2):198-214.
77. Juanes R. Nonequilibrium effects in models of three-phase flow in porous media. Adv. Water Resour. 2008, 31(4):661-673.
78. 2 and ionic strength effects on wettability of silica surfaces. equilibrium contact angle measurements. Energy Fuels 2012, 488-498.
79. Juric D., Tryggvason G. Computations of boiling flows. Int. J. Multiph. Flow 1998, 24(3):387-410.
80. Kalaydjian F. Origin and quantification of coupling between relative permeabilities for 2-phase flows in porous-media. Transp. Porous Media 1990, 5(3):215-229.
81. Kang Q., Zhang D., Chen S. Immiscible displacement in a channel. simulations of fingering in two dimensions. Adv. Water Resour. 2004, 27(1):13-22.
82. Kelkar, M., Perez, G., Chopra, A., 2002. Applied Geostatistics for Reservoir Characterization. Society of Petroleum Engineers, Richardson, TX.
83. Korteland S., Bottero S., Hassanizadeh S.M., Berentsen C.W.J. What is the correct definition of average pressure?. Transp. Porous Media 2010, 84(1):153-175.
84. 2 and water in sandstone rocks at reservoir conditions. Water Resour. Res. 2012, 48.
85. 2-NaCl mixtures up to 850°C and 500MPa: a synthetic fluid inclusion study. XVI ECROFI Eur. Curr. Res. Fluid Inclus. 2001, 241-244.
86. Le Guen S.S., Kovscek A.R. Nonequilibrium effects during spontaneous imbibition. Transp. Porous Media 2006, 63(1):127-146.
87. Leal L.G. Advanced Transport Phenomena. Fluid Mechanics and Convective Transport Processes 2007, Cambridge University Press, New York, USA.
88. Lenormand R. Flow through porous-media-limits of fractal patterns. Proc. R. Soc. Lond. Ser. A Math. Phys. Eng. Sci. 1989, 423(1864):159-168.
89. Lenormand R., Touboul E., Zarcone C. Numerical-models and experiments on immiscible displacements in porous-media. J. Fluid Mech. 1988, 189:165-187.
90. Leverett M. Capillary behavior in porous solids. Trans. AIME Pet. Eng. 1941, 142:152-168.
91. 2 solubility trapping. Adv. Water Resour. 2013, 62:488-498.
92. 2 storage in the Weyburn field. Geofluids 2005, 5:326-334.
93. Li H.N., Pan C.X., Miller C.T. Pore-scale investigation of viscous coupling effects for two-phase flow in porous media. Phys. Rev. E 2005, 72(2 Part 2).
94. 2 storage capacity of the Utsira formation. Energy Procedia 2009, 1(1):2777-2784.
95. 2 injection into saline aquifers. Int. J. Greenh. Gas Control 2013, 15:42-47.
96. Liu X.D., Fedkiw R.P., Kang M.J. A boundary condition capturing method for Poisson[U+05F3]s equation on irregular domains. J. Comput. Phys. 2000, 160(1):151-178.
97. Maloy K.J., Boger F., Feder J., Jossang T., Meakin P. Dynamics of viscous-fingering fractals in porous-media. Phys. Rev. A 1987, 36(1):318-324.
98. Marle C.M. On macroscopic equations governing multiphase flow with diffusion and chemical-reactions in porous-media. Int. J. Eng. Sci. 1982, 20(5):643-662.
99. McClure J.E., Adalsteinsson D., Pan C., Gray W.G., Miller C.T. Approximation of interfacial properties in multiphase porous medium systems. Adv. Water Resour. 2007, 30(3):354-365.
100. Meheust Y., Lovoll G., Maloy K., Schmittbuhl J. Interface scaling in a two-dimensional porous medium under combined viscous, gravity, and capillary effects. Phys. Rev. E 2002, 66(5).
101. Mei C.C., Auriault J.L. Mechanics of heterogeneous porous-media with several spatial scales. Proc. R. Soc. Lond. A Math. Phys. Eng. Sci. 1989, 426(1871):391-423.
102. Mo, S., Akervoll, I., 2005. Modeling long-term CO2 storage in aquifer with a black-oil reservoir simulator. In: Proceedings of the SPE/EPA/DOE Exploration and Production Environmental Conference. Society of Petroleum Engineers, SPE, Richardson, Texas 75080, USA.
103. Molins S., Trebotich D., Steefel C.I., Shen C. An investigation of the effect of pore scale flow on average geochemical reaction rates using direct numerical simulation. Water Resour. Res. 2012, 48.
104. 2-brine relative permeability experiments in reservoir rocks - Literature review and recommendations. Transp. Porous Media 2011, 87(2):367-383.
105. Muskat M. The flow of fluids through porous media. J. Appl. Phys. 1937, 8:274-282.
106. Muskat M., Meres M.W. The flow of heterogeneous fluids through porous media. Physics 1936, 7(9):346-363.
107. 2 storage. Geochim. Cosmochim. ACTA 2012, 81:28-38.
108. 2 plume evolution during injection. Transp. Porous Media 2005, 58(3):339-360.
109. Nordbotten J.M., Celia M.A., Dahle H.K., Hassanizadeh S.M. Interpretation of macroscale variables in Darcy[U+05F3]s law. Water Resour. Res. 2007, 43(8).
110. Nordbotten J.M., Celia M.A., Dahle H.K., Hassanizadeh S.M. On the definition of macroscale pressure for multiphase flow in porous media. Water Resour. Res. 2008, 44(6).
111. Oak M., Baker L., Thomas D. Three-phase relative permeability of berea sandstone. J. Pet. Technol. 1990, 42(8):1054-1061.
112. 2 sequestration. Energy Procedia 2013, 37:5014-5025.
113. Olsson E., Kreiss G., Zahedi S. A conservative level set method for two phase flow II. J. Comput. Phys. 2007, 225(1):785-807.
114. Ono M., Kameya H., Hosoda K., Kamidozono Y., Azuma H. Experimental measurements of threshold pressure for modelling saline aquifers in Japan. Energy Procedia 2013, 37:5456-5463.
115. Pan C., Hilpert M., Miller C. Lattice-Boltzmann simulation of two-phase flow in porous media. Water Resour. Res. 2004, 40(1).
116. Paterson L., Hornof V., Neale G. Visualization of a surfactant flood of an oil-saturated porous-medium. Soc. Pet. Eng. J. 1984, 24(3):325-327.
117. Pentland C.H., El-Maghraby R., Iglauer S., Blunt M.J. Measurements of the capillary trapping of super-critical carbon dioxide in berea sandstone. Geophys. Res. Lett. 2011, 38(6):L06401.
118. Perkins T.K., Johnston O.C. A study of immiscible fingering in linear models. Soc. Pet. Eng. J. 1969, 9(1):39-46.
119. 2 distribution in reservoir rocks. Transp. Porous Media 2010, 82(1):93-109.
120. 2 and brine in reservoir rocks. Energy Procedia 2009, 1(1):3515-3522.
121. 2/water system in sandstone rocks at reservoir conditions. Adv. Water Resour. 2012, 38:48-59.
122. 2 sequestration. Adv. Water Resour. 2007, 30(11):2339-2353.
123. Porter M.L., Schaap M.G., Wildenschild D. Lattice-Boltzmann simulations of the capillary pressure-saturation-interfacial area relationship for porous media. Adv. Water Resour. 2009, 32(11):1632-1640.
124. Purcell W. Capillary pressures-their measurement using mercury and the calculation of permeability therefrom. J. Pet. Technol. 1949, 1(2):39-48.
125. Raeini A.Q., Blunt M.J., Bijeljic B. Modelling two-phase flow in porous media at the pore scale using the volume-of-fluid method. J. Comput. Phys. 2012, 231(17):5653-5668.
126. Riaz A., Tang G.-Q., Tchelepi H.A., Kovscek A.R. Forced imbibition in natural porous media. comparison between experiments and continuum models. Phys. Rev. E 2007, 75(3 Part 2).
127. Riaz A., Tchelepi H. Stability of two-phase vertical flow in homogeneous porous media. Phys. Fluids 2007, 19(7).
128. Riaz A., Tchelepi H.A. Linear stability analysis of immiscible two-phase flow in porous media with capillary dispersion and density variation. Phys. Fluids 2004, 16(12):4727-4737.
129. Riaz A., Tchelepi H.A. Influence of relative permeability on the stability characteristics of immiscible flow in porous media. Trans. Porous Media 2006, 64:315-338.
130. Rose W. Ideas about viscous coupling in anisotropic media. Transp. Porous Media 1995, 18(1):87-93.
131. Scardovelli R., Zaleski S. Direct numerical simulation of free-surface and interfacial flow. Annu. Rev. Fluid Mech. 1999, 31:567-603.
132. 2 at elevated temperature and pressure. Geochim. Cosmochim. Acta 1995, 59(19):3953-3959.
133. Scriven L.E. Dynamics of a fluid interface-equation of motion for newtonian surface fluids. Chem. Eng. Sci. 1960, 12(2):98-108.
134. Shah, V., Broseta, D., Mouronval, G.r., 2008. Capillary alteration of caprocks by acid gases. In: Proceedings of the SPE/DOE Symposium on Improved Oil Recovery Richardson, TX.
135. Sharma J., Inwood S., Kovscek A. Experiments and analysis of multiscale viscous fingering during forced imbibition. SPE J. 2012, 17(4):1142-1159.
136. Sheu T.W., Yu C., Chiu P. Development of level set method with good area preservation to predict interface in two-phase flows. Int. J. Numer. Methods Fluids 2011, 67(1):109-134.
137. Sheu T.W.H., Yu C.H., Chiu P.H. Development of a dispersively accurate conservative level set scheme for capturing interface in two-phase flows. J. Comput. Phys. 2009, 228(3):661-686.
138. Slattery J.C. Flow of viscoelastic fluids through porous media. AIChE J. 1967, 13(6):1066.
139. Slattery J.C. Advanced Transport Phenomena 1999, Cambridge University Press, Cambridge, U.K.
140. Song Y., Chen B., Nishio M., Akai M. The study on densitychange of carbon dioxide seawater solution at high pressure andlow temperature. Energy 2005, 30:2298-2307.
141. 2-rich regions. Chem. Geol. 2012, 322-323:151-171.
142. Stokes J.P., Weitz D.A., Gollub J.P., Dougherty A., Robbins M.O., Chaikin P.M., Lindsay H.M. Interfacial stability of immiscible displacement in a porous-medium. Phys. Rev. Lett. 1986, 57(14):1718-1721.
143. Tartakovsky A.M., Ward A.L., Meakin P. Pore-scale simulations of drainage of heterogeneous and anisotropic porous media. Phys. Fluids 2007, 19(10).
144. Teng H., Yamasaki A. Solubility of liquid CO2 in synthetic seawater at temperatures from 278K to 293K and pressures from 6.44MPa to 29.49MPa, and densities of the correspondingaqueous solutions. J. Chem. Eng. Data 1998, 43(1):2-5.
145. Theodoropoulou M.A., Sygouni V., Karoutsos V., Tsakiroglou C.D. Relative permeability and capillary pressure functions of porous media as related to the displacement growth pattern. Int. J. Multiph. Flow 2005, 31(10-11):1155-1180.
146. Thibodeau L., Guo T.L., Neale G.H. Effects of connate water on immiscible displacement processes in porous media. Powder Technol. 1997, 93(3):209-217.
147. Tho N.M., Ha T.K. A theoretical study of the formation of carbonic acid from the hydration of carbon dioxide: a case of active solvent catalysis. J. Am. Chem. Soc. 1984, 106(3):599-602.
148. 2 geological storage purposes. Energy Procedia 2011, 4:5422-5429.
149. Tsakiroglou C.D., Theodoropoulou M.A., Karoutsos V. Nonequilibrium capillary pressure and relative permeability curves of porous media. AIChE J. 2003, 49(10):2472-2486.
150. Valvatne P.H., Piri M., Lopez X., Blunt M.J. Predictive pore-scale modeling of single and multiphase flow. Transp. Porous Media 2005, 58(1-2):23-41.
151. van Genuchten M.T. A closed-form equation for predicting the hydraulic conductivity of unsaturated soils. Soil Sci. Soc. Am. J. 1980, 44(5):892-898.
152. Wang X., Conway W., Burns R., McCann N., Maeder M. Comprehensive study of the hydration and dehydration reactions of carbon dioxide in aqueous solution. J. Phys. Chem. A 2010, 114(4):1734-1740.
153. Wang Z., Yang J., Stern F. A new volume-of-fluid method with a constructed distance function on general structured grids. J. Comput. Phys. 2012, 231(9):3703-3722.
154. Whitaker S. Velocity profile in Stefan diffusion tube. Ind. Eng. Chem. Fundam. 1967, 6(3):476.
155. Whitaker S. Flow in porous-media. 2. The governing equations for immiscible, 2-phase flow. Transp. Porous Media 1986, 1(2):105-125.
156. 2 storage. an experimental study on sealing efficiency and mineral alterations. Energy Procedia 2009, 1(1):3469-3476.
157. Wyckoff R.D., Botset H.G. The flow of gas-liquid mixtures through unconsolidated sands. Physics A: J. Gen. Appl. Phys. 1936, 7(1):325-345.
158. Yang D., Currier R.P., Zhang D.Z. Ensemble phase averaged equations for multiphase flows in porous media. Part 1. the bundle-of-tubes model. Int. J. Multiph. Flow 2009, 35(7):628-639.
159. Yiotis A.G., Psihogios J., Kainourgiakis M.E., Papaioannou A., Stubos A.K. A lattice Boltzmann study of viscous coupling effects in immiscible two-phase flow in porous media. Colloids and Surf. A: Physicochem. Eng. Asp. 2007, 300(1-2 Sp. Iss. SI):35-49.
160. Yortsos Y.C., Hickernell F.J. Linear-stability of immiscible displacement in porous-media. SIAM J. Appl. Math. 1989, 49(3):730-748.
161. Yortsos Y.C., Xu B., Salin D. Phase diagram of fully developed drainage in porous media. Phys. Rev. Lett. 1997, 79(23):4581-4584.
162. Yortsos Y.C., Xu B.M., Salin D. Delineation of microscale regimes of fully-developed drainage and implications for continuum models. Comput. Geosci. 2001, 5(3):257-278.
163. Zhang D.Z. Ensemble phase averaged equations for multiphase flows in porous media. Part 2. a ageneral theory. Int. J. Multiph. Flow 2009, 35(7):640-649.
164. 2 saturated water depressurization. Transp. Porous Media 2012, 91(2):459-478.