Characterizing two-phase flow relative permeabilities in chemicalflooding using a pore-scale network model

Liu, Qingjie ; Shen, Pingping ; Wu, Yu-Shu

Lawrence Berkeley National Laboratory

关键词: Saturation;    58;    Chemical Properties;    Two-Phase Flow;    Water;   

DOI  :  10.2172/929035
RP-ID  :  LBNL--54750
RP-ID  :  DE-AC02-05CH11231
RP-ID  :  929035

美国|英语

来源: UNT Digital Library

【 摘 要 】

A dynamic pore-scale network model is presented for investigating the effects of interfacial tension and oil-water viscosity on relative permeability during chemical flooding. This model takes into account both viscous and capillary forces in analyzing the impact of chemical properties on flow behavior or displacement configuration, as opposed to the conventional or invasion percolation algorithm which incorporates capillary pressure only. The study results indicate that both water and oil relative-permeability curves are dependent strongly on interfacial tension as well as an oil-water viscosity ratio. In particular, water and oil relative-permeability curves are both found to shift upward as interfacial tension is reduced, and they both tend to become linear versus saturation once interfacial tension is at low values. In addition, the oil-water viscosity ratio appears to have only a small effect under conditions of high interfacial tension. When the interfacial tension is low, however, water relative permeability decreases more rapidly (with the increase in the aqueous-phase viscosity) than oil relative permeability. The breakthrough saturation of the aqueous phase during chemical flooding tends to decrease with the reduction of interfacial tension and may also be affected by the oil-water viscosity ratio.