Skip to main content
Log in

Relative Permeability Analysis of Tube Bundle Models, Including Capillary Pressure

  • Published:
Transport in Porous Media Aims and scope Submit manuscript

Abstract

The analytical equations for calculating two-phase flow, including local capillary pressures, are developed for the bundle of parallel capillary tubes model. The flow equations that are derived were used to calculate dynamic immiscible displacements of oil by water under the constraint of a constant overall pressure drop across the tube bundle. Expressions for averaged fluid pressure gradients and total flow rates are developed, and relative permeabilities are calculated directly from the two-phase form of Darcy's law. The effects of pressure drop and viscosity ratio on the relative permeabilities are discussed. Capillary pressure as a function of water saturation was delineated for several cases and compared to a steady-state mercury-injection drainage type of capillary pressure profile. The bundle of serial tubes model (a model containing tubes whose diameters change randomly at periodic intervals along the direction of flow), including local Young-Laplace capillary pressures, was analyzed with respect to obtaining relative permeabilities and macroscopic capillary pressures. Relative permeabilities for the bundle of parallel tubes model were seen to be significantly affected by altering the overall pressure drop and the viscosity ratio; relative permeabilities for the bundle of serial tubes were seen to be relatively insensitive to viscosity ratio and pressure, and were consistently X-like in profile. This work also considers the standard Leverett (1941) type of capillary pressure versus saturation profile, where drainage of a wetting phase is completed in a step-wise steady fashion; it was delineated for both tube bundle models. Although the expected increase in capillary pressure at low wetting-phase saturation was produced, comparison of the primary-drainage capillary pressure curves with the pseudo-capillary pressure profiles, that are computed directly using the averaged pressures during the displacements, revealed inconsistencies between the two definitions of capillary pressure.

This is a preview of subscription content, log in via an institution to check access.

Access this article

Price excludes VAT (USA)
Tax calculation will be finalised during checkout.

Instant access to the full article PDF.

Similar content being viewed by others

References

  • Aker, E., Måløy, K.J. and Hansen, A.: 1998, Simulating temporal evolution of pressure in two-phase flow in porous media, Phys. Rev. E 58(2), 2217-2226.

    Google Scholar 

  • Avraam, D.G. and Payatakes, A.C.: 1995, Flow regimes and relative permeabilities during steadystate two-phase flow in porous media, J. Fluid Mech. 293, 207-236.

    Google Scholar 

  • Bartley, J.T.: 2001, Relative permeability studies of tube bundle models and unconsolidated porous media, PhD. dissertation, University of Manitoba, Winnipeg, Canada.

    Google Scholar 

  • Bartley, J.T. and Ruth D.W.: 1999, Relative permeability analysis of tube bundle models, Transport in Porous Media 36, 161-187.

    Google Scholar 

  • Buckley, S.E. and Leverett, M.C.: 1942, Mechanism of fluid displacement in sands, Petrol. Trans. AIME 146, 107-116.

    Google Scholar 

  • Constantinides, G.N. and Payatakes, A.C.: 1996, Network simulation of steady-state two-phase flow in consolidated porous media, AIChE J. 42(2), 369-382.

    Google Scholar 

  • Dahle, H.K. and Celia, M.A.: 1999, A dynamic network model for two-phase immiscible flow, Comput. Geosci. 3, 1-22.

    Google Scholar 

  • Dake, L.P.: 1978, Fundamentals of Reservoir Engineering, Developments in Petroleum Science 8, Elsevier Scientific Publishing Company, New York, pp. 343-430.

    Google Scholar 

  • Delclaud J.P.: 1972, New results on the displacement of a fluid by another in a porous medium, SPE Annual Fall Meeting, San Antonio, Oct. 8-11, SPE 4103.

  • Dias, M.M. and Payatakes, A.C.: 1986, Network models for two-phase flow in porous media Part 1. Immiscible microdisplacement of non-wetting fluids, J. Fluid Mech. 164, 305-336.

    Google Scholar 

  • Islam, M.R. and Bentsen, R.G.: 1986, A dynamic method for measuring relative permeability, J. Can. Pet. Tech. 25(1), 39-50.

    Google Scholar 

  • Johnson, E.F., Bossler, D.P. and Naumann, V.O.: 1959, Calculation of relative permeability from displacement experiments, Petrol. Trans. AIME 216, 370-372.

    Google Scholar 

  • Kaasschieter, E.F.: 1999, Solving the Buckley-Leverett equation with gravity in a heterogeneous porous medium, Comput. Geosci. 3, 23-48.

    Google Scholar 

  • Lebastie, A., Guy, M., Delclaud, J.P. and Iffley, R.: 1980, Effect of flow rate and wettability on wateroil relative permeabilities and capillary pressure, SPE Annual Fall Meeting, Dallas, September 21-24, SPE 9236.

  • Leverett, M.C.: 1941, Capillary behavior in porous solids, Petrol. Trans. AIME 142, 152-169.

    Google Scholar 

  • Levine, J.S.: 1954, Displacement experiments in a consolidated porous system, Petrol. Trans. AIME 201, 57-66.

    Google Scholar 

  • Mejia, G.M., Mohanty, K.K. and Watson, A.T.: 1995, Use of in situ saturation data in estimation of two-phase flow functions in porous media, J. Pet. Sci. Eng. 12(3), 233-245.

    Google Scholar 

  • Sarma, H.K. and Bentsen, R.G.: 1989, A study of the impact of instability on relative permeability and capillary pressure, J. Pet. Sci. Eng. 2(4), 311-330.

    Google Scholar 

Download references

Author information

Authors and Affiliations

Authors

Rights and permissions

Reprints and permissions

About this article

Cite this article

Bartley, J., Ruth, D. Relative Permeability Analysis of Tube Bundle Models, Including Capillary Pressure. Transport in Porous Media 45, 445–478 (2001). https://doi.org/10.1023/A:1012297432745

Download citation

  • Issue Date:

  • DOI: https://doi.org/10.1023/A:1012297432745

Navigation