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Title: An extended JBN method of determining unsteady-state two-phase relative permeability: EXTENDED JBN METHOD OF DETERMINING RELATIVE PERMEABILITY

Authors:
 [1];  [1];  [1]
  1. Department of Petroleum and Geosystems Engineering, University of Texas at Austin, Austin Texas USA
Publication Date:
Research Org.:
Energy Frontier Research Centers (EFRC) (United States). Center for Frontiers of Subsurface Energy Security (CFSES)
Sponsoring Org.:
USDOE Office of Science (SC), Basic Energy Sciences (BES) (SC-22)
OSTI Identifier:
1388731
DOE Contract Number:
SC0001114
Resource Type:
Journal Article
Resource Relation:
Journal Name: Water Resources Research; Journal Volume: 52; Journal Issue: 10; Related Information: CFSES partners with University of Texas at Austin (lead); Sandia National Laboratory
Country of Publication:
United States
Language:
English
Subject:
nuclear (including radiation effects), carbon sequestration

Citation Formats

Chen, Xiongyu, Kianinejad, Amir, and DiCarlo, David A. An extended JBN method of determining unsteady-state two-phase relative permeability: EXTENDED JBN METHOD OF DETERMINING RELATIVE PERMEABILITY. United States: N. p., 2016. Web. doi:10.1002/2016WR019204.
Chen, Xiongyu, Kianinejad, Amir, & DiCarlo, David A. An extended JBN method of determining unsteady-state two-phase relative permeability: EXTENDED JBN METHOD OF DETERMINING RELATIVE PERMEABILITY. United States. doi:10.1002/2016WR019204.
Chen, Xiongyu, Kianinejad, Amir, and DiCarlo, David A. 2016. "An extended JBN method of determining unsteady-state two-phase relative permeability: EXTENDED JBN METHOD OF DETERMINING RELATIVE PERMEABILITY". United States. doi:10.1002/2016WR019204.
@article{osti_1388731,
title = {An extended JBN method of determining unsteady-state two-phase relative permeability: EXTENDED JBN METHOD OF DETERMINING RELATIVE PERMEABILITY},
author = {Chen, Xiongyu and Kianinejad, Amir and DiCarlo, David A.},
abstractNote = {},
doi = {10.1002/2016WR019204},
journal = {Water Resources Research},
number = 10,
volume = 52,
place = {United States},
year = 2016,
month =
}
  • A semianalytic method for calculation of relative permeabilities from unsteady-state displacement data is developed. The method is based on the simultaneous solution of the fractional-flow equation and an integro-differential equation, derived from the material-balance and Darcy equations for immiscible displacement of two incompressible phases, including the capillary pressure by use of various volumetric relationships. This method for calculating two-phase relative permeabilities from unsteady-state displacement data is not restricted to the high-flow-rate experimental conditions used to overcome capillary and effects. Removal of this restriction allows the analysis of low-permeability cores with water and oil where the flow rates are low andmore » capillary end effects are important. Our method allows direct calculation from the experimental data without intermediate interpretations of graphs.« less
  • The objective of this work is to improve determination of two-phase and three-phase relative permeabilities by the use of saturation imaging techniques. The first part of the paper reports on steady-state and unsteady-state relative permeability experiments performed on restored-state carbonate reservoir cores. The aim was to study how relative permeability test methodology impacts relative permeability curves. hysteresis and residual oil saturations in these intermediate-wet cores. Refined oil was used. Significant hysteresis was observed in both the unsteady-state water and oil relative permeabilities. The characteristics of the unsteady-state water relative permeabilities imply that viscous instabilities were present during the waterflood. Centrifugemore » capillary pressure-wettability tests performed on companion core plugs both before and after the relative permeability tests showed good agreement with the unsteady-state results, but indicated change towards less oil-wetness during the steady-state tests. The main conclusion of this work is that extensive flushing of a restored-state core with refined oil may lead to a non representative relative permeability data and should therefore be avoided. The second part of the paper presents a summary of results obtained from three-phase unsteady-state flow in water-wet sandstone (Berea and Clashach) cores. In-situ saturation measurements show that the water relative permeability is dependent on water saturation alone, and that there is no change in water relative permeability due to three-phase flow. The waterflood residual oil saturation was found reduced in the presence of a gas phase, and may depend on the phase (oil or gas) injected prior to waterflooding.« less
  • The development of an unsteady-state procedure for determining three-phase relative permeability curves requires the characterization of the relative permeability curves by adjustable parameters and the adaption of a nonlinear least-squares procedure to the finite-difference approximation of the Buckley-Leverett three-phase flow equation including capillary pressure. A method was developed to represent three-phase relative permeability data by a functional form based on experimental data. Three-phase relative permeability experimental data reported by previous investigators were represented by relative permeability functions. These functions express the relative permeability of a given phase to all fluid saturations (three saturations in the case of three-phase flow) bymore » a six parameter power law equation. The six parameter equations fit the experimental data within 0.53% error. An automatic method also was developed for representing three-phase relative permeability expeimental data. This procedure eliminates errors due to subjective bias. The developed relative permeability functions were incorporated in a multi-dimensional, three-phase black oil simulator. Also, a finite difference Levenberg-Marquardt routine for solving least-squares problems was adapted to the black oil simulator. These modifications make the estimation of the parameters in the relative premeability functions possible by fitting simulated transient three-phase displacement tests to experimental tests. Preliminary results using two-phase flow displacement showed that the parameters can be estimated within a reasonable amount of computer time. Although preliminary results showed that the program works adequately for two-phase flow, conclusions cannot be stated at the present time since some errors were found in the Fortran code of the optimization function. Appropriate changes have been made, and the new version is being tested.« less