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1 edition of Simulation of end effects in relative permeability experiments found in the catalog.

Simulation of end effects in relative permeability experiments

Knud Ladekarl Thomsen

Simulation of end effects in relative permeability experiments

by Knud Ladekarl Thomsen

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  • 34 Currently reading

Published by Forskningscenter Riso in Roskilde .
Written in English


The Physical Object
Pagination61 p.
Number of Pages61
ID Numbers
Open LibraryOL24675738M
ISBN 108755013325

ADVERTISEMENTS: The below mentioned article includes a list of three experiments on permeability. 1. Experiment to study the rates of penetration (permeability) of various organic solvents into living epidermal cells: Requirements: Onion bulbs, slides, cover slip, microscope, water, stop watch, glucose, sucrose, glycerol, methyl alcohol, tertiary butyl alcohol (TBA). evaluate in-situ fluid capillary behavior. End-point relative permeability and saturation data from whole core samples, constrain the movement of fluids at these end-points. Between these end-point values, Corey’s () two-phase model is used to simulate the relative permeability characteristics.

  A presentation of the multiphase Darcy law and relative permeability. Part of a series of presentations on multiphase flow in porous media by Prof. Martin Blunt from Imperial College London. Relative permeability is measured as a core-average property using a steady-state relative permeability experiment. Relative permeability is represented numerically as a power law function of saturation, shown at right. Saturation can be measured in the same way as porosity using the CT scanner, where the core average saturation corresponding.

The permeability computed by each simulation was compared. After comparison between these three methods, the results of the direct computation method based on Navier-Stokes equations were found to be higher than the other two methods. The pore network model simulation has an obvious advantage on the computation speed and the simulation by: 6.   The physical effect of multiphase fluid distribution and flow at permeability boundaries has not been fully investigated, particularly at the pore scale (1– μm), although such behaviour can significantly affect the overall scaled-up reservoir trapping capacity and production performance. In this article, microscale physical models have been used to qualitatively study the pore scale flow Cited by:


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Simulation of end effects in relative permeability experiments by Knud Ladekarl Thomsen Download PDF EPUB FB2

Chapter Relative Permeability Introduction and Definition Routine permeability measurements are made with a single fluid filling the pore space. This is seldom the case in the reservoir situation except in water zones. Generally, two and sometimes three phases are.

Experimental and Simulation Study of Relative Permeabilities in Heavy Oil/Water/Gas Systems. Jafar Modaresghazani. imbibition process and secondary drainage to assess the possible hysteresis effects on oil-water relative permeability.

The secondary drainage process in which the core reaches the residual Capillary end. An Improved Relative Permeability Model to Match Displacement Experiments Mohammed Idrees Al-Mossawy (Corresponding Author) permeability data are essential to the reservoir simulation.

The relative permeability test can be conducted are end-point relative permeabilities for phases 1. In multiphase flow in porous media, the relative permeability of a phase is a dimensionless measure of the effective permeability of that phase. It is the ratio of the effective permeability of that phase to the absolute permeability.

It can be viewed as an adaptation of Darcy's law to multiphase flow. For two-phase flow in porous media given steady-state conditions, we can write. (). Numerical Simulation of the Mutative Permeability Effect of Percolation on Low-Permeability Reservoirs.

Petroleum Science and Technology: Vol. 29, No. 20, pp. Author: S. Liu, W. Xiao, L.-H. Yang, J.-H. Jiang. Relative permeability data (as there is special core data), values of horizontal and vertical permeability (since they were generated by geostatistical techniques) and initial oil-water contact (as there is no water observation well) are considered as uncertain parameters.

Using experimental design, effects of these parameters (maximum oil relative permeability, KRO, maximum water relative. Estimation of Dynamic Relative Permeability and Capillary Pressure from Countercurrent Imbibition Experiments Article (PDF Available) in Transport in Porous Media 65(1) October with.

The relative permeability curve which is the key parameter to field scale simulation can be obtained by the experiments. 1D numerical modelling is conducted to understand the results observed Author: Nadja Müller. Fundamentals of Fluid Flow in Porous Media Chapter 2 Relative Permeability Laboratory Measurements of Relative Permeability There are essentially five means by which relative permeability data can be obtained: Direct measurement in the laboratory by a steady state fluid flow process Direct measurement in the laboratory by an unsteady state fluid flow process Calculation.

There are two basic approaches for estimating relative permeability curves from displacement data. The methods of Johnson et al. 1 and Jones and Roszelle 2 are explicit methods in which saturation values and corresponding relative-permeability values at the end of the core sample are estimated directly.

Alternatively, an implicit approach may Cited by: @article{osti_, title = {Steady-state relative permeability measurements corrected for capillary effects}, author = {Virnovsky, G A and Skjaeveland, S M and Surdal, J}, abstractNote = {A new method is presented which enables to interpret steady-state flow experiments eliminating efforts caused by the capillary end-effect.

This is achieved by retaining the capillary term in the equations. Hysteretic Relative Permeability Effects and Reservoir Conformance - An Overview Bennion F. Brent Thomas Ronald F. Bietz Hycal Energy Research Laboratories Ltd. functions of such parameters as pore system geometry and tortousitf, wettabilityJ,4,S, initial phase saturations6, temperature1, viscmity of fluids', interfacial teosion9 andFile Size: 1MB.

Download PDF: Sorry, we are unable to provide the full text but you may find it at the following location(s): (external link)Author: K.L. Thomsen. Treatment of relative permeabilities for application in hydrocarbon reservoir simulation model A. Feigl REVIEW Measurements of relative permeabilities and their analysis and modification by means of appropriate relative permeability models represent one of the bases for development and verification of reservoir simulation Size: 1MB.

Relative permeability behavior. Figs. 1 and 2 show typical behavior for a gas/oil system. The semilog scale of Fig. 2 is convenient for reading the relative permeabilities less than Although the curves are labeled "gas" and "oil" in these figures, the phase identity of a curve can be deduced without the labels.

The global permeability damage, deduced from the backflow measurements is the result of i) a reduction of the intrinsic permeability due to the solid particles invasion and ii) an unfavorable water/oil relative permeability effect linked to the trapping of wetting phase during secondary drainage processes.

The effects of these parameters on relative permeability may be different as well. More experiments must be conducted to investigate the effects of each parameter on relative permeability.

The selection of an appropriate model to predict relative permeability of viscous oil should be made with care. Saturation table end-point scaling (SWCR, SGCR, SOWCR, SOGCR, SWL) SGCR - critical gas saturation (that is the largest gas saturation for which the gas relative permeability is zero) SOGCR - critical oil-in-gas saturation (that is the largest oil saturation for which the oil relative permeability is zero in an oil-gas-connate water system).

Relative permeability end-point scaling (KRW, KRG. Effects of Relative Permeability on Parameter Estimation AREPORT SUBMITTED TO THE DEPARTMENT OF PETROLEUM ENGINEERING OF STANFORD UNIVERSITY IN PARTIAL FULFILLMENT OF THE REQUERIMENTS FOR THE DEGREE Estimated porosities and the end point of the oil relative permeabilityFile Size: KB.

different depending on the relative permeability model used. In this paper, we extend previous investigations by performing a quantitative analysis of three-phase relative permeability models that account for hysteresis effects.

The objective of this paper is twofold: (1) assess the validity of hysteretic relative permeability models to. the end-points on the relative permeability curves for the second experiment are considered “more correct.” The lower water relative permeability values for the first experiment in spite the higher pressure drop at the end of the experiment is explained by realising its .Cite this chapter as: Qadeer S., Dehghani K., Ogbe D.O., Ostermann R.D.

() Correcting Oil-Water Relative Permeability Data for Capillary End Effect in Displacement by: Also, the low rates can allow gravitational segregation to occur in the core during the test.

A simulator was used to investigate the potential impact of both end effects and gravitational segregation on the interpretation. It was found that the additional pressure drop caused by the end effects shifted the estimated relative permeability by: 2.