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2 edition of Three-phase relative permeability found in the catalog.

Three-phase relative permeability

A. Manjnath

Three-phase relative permeability

an overview

by A. Manjnath

  • 21 Want to read
  • 18 Currently reading

Published by Montana College of Mineral Science and Technology in Butte, MT .
Written in English

    Subjects:
  • Secondary recovery of oil.,
  • Oil fields -- Production methods.,
  • Rocks -- Permeability.

  • Edition Notes

    Other titles3-phase relative permeability.
    StatementA. Manjnath, Matt M. Honarpour.
    ContributionsHonarpour, Mehdi.
    Classifications
    LC ClassificationsTN871 .M3497 1984
    The Physical Object
    Pagination56 leaves :
    Number of Pages56
    ID Numbers
    Open LibraryOL2926068M
    LC Control Number84160626

    Purchase Integrated Flow Modeling, Volume 49 - 1st Edition. Print Book & E-Book. ISBN , @article{osti_, title = {Three-phase relative permeability of Berea sandstone}, author = {Oak, M J and Baker, L E and Thomas, C C}, abstractNote = {Reservoir engineering calculations frequently require consideration of coexisting oil, water, and gas phases. Such three-phase flow occurs when oil is displaced by simultaneous gas/water flow as in CO{sub 2}, water-alternating-gas flooding.

    An in-depth study of the fundamental aspects of enhanced oil recovery (EOR), this book brings together detailed analyses of proven techniques. It begins with the current theories of the origin of oil and ends with a treatise on waterflooding which is the basis of the majority of EOR processes. Two and three-phase relative permeability relationships are discussed since they form the basis for.   Immiscible three-phase flow in a rigid porous medium is upscaled from the pore to the continuum (Darcy) scale through homogenization relying on multiple scale expansion. We solve the Stokes flow problem at the pore level upon imposing continuity of velocity and shear stress at the fluid–fluid interfaces. This enables one to explicitly account for the momentum transfer between the .

    three-phase relative permeability. For the three-phase relative permeability to oil, the best correlations between experimental data and tests using Blunt, Hustad Hasen, and Baker’s models were obtained at oil saturations between 40% and 70%. Keywords: oil reservoir, unsteady state, multiphase flow, relative permeability. The Environmental Hydrogeology group and its laboratory (Multiscale Porous Media Lab) perform research projects related to veracity of porous media types including natural porous media (such as soil and rocks), industrial porous media (e.g., paper, diapers, fuel .


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Three-phase relative permeability by A. Manjnath Download PDF EPUB FB2

Three Phase Relative Permeability. Three-phase flow situations occur when gas is injected into a reservoir or when a reservoir is produced at a pressure below its bubble point. The flow of one phase relative to the other phases is represented by the relative permeability of that phase.

The results of three-phase relative permeability tests on nine water-wet consolidated Berea sandstone samples are presented as composite ternary diagrams showing isoperms of oil, water and gas.

Capillary pressure control was exercised over the flow of gas and oil in the presence of water. The water saturations ranged from 17 to 71 per cent pore. Recent innovations in the field of oil recovery have led to a renewed interest in three-phase relative permeability.

Three-phase relative permeability book flow occurs when the water saturation is higher than the Three-phase relative permeability book level, and oil and gas are also present as mobile by: Two- and three-phase relative permeability studies (OCoLC) Material Type: Government publication, National government publication: Document Type: Book: All Authors / Contributors: Erle C Donaldson; Gordon W Dean; United States.

Bureau of Mines. The estimation of three‐phase relative permeability is proposed using the digital rock physics (DRP) simulations. The results indicate that the relative permeability of CO 2 as calculated using our steady state method is not sensitive to the initial oil fraction if the oil distribution is originally uniform.

Baker's () empirical model was Cited by: Calculated three-phase relative permeability (k calc rj) vs. measured three-phase data (k expr rj), j 5 1, 2, 3 [Sam Oak ()]. +1 a) UTKR3P model, path dependency (k 0 r 31 6 ¼ 6 ¼k. Figure shows an example of relative permeability curves in an oil-wet rock.

The water relative permeability curve after polymer contact, k rwp, was parallel but significantly lower than the water relative permeability curve before polymer flood, k rw1. Relative Permeability Three Phase Relative Permeability: Relative Permeability in Two-Phase Systems. The wetting fluid in a uniformly wetted system is located in the smaller pores and as a thin film in the larger pores, while the non wetting phase is located in the centers of the larger pores.

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. Introductions to Stone II three-phase relative permeability model and unconventional oil and gas resources; Discussions on low salinity water injection, saturated reservoirs and production trends of five reservoir fluids, impact of mud filtrate invasion and heavy organics on samples, and flow assurance problems due to solid components of petroleum1/5(2).

Baker, L. E.:Three-phase relative permeability correlations, SPE/DOESociety of Petroleum Engineers, PO BoxRichardson, TX Presented at the SPE/DOE Enhanced Oil Recovery Symposium April 17– Introductions to Stone II three-phase relative permeability model and unconventional oil and gas resources; Discussions on low salinity water injection, saturated reservoirs and production trends of five reservoir fluids, impact of mud filtrate invasion and heavy organics on samples, and flow assurance problems due to solid components of petroleum.

This book enables petroleum reservoir engineers to predict the flow of fluids within a hydrocarbon deposit. Laboratory techniques are described for both steady-state and unsteady state measurements, and the calculation of relative permeability from field data is illustrated.

Using this data set, we derived a set of empirical relations that relate NAPL three‐phase relative permeability k rn to NAPL saturation S n and spreading coefficient C s for S n less than aboutsuch that k rn = where A 1 = exp (−C s) and A 2 = − C s + C s 2.

At higher S n, k rn ≈ S n 4, independent of C s. Laboratory Measurement of Relative Permeability Three-Phase Relative Permeability Summary End of Chapter Questions Data Integration and Volumetric Estimation of Hydrocarbons Estimation of Hydrocarbons in Place Data Integration and Uncertainty Summary End of Chapter Questions References.

Book Summary. Try the new Google Books. Check out the new look and enjoy easier access to your favorite features sandstone saturation measurements shown in Figure steady-state strongly water-wet surface technique Technol three-phase flow three-phase relative permeability Trans two-phase flow unconsolidated sand unsteady-state viscosity viscosity ratio.

Simulations were run with and without hysteresis for different three phase relative permeability models with different effects observed for the recovery factor. The results of this work show that a good understanding of the three phase relative permeability model in use is very important for a more robust reservoir simulation model.

The relative permeability of water-wet rocks for both two- and three-phase systems, with the saturation change in the imbibition direction, may be obtained by this method after properly selecting two rock properties: the residual nonwetting-phase saturation after. This book enables petroleum reservoir engineers to predict the flow of fluids within a hydrocarbon deposit.

Laboratory techniques are described for both steady-state and unsteady state measurements, and the calculation of relative permeability from field data is illustrated. In this study, a Pore Network (PN) tool was developed in order to obtain two and three phase relative permeability values.

It has been found that the observed results agree with published data. In this case, three-phase relative permeabilities must be considered; however, no general method has been established for three-phase relative permeability measurements.

Methods for the determination of relative permeabilities for two phases have been well established.In this paper we present a series of three-phase relative permeability obtained from core flood experiments of WAG injection into a water wet and a mixed wet core using a very low IFT oil/gas system.

The objective of this study was to investigate hysteresis behaviour in WAG process under with different rock wettability conditions.Relative permeability and capillary pressure curves Direct measurement of three-phase relative permeabil-ities is di cult and time consuming; hence, empirical models are widely used [27].

A comprehensive descrip-tion of the available correlations for the three-phase relative permeabilities along with their shortcomings.