An Approximate Theory of Oil/Water Coning

1985 ◽  
Author(s):  
M.J. Wheatley
Keyword(s):  
Approximate Theory ◽  
Water Coning ◽  
Oil Water

scholarly journals Extraction of density-layered fluid from a porous medium

2020 ◽  
Vol 61 ◽  
pp. C137-C151
Author(s):  
Jyothi Jose ◽  
Graeme Hocking ◽  
Duncan Farrow
Keyword(s):  
Porous Media ◽  
Finite Difference ◽  
Finite Difference Method ◽  
Difference Method ◽  
Axisymmetric Flow ◽  
Density Stratification ◽  
Comsol Multiphysics ◽  
Approximate Theory ◽  
Hodograph Method ◽  
Water Coning

We consider axisymmetric flow towards a point sink from a stratified fluid in a vertically confined aquifer. We present two approaches to solve the equations of flow for the linear density gradient case. Firstly, a series method results in an eigenfunction expansion in Whittaker functions. The second method is a simple finite difference method. Comparison of the two methods verifies the finite difference method is accurate, so that more complicated nonlinear, density stratification can be considered. Such nonlinear profiles cannot be considered with the eigenfunction approach. Interesting results for the case where the density stratification changes from linear to almost two-layer are presented, showing that in the nonlinear case there are certain values of flow rate for which a steady solution does not occur. References Abramowitz, M. and Stegun, I. A., Handbook of Mathematical Functions, 9th ed. National Bureau of Standards, Washington, 1972. Bear, J. and Dagan, G. Some exact solutions of interface problems by means of the hodograph method. J. Geophys. Res. 69(8):1563–1572, 1964. doi:10.1029/JZ069i008p01563 Bear, J. Dynamics of fluids in porous media. Elsevier, New York, 1972. https://store.doverpublications.com/0486656756.html COMSOL Multiphysics. COMSOL Multiphysics Programming Reference Manual, version 5.3. https://doc.comsol.com/5.3/doc/com.comsol.help.comsol/COMSOL_ProgrammingReferenceManual.pdf Farrow, D. E. and Hocking, G. C. A numerical model for withdrawal from a two layer fluid. J. Fluid Mech. 549:141–157, 2006. doi:10.1017/S0022112005007561 Henderson, N., Flores, E., Sampaio, M., Freitas, L. and Platt, G. M. Supercritical fluid flow in porous media: modelling and simulation. Chem. Eng. Sci. 60:1797–1808, 2005. doi:10.1016/j.ces.2004.11.012 Lucas, S. K., Blake, J. R. and Kucera, A. A boundary-integral method applied to water coning in oil reservoirs. ANZIAM J. 32(3):261–283, 1991. doi:10.1017/S0334270000006858 Meyer, H. I. and Garder, A. O. Mechanics of two immiscible fluids in porous media. J. Appl. Phys., 25:1400–1406, 1954. doi:10.1063/1.1721576 Muskat, M. and Wycokoff, R. D. An approximate theory of water coning in oil production. Trans. AIME 114:144–163, 1935. doi:10.2118/935144-G GNU Octave. https://www.gnu.org/software/octave/doc/v4.2.1/ Yih, C. S. On steady stratified flows in porous media. Quart. J. Appl. Maths. 40(2):219–230, 1982. doi:10.1090/qam/666676 Yu, D., Jackson, K. and Harmon, T. C. Disperson and diffusion in porous media under supercritical conditions. Chem. Eng. Sci. 54:357–367, 1999. doi:10.1016/S0009-2509(98)00271-1 Zhang, H. and Hocking, G. C. Axisymmetric flow in an oil reservoir of finite depth caused by a point sink above an oil-water interface. J. Eng. Math. 32:365–376, 1997. doi:10.1023/A:1004227232732 Zhang, H., Hocking, G. C. and Seymour, B. Critical and supercritical withdrawal from a two-layer fluid through a line sink in a bounded aquifer. Adv. Water Res. 32:1703–1710, 2009. doi:10.1016/j.advwatres.2009.09.002 Zill, D. G. and Wright, W. S. Differential Equations with Boundary-value problems, 8th Edition. Brooks Cole, Boston USA, 2013.

An Approximate Theory of Water-coning in Oil Production

1935 ◽  
Vol 114 (01) ◽  
pp. 144-163 ◽  
Author(s):  
M. Muskat ◽  
R.D. Wycokoff
Keyword(s):  
Oil Production ◽  
Approximate Theory ◽  
Water Coning

scholarly journals FILTRATION MODEL OF OIL CONING IN A BOTTOM WATER-DRIVE RESERVOIR

2018 ◽  
Vol 15 (30) ◽  
pp. 725-733
Author(s):  
R. F. YAKUPOV ◽  
V. S. MUKHAMETSHIN ◽  
K. T. TYNCHEROV
Keyword(s):  
Hydrodynamic Model ◽  
Bottom Water ◽  
Water Contact ◽  
Hydrodynamic Simulation ◽  
Water Coning ◽  
Oil Water ◽  
Filtration Modeling ◽  
Water Saturated ◽  
Successive Method ◽  
Filtration Model

The purpose of the paper is the substantiation of the application of the oil coning technology in the process of the hydrodynamic simulation of the successive method, which includes the perforation of the casing below the level of oil-water contact; the drawing of water from the lower water-saturated part of the reservoir; the isolation of this perforation interval; the drilling-in of the near-caprock oil-saturated part of the reservoir and the production of near-caprock oil. The leading approach to the research of this problem is the method of filtration modeling of the oil and water coning processes in the reservoir. As a result of the study, a hydrodynamic model of a well has been created, which corresponds to the requirements of the visualization of the process, the authenticity and the possibility to control the necessary parameters of the model and to estimate the effectiveness of the technology.

A Simplified Semi-Analytical Model for Water-Coning Control in Oil Wells With Dual Completions System

2002 ◽  
Vol 124 (4) ◽  
pp. 246-252 ◽  
Author(s):  
Jakub Siemek ◽  
Jerzy Stopa
Keyword(s):  
Water Flow Rate ◽  
Water Contact ◽  
Numerical Investigations ◽  
Well Completion ◽  
In Situ Separation ◽  
Water Coning ◽  
Bottom Waters ◽  
Oil Water ◽  
Flow Simulator

In this paper, a mathematical model and numerical investigations on dynamic water/oil contact (WOC) in a reservoir with active bottom waters are addressed. An original analytical solution describing the theoretical shape of the dynamic oil-water contact in the reservoir is presented and compared with some results of numerical simulations made by a commercial flow-simulator. It is shown that both water and oil may be produced simultaneously but selectively from their respective zones. This allows a theoretical control of the dynamic WOC by the water flow rate. Consequently, an increased amount of oil can be produced along with water, depending on the well completion interval in relation to the oil/water contact in the reservoir. This shows the possibility of an “in situ” separation concept. The advantage of such a separate production of water and oil is to prevent the mixing oil with water within the pump and tubing.

A Model of Oil-Water Coning for Two-Dimensional, Areal Reservoir Simulation

1976 ◽  
Vol 16 (02) ◽  
pp. 65-72 ◽  
Author(s):  
J.E. Chappelear ◽  
G.J. Hirasaki
Keyword(s):  
Finite Difference ◽  
Flow Resistance ◽  
Bottom Water ◽  
Effective Radius ◽  
Vertical Equilibrium ◽  
Well Model ◽  
Water Coning ◽  
Partial Completion ◽  
Oil Water ◽  
Reservoir Simulator

Abstract A model for oil-water coning in a partially perforated well has been developed and tested by perforated well has been developed and tested by comparison with numerical simulations. The effect of oil-water coning, including down-coning of oil, on field production is demonstrated by studying a small water drive reservoir whose complete production data arc known. production data arc known.The coning model is derived by assuming vertical equilibrium and segregated flow. A necessary correction for departure from vertical equilibrium in the immediate neighborhood of the well is developed The coning model is suitable for single-well studies or for inclusion in a reservoir simulator for two-dimensional, areal studies. Introduction The objective of this investigation of oil-water coning was to develop tools to evaluate operational problems for reservoirs with bottom water. Although problems for reservoirs with bottom water. Although any specific question can be answered (a least in principle) by finite-difference simulation, a practical principle) by finite-difference simulation, a practical problem occurs. Great detail may be necessary for problem occurs. Great detail may be necessary for a reservoir-wide simulation of problems involving coning. Two approaches are possible. One can use more accurate finite-difference equations (such as those derived by some type of Galerkin procedure) to solve the problem of insufficient accuracy. Or one can include in his simulator a "well model" that accurately predicts coning on the basis of near-well properties. The well model could be either another finite-difference subsystem or a formula theoretical or empirical (or both) in character. Our approach is to develop a theoretical model that can be installed in a finite-difference reservoir simulator. We feel that such a model, particularly if it is simple and widely applicable, has several advantages:(1)the assumptions made in the derivation aid in understanding coning;(2)the formula guides the engineer by indicating significant parameters and their relationships;(3)the existence parameters and their relationships;(3)the existence of a simple formula permits preliminary studies without a full simulation; and(4)the simple formula is easy to install in a reservoir simulator. This model for oil-water coning differs from others presented previously in two respects. First, presented previously in two respects. First, partial completion that does not necessarily extend partial completion that does not necessarily extend to the top of the formation is treated. Second, an effective radius that allows for vertical flow resistance is introduced. DESCRIPTION OF MODEL ASSUMPTIONS The geometric configuration for the coning model is a radially symmetric, homogeneous, anisotropic system with inflow at the outer boundary and with a partially perforated well. The fluid distribution is shown in Fig. 1. The presence of initial bottom water at 100-percent water saturation is considered. The perforated interval is assumed to be within the original oil column. The fluids are assumed to be incompressible. The model will be developed in steady-state flow. It is shown in Ref. 6 that the transient time for the start of flow is short for most practical problems and, thus, the rise of the cone can be represented as a succession of steady states. The fluids are assumed to flow in segregated regions, as shown in Fig. 1. The fractional flow into the perforated interval is assumed to be only a function of the fraction of the interval covered by each fluid and of the mobility ratio. The fluids are assumed to be in vertical equilibrium everywhere except near the wellbore. The departure from vertical equilibrium near the well caused by the vertical flow resistance is represented by an "effective radius." The expression for the effective radius represents the anisotropy through the vertical-to-horizontal permeability ratio. permeability ratio.The fluid flow equations are linearized by assuming that the average oil-column thickness over the drainage area can be used to compute the vertically averaged relative-permeability functions for the entire drainage area. SPEJ P. 65

Oil, Water, and Climate

2001 ◽  
Author(s):  
Catherine Gautier
Keyword(s):  
Oil Water

Porous materials from cellulose nanocrystal and mxene surfactants at the oil/water interface

2020 ◽  
Author(s):  
Bingqing qian ◽  
Haiqiao Wang ◽  
Dong Wang ◽  
Hao-Bin Zhang ◽  
Jessica Wu ◽  
...  
Keyword(s):  
Porous Materials ◽  
Cellulose Nanocrystal ◽  
Water Interface ◽  
Oil Water
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