Flow Simulation of Geologic Models

King, Micháel J.; Mansfield, Mark

doi:10.2523/38877-ms

Cited by 18 publications

(13 citation statements)

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“…The worst method here is the use of linear pressure gradient boundary conditions, which significantly overestimates the flow rate. This is in contrast to previously reported studies 22 . Both no-flow boundary conditions and arithmetic-harmonic averaging give good predictions.…”

Section: Upscaled Solutionscontrasting

confidence: 99%

Tenth SPE Comparative Solution Project: A Comparison of Upscaling Techniques

Christie¹,

Blunt

2001

SPE Reservoir Simulation Symposium

451

243

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper presents the results of the Tenth SPE Comparative Solution Project on Upscaling. Two problems were chosen. The first problem was a small 2D gas injection problem, chosen so that the fine grid could be computed easily, and both upscaling and pseudoisation methods could be used. The second problem was a waterflood of a large geostatistical model chosen so that it was hard (though not impossible) to compute the true fine grid solution. Nine participants provided results for one or both problems.

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Section: Upscaled Solutionscontrasting

confidence: 99%

Tenth SPE Comparative Solution Project: A Comparison of Upscaling Techniques

Christie¹,

Blunt

2001

SPE Reservoir Simulation Symposium

451

243

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“…1a). We do not attempt to predict exactly the behavior of a given geologic reservoir or multiphase flow system; rather, our objectives are to predict where and how viscous crossflow affects the displacement of one fluid phase by another, as a function of a small number of key dimensionless numbers, in order to support mechanistic interpretations of more complex numerical model predictions, regardless of length scale (e.g., King and Mansfield 1999).…”

Section: Introductionmentioning

confidence: 99%

Viscous Crossflow in Layered Porous Media

et al. 2017

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We examine the effect of viscous forces on the displacement of one fluid by a second, immiscible fluid along parallel layers of contrasting porosity, absolute permeability and relative permeability. Flow is characterized using five dimensionless numbers and the dimensionless storage efficiency, so results are directly applicable, regardless of scale, to geologic carbon storage. The storage efficiency is numerically equivalent to the recovery efficiency, applicable to hydrocarbon production. We quantify the shock-front velocities at the leading edge of the displacing phase using asymptotic flow solutions obtained in the limits of no crossflow and equilibrium crossflow. The shock-front velocities can be used to identify a fast layer and a slow layer, although in some cases the shock-front velocities are identical even though the layers have contrasting properties. Three crossflow regimes are identified and defined with respect to the fast and slow shock-front mobility ratios, using both theoretical predictions and confirmation from numerical flow simulations. Previous studies have identified only two crossflow regimes. Contrasts in porosity and relative permeability exert a significant influence on contrasts in the shock-front velocities and on storage efficiency, in addition to previously examined contrasts in absolute permeability. Previous studies concluded that the maximum storage efficiency is obtained for unit permeability ratio; this is true only if there are no contrasts in porosity and relative permeability. The impact of crossflow on storage efficiency depends on the mobility ratio evaluated across the fast shock-front and on the time at which the efficiency is measured.

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“…Other authors start out with a mathematical derivation and define a WI built on the numerical factor 0.14 (see Ref. 7). Assuming an orthogonal, boxshaped reservoir, Babu and Odeh et al 8,9 use separation of variables and Green's functions to compute a WI.…”

Section: Introductionmentioning

confidence: 99%

Well Index in Reservoir Simulation for Slanted and Slightly Curved Wells in 3D Grids

Aavatsmark

Klausen

2003

SPE Journal

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A new, accurate method for computing the well index (WI) for a well that is oriented in an arbitrary direction in a 3D grid is presented. The method is simple and seminumerical and takes well direction and neighboring gridblocks into account. It is assumed that the medium is homogeneous. The method can be applied for any grid or discretization. However, only Cartesian grids with a seven-point stencil are used here. Properties of the seminumerical WI are investigated for both synthetic and field examples. The investigated properties are convergence rate and dependency on well direction, well location, grid geometry, and anisotropy. The new method shows the importance of taking the neighboring gridblocks into account. Seminumerical Well IndexThe problem of finding the WI is one of finding a relation between the well pressure, the well rate and the discrete pressure value from a numerical simulation for the entire gridblock. A typical well radius is about 10 cm, while one numerical pressure value for a gridblock typically represents a volume of 100×100×1 m 3 . The well represents a sink (or source) for the pressure distribution. This means that in the wellblock there will be a huge variation in the real pressure. An illustration is given in Fig.

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Flow Simulation of Geologic Models

Cited by 18 publications

References 0 publications

Tenth SPE Comparative Solution Project: A Comparison of Upscaling Techniques

Tenth SPE Comparative Solution Project: A Comparison of Upscaling Techniques

Viscous Crossflow in Layered Porous Media

Well Index in Reservoir Simulation for Slanted and Slightly Curved Wells in 3D Grids

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