The study of relative phase-permeability functions for anisotropic media

Pergament, A. Kh.; Tomin, Pavel

doi:10.1134/s2070048212010097

Cited by 7 publications

(1 citation statement)

References 26 publications

(47 reference statements)

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“…Allowing for reservoir heterogeneity, it should be understood that fluid flow varies in different reservoir zones [40]. Therefore, the phase permeability curves will be shaped differently [41][42][43].…”

Section: Introductionmentioning

confidence: 99%

Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy

Krivoshchekov¹,

Kochnev²,

Kozyrev³

et al. 2022

Energies

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Current methods of oil and gas field development design rely on reservoir simulation modeling. A reservoir simulation model is a tool to reproduce field development processes and forecast production data. Reservoir permeability is one of the basic properties that determines fluid flow. From existing approaches, the porosity and permeability values should be consistent with petrophysical correlations obtained from core sample tests in the course of development of an absolute permeability cube in the reservoir simulation model. For carbonate reservoirs with complex pore space structure and fractures, the petrophysical correlations are often unstable. To factor in the fluid flow in a fractured rock system, dual-medium models are developed, allowing for matrix and fracture components. Yet in this case, the degree of uncertainty only increases with the introduction of a new parameter: a cross-flow index of fluid migration from matrix to fracture, which is only determined indirectly by results of fluid flow studies conducted in the initial development period, and therefore most often is adaptive. Clearly, for well-studied fields there is an extensive data pool drawn on research findings: core studies, well logging, well flow testing, flowmetry, special well-logging methods (FMI, Sonic Scanner, etc.); the dual-medium model development for such reservoirs is fairly well-founded and supported by actual studies. However, at the start of the field development, the data are incomplete, which renders qualitative dual-medium modeling impossible. This paper proposes an approach to factor in the target’s permeability anisotropy at an early development stage through the integration of well, core and 3D seismic surveys. The reservoir was classified into pore space types, to which different petrophysical correlations were assigned to develop a permeability array, and relative phase permeabilities were studied. The fluid flow model was history-matched with allowance for permeability anisotropy and rock types. Comparative calculations were conducted on the resulting model to select the optimum development strategy for the target.

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Section: Introductionmentioning

confidence: 99%

Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy

Krivoshchekov¹,

Kochnev²,

Kozyrev³

et al. 2022

Energies

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Asymptotic Analysis of the Inflow to a Fracture in an Oil–Gas Reservoir with Bottom Water

Kanevskaya,

Kuznetsov,

Ryzhova

2024

Fluid Dyn

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Characterization and Analysis of Anisotropic Relative Permeability

Pei

Liu

Gu³

et al. 2021

SPE Journal

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Summary The relative permeability functions of two-phase reservoirs are extensively used in modern reservoir-engineering theories for calculations and numerical simulations. In recent years, the theory of anisotropic reservoir development has advanced rapidly, and the anisotropic absolute permeability of reservoirs has been characterized and applied accurately. However, if only the anisotropy of absolute permeability is considered while neglecting the anisotropy of relative permeability, the effective permeability used in the calculations will differ significantly from that of an actual reservoir. In this study, an anisotropy experiment on two-phase relative permeability, with oil and water, was conducted using natural sandstone without fractures, which demonstrated the existence of anisotropy in relative permeability and analyzed its mechanism. The properties and calculation methods for anisotropic relative permeability were studied under the symmetry groups of a rhombic system. Numerical simulations of the reservoir considering anisotropic relative permeability were performed. The results demonstrated that the anisotropic relative permeability significantly affected the development of the oil reservoir, which is primarily indicated by the significant difference in the seepage direction of oil and water, and the complicated oil/water distribution. The results of this study differed significantly from the conventional understanding of remaining oil distribution. The deformed well pattern established for the anisotropy of the absolute permeability indicated a decrease in the oil-recoveryratio.

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The study of relative phase-permeability functions for anisotropic media

Cited by 7 publications

References 26 publications

Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy

Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy

Asymptotic Analysis of the Inflow to a Fracture in an Oil–Gas Reservoir with Bottom Water

Characterization and Analysis of Anisotropic Relative Permeability

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