Digital Core Analysis &amp;ndash; Innovative Approach for EOR Agent Screening at Pore-Scale for Achimov Rocks (Russian)

Yakimchuk, Ivan; Evseev, Nikolay; Korobkov, Dmitry V.; Dinariev, O. Yu.; Ridzel, Olga; Khan, Vladimir; Semkov, Vyacheslav; Zhonin, Alexander; Kravets, Dmitry

doi:10.2118/202015-ru

Cited by 8 publications

(2 citation statements)

References 15 publications

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“…As the first step in numerical simulation on the DRM, we have modeled initial saturation of the reservoir gas and connate water (Fig. 3) by solving a full thermodynamic equilibrium problem (global minimum of Helmholtz free energy) following the methodology described in [25]. Spatial distribution of wettability was established by surface Helmholtz energy density field ( * f ) with correlated stochastic noise representing expected natural variability in rock surface properties.…”

Section: Numerical Resultsmentioning

confidence: 99%

“…In previous publications it has been demonstrated that various multiphase compositional problems can be modeled in the frame of the density functional hydrodynamics (DFH) [7][8][9][10][11][12][13][14][15][16][17], including practical digital rock applications [18][19][20][21][22][23][24][25][26]. In the present work we discuss the pore-scale modeling of gas-condensate mixtures in digital rock models obtained by X-ray microCT.…”

Section: Introductionmentioning

confidence: 99%

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The Problem of Stability of Gas-Condensate Mixture at Pore-Scale: The Study by Density Functional Hydrodynamics

Dinariev

Evseev²,

Klemin³

2023

E3S Web Conf.

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The method of the density functional hydrodynamics (DFH) is used to model compositional gas-condensate systems in natural cores at pore-scale. In previous publications, it has been demonstrated by the authors that DFH covers many diverse multiphase pore-scale phenomena, including fluid transport in RCA and SCAL measurements and complex EOR processes. The pore-scale modeling of multiphase flow scenarios is performed by means of the direct hydrodynamic (DHD) simulator, which is a numerical implementation of the DFH. In the present work, we consider the problem of pore-scale numerical modeling of three-phase system: residual water, hydrocarbon gas and hydrocarbon liquid with phase transitions between the two latter phases. Such situations happen in case of gas-condensate or volatile oil deposits, in oil deposits with gas caps or in EOR methods with gas injection. The corresponding field development modeling by the conventional reservoir simulators rely on phase permeabilities and capillary pressures, which are provided by laboratory core analysis experiments. But the problem with gas-liquid hydrocarbon mixtures is that in laboratory procedures it may be difficult or even impossible to achieve full thermodynamic equilibrium between phases as it must be under the reservoir conditions of the initial reservoir state. However, reaching the said equilibrium is quite possible in numerical simulation. In this work, the gas-liquid mixture, after being injected into core sample, would slowly undergo the rearrangement of the phases and chemical components in pores converging to the minimum of the Helmholtz energy functional. This process is adequately described by DFH with consequent impact on phase permeabilities and capillary pressure. We give pore-scale numerical examples of the described phenomena in a micro-CT porous rock model for a realistic gas-condensate mixture with quantitative characterization of phase transition kinetic effects.

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Section: Numerical Resultsmentioning

confidence: 99%