Refining of the Permeability Cube of Geological-Hydrodynamic Models  Under Conditions of Various Volumes of Initial Data

Kozyrev, Nikita; Менгалиев, Александр Генрихович; Kochnev, Alexander; Krivoshchekov, Sergey

doi:10.33285/2413-5011-2021-5(353)-24-29

Cited by 2 publications

(2 citation statements)

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“…There are various approaches to factoring in permeability anisotropy, as well [30,31]. For example, the works [32,33] offer well test analysis. The relationship between permeability and well-log curves parameters is closely studied.…”

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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“…В свою очередь К ов определялся на основе исследований керна через зависимость от коэффициента пористости К ов =f(К п ) [1,2]. Согласно современным представлениям в условиях гидрофильных коллекторов в зависимости от их неоднородности и проницаемости Н усв может изме-няться в широких пределах [3], для залежей Пермского региона часто превышая 5-10 м. С учетом этого достоверное определение переходных или недонасыщенных зон в совокупности с распределением К н в 3D-модели залежи имеют определяющее значение при проведении геолого-технологического моделирования [4,5].…”

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3d-Modeling Technology of Initial Oil Saturation in Transitional Oil-Water Zone by Complex of Capillarimetry and Electric Logging Methods

Potekhin,

Shiryaev,

Galkin

2023

IZVESTIYA

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Link for citation: Potekhin D.V., Shiryaev E.O., Galkin S.V. 3D-modeling technology of initial oil saturation in transitional oil-water zone by complex of capillarimetry and electric logging methods. Bulletin of the Tomsk Polytechnic University. Geo Аssets Engineering, 2023, vol. 334, no. 10, рр. 98-107. In Rus. The relevance. The 3D distribution of the initial oil saturation in the reservoir volume is one of the key elements of geological and technological modeling, largely determining the quality of subsequent development design solutions. The publication presents an analysis of the current state of the problem of studying the oil-water transition zone and the distribution of oil saturation. For terrigenous hydrophilic reservoirs, electric lateral logging quite reliably controls the fluid saturation of the void space of the oil part of the deposit, which suggests the possibility of its integration with widely used capillarimetry methods. Aim: to evaluate the possibility of reliably determining the oil saturation of terrigenous hydrophilic reservoirs by combining the data of electrical lateral logging, filtration-capacitance properties of reservoirs and capillarimetric core studies, to build a 3D model of the distribution of the initial oil saturation of reservoirs in oil deposits, taking into account the allocation of the oil-water transition zone. Object: oil-saturated reservoirs of the Visean oil deposits of the Perm region. Method: methods of multidimensional mathematical modeling in the development of a methodology for determining the initial oil saturation of reservoirs based on a complex of well logging and capillarimetric studies of the core, construction of 3D distribution of the initial oil saturation of the reservoir, taking into account the parameters of the oil-water transition zone. Results. The authors, based on the developed methodology for the deposit of the reservoir Bb of the Aspinskoe field, built a 3D model of the distribution of the initial oil saturation. For the studied reservoir, they carried out the analysis of distribution of zones of free saturation, undersaturation, transition zone and limiting oil saturation. The resulting 3D model can be used in geological and technological modeling of the development of an oil deposit.

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Refining of the Permeability Cube of Geological-Hydrodynamic Models Under Conditions of Various Volumes of Initial Data

Cited by 2 publications

References 0 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

3d-Modeling Technology of Initial Oil Saturation in Transitional Oil-Water Zone by Complex of Capillarimetry and Electric Logging Methods

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