In-Situ Determination of Displacement Efficiency and Oil and Water Relative Permeability Curves through Integrated Well Test Study at Exploration-to-Pilot Stage of the Oilfield Development Project

Zakirov, S. N.; Indrupskiy, I. M.; Zakirov, E. S.; Anikeev, D.P.; Vasilyev, I. V.; Tsagan-Mandzhiev, T. N.; Afanasiev, V. S.; Afanasiev, S.; Antonovich, A. A.; Иванова, Е. А.

doi:10.2118/181967-ms

Cited by 3 publications

(3 citation statements)

References 6 publications

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“…Комплексный подход к оценке Квыт и кривых ОФП для нефти и воды в пластовых условиях развивается с 2001 г. специалистами ИПНГ РАН [5]. Он включает комбинацию специализированных двухфазных ГДИС с геофизическим контролем изменения насыщенности в околоскважинной зоне и анализом изменения минерализации водной фазы при смешении пластовой воды, закачиваемой воды и остаточных технологических растворов [6,7].…”

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“…Предшествующий опыт по отечественным объектам связан с обсаженными металлической колонной скважинами и применением импульсного нейтрон-нейтронного каротажа (ИННК) для контроля изменения водонасыщенности [5,7]. Для обеспечения информативности метода осуществлялась закачка минерализованных водных растворов.…”

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“…Для интерпретации результатов двухфазных ГДИС осуществляется решение обратной задачи с определением искомых характеристик пласта, включая функции ОФП для нефти и воды. В роли исходных данных для обратной задачи выступают замеренные на скважине динамики забойного давления, обводненности продукции, минерализации добываемой водной фазы [5,7]. Кроме того, используются оценки водонасыщенности околоскважинной зоны, полученные из выполненных контрольных записей каротажа.…”

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Simulation of resistivity logging during two-phase well testing

Шишкина¹,

Indrupskiy²,

Alekseeva³

et al. 2019

APOG

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Simulation of resistivity logging during two-phase well testing

Шишкина¹,

Indrupskiy²,

Alekseeva³

et al. 2019

APOG

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Simulation of Time-Lapse Resistivity Logging During Two-Phase Well Testing in Petroleum Reservoirs

Шишкина

Indrupskiy

Коваленко

et al. 2021

J. Phys.: Conf. Ser.

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Well testing methods are widely used in petroleum industry to identify reservoir parameters in-situ, at real reservoir flow conditions. Two-phase tests with water injection extend capabilities of well testing to evaluation of oil-water flow characteristics through the solution of an inverse problem based on well measurements during the test. Near-wellbore water saturation is used as one of the informative measured parameters. However, water saturation is actually not directly measured on wells. Instead, it is interpreted from time-lapse well logging data, with resistivity logging being one of the options. This means that forward and inverse problems are to be extended to incorporate direct simulations of resistivity logging. In this paper we address the forward problem. It is formulated and solved for different types of logging tools, both for open hole and through the casing. A numerical algorithm and software implementation have been developed for repeated solution of an axisymmetric forward problem of resistivity logging – a 2D elliptical partial differential equation for electrical potential. Distributions of formation resistivity at the moments of logging are calculated from distributions of water saturation and salinity. The latter are computed through numerical solution of the forward problem of well testing – a two-phase oil-water flow in the reservoir with changing salinity of the water phase, with full account for real fluid and reservoir properties. The software implementation of the resistivity logging problem has been tested in comparison with the known theoretical solutions. Examples are presented to show how time-lapse changes in resistivity logging data reflect the specifics of the two-phase flow with changing water salinity during the well test.

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About Identifiability of Oil and Water Relative Permeability Curves and Reservoir Heterogeneity through Integrated Well Test Study

Zakirov

Anikeev

Indrupskiy

et al. 2021

J. Phys.: Conf. Ser.

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Relative permeabilities (RP) play an important role in reservoir engineering. RP functions together with the permeability anisotropy coefficient predetermine waterflooding efficiency and oil/water ratio in production forecast. Traditionally multiphase flow parameters are estimated from core analysis data. But such measurements suffer from small representative elementary volume (REV) and limited characterization of reservoir properties. Therefore using core data in 3D reservoir modelling could lead to distorted description of actual flow conditions. Despite those functions (RP) could be history matched with assimilated production data, such a procedure would require long history of waterflooding. So the authors’ idea is to apply integrated well test study to estimate the displacement efficiency and/or relative permeability functions at downhole conditions. Well testing is traditionally applied in reservoir engineering for single-phase reservoir parameters estimation. Our approach is extended to multi-phase flow and is based on data collection at well bottomholes and subsequent data assimilation in flow model. In this paper we summarize both features of mathematical problem statement and identifiability of multiphase parameters through inverse problem solution, but also discuss 10+ -year experience in interpretation of two-phase well testing using our technologies. To estimate multiphase parameters, we have to jointly consider complex data of well logging and dynamic data of well testing. Both data sets are used in the inverse problem quality criteria, where the least squares method has been applied. Forward problem corresponds to a 3D multiphase fluid flow model in porous media. The latter consists of continuity equation with multiphase Darcy equation instead of moment balances. For data assimilation modern methods of optimal control theory were successfully applied. For all synthetic test cases real reservoir parameters were accurately recovered through the use of forward simulation data. In order to estimate reservoir heterogeneity, we applied a single-phase model to get the ratio of vertical to horizontal permeability. Data of well self-interference testing were used for vertical permeability estimation. Depending on the depth of reservoir pressure perturbation, reservoir properties could be properly inferred from observations. Two other options of 3D interference testing using vertical and horizontal wells are also presented. In other words, all the problems considered are identifiable, and the level of their correctness is completely predetermined by the amount and quality of observed data. And transition to digital (intelligent) oil-and-gas production and closed-loop reservoir management [1] provides a possibility to remove discussed restrictions and all inverse problems considered should be accounted as fully identifiable.

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In-Situ Determination of Displacement Efficiency and Oil and Water Relative Permeability Curves through Integrated Well Test Study at Exploration-to-Pilot Stage of the Oilfield Development Project

Cited by 3 publications

References 6 publications

Simulation of resistivity logging during two-phase well testing

Simulation of resistivity logging during two-phase well testing

Simulation of Time-Lapse Resistivity Logging During Two-Phase Well Testing in Petroleum Reservoirs

About Identifiability of Oil and Water Relative Permeability Curves and Reservoir Heterogeneity through Integrated Well Test Study

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