Characterization of the reservoir property time-variation based on ‘surface flux’ and simulator development

Jiang, Rui; Zhang, Wei; Zhao, Pingqi; Jiang, Yu; Tao, Ziqiang; Zhao, Ming; Ni, Tianlu; Xu, Jianchun; Cui, Yongzheng; Hua, Jing

doi:10.1016/j.fuel.2018.06.136

Cited by 11 publications

(3 citation statements)

References 11 publications

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“…Due to the long-term large-scale development of conventional oil and gas resources, it is increasingly difficult to increase reserves and production. However, the global unconventional gas and oil resources are abundant [1] . Oil and gas from tight shale reservoirs are often extracted using hydraulic fracturing.…”

Section: Introductionmentioning

confidence: 99%

Numerical Simulation of Oil-Water Two-phase Conductivity in Hydraulic Fracturing Considering Proppant Crushing

Chen

Wang

Yang

2023

J. Phys.: Conf. Ser.

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Hydraulic fracturing can effectively increase reservoir productivity, and the effect depends on proppant behavior. Crushing of proppant during fracturing induces a series of changes in fracture width and the pore space formed between proppant particles, affecting reservoir fluid flow. For exploring the flow law of oil and water in proppant fractures, the discrete element method (DEM) and Tavares crushing model were combined to simulate the proppant crush process. At the same time, based on the formed pore space, the flow law of two phase fluid under the influence of such factors as the number of proppant placement, combination of particle size, closing pressure, and particle wettability was studied by fluid volume method(VOF). A series of data obtained through simulation show that with the increase of the average particle radius of single-layer and multilayer proppant is, the fracture conductivity and fracture width increase at the same closure pressure,. In the pore space formed by surface water-wet proppant, the ability of pore to transport oil phase increases; the higher of the number of closure pressure is, the larger the ability of pore to transport oil phase is.

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Section: Introductionmentioning

confidence: 99%

Numerical Simulation of Oil-Water Two-phase Conductivity in Hydraulic Fracturing Considering Proppant Crushing

Chen

Wang

Yang

2023

J. Phys.: Conf. Ser.

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“…Deeply understanding the seepage law of oil, gas, and water in reservoir porous media and the time-varying law of rock porous is the basis for improving the accuracy of reservoir numerical simulators, which has been widely studied by scholars in recent years (Xu et al, 2012;Jiang et al, 2018;Shen et al, 2019;Sun et al, 2019;Rios et al, 2020;Qiao, 2021).…”

Section: Introductionmentioning

confidence: 99%

The numerical simulation study on the dynamic variation of residual oil with water drive velocity in water flooding reservoir

Sun¹,

Liu²,

Cai³

et al. 2023

Front. Energy Res.

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The results of core displacement experiments show that increasing the water drive velocity when it is bigger than the limit value can effectively reduce the residual oil saturation and improve the oil displacement efficiency under the same PV. However, the existing commercial simulators (Eclipse, CMG et al.) cannot simulate the effect of water velocity on the relative permeability curve in the process of numerical simulation.In this article, capillary number (Ca), defined as the dimensionless ratio of viscous force to capillary force, is used to characterize the relationship between water drive velocity and residual oil. Second, a new Boltzmann (BG) equation is proposed to match the nonlinear relationship between Ca and residual oil. The BG equation is a continuous function, which is very beneficial to the stability of numerical calculation. Finally, a new reservoir numerical simulator is established which captures the dynamic variation of residual oil saturation with water drive velocity in a water flooding reservoir based on the black oil model. The new simulator was verified by comparing it with the commercial reservoir simulator ECLIPSE and experimental data. The simulation results show that compared with the common model, the model considering the dynamic variation of residual oil saturation with water drive velocity reduced the residual oil saturation near the main flow line after enhanced injection rate. The oil phase flow capacity in the model is enhanced, the water cut is decreased, and the oil recovery rate is higher. The history matching of the S oilfield in Bohai Bay is achieved with the new simulator, and the history matching accuracy is obviously higher than that of Eclipse. The findings of this study can help with a better understanding of the distribution law and flow law of remaining oil in the high water cut stage of the reservoir and have good theory and application value for water flooding offshore oilfields.

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“…The pore structure and permeability variations should be comprehensively addressed so as to get a better understanding of them. However, the research to date mostly concentrates on the macroscopic time-dependent porosity and permeability evolution in core and field scale including physical and numerical simulation [16][17][18], especially for oil reservoirs [19][20][21][22]. And the macroscopic investigation will not provide a revealing insight into the microscope evolution.…”

Section: Introductionmentioning

confidence: 99%

Pore Structure and Permeability Variations during Gas Displacement in Unconsolidated Sandstone Reservoirs through CT Reconstruction Analysis

Zha¹,

Bao²,

Li³

et al. 2023

Geofluids

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The continuous gas displacement in unconsolidated sandstone gas reservoirs will necessarily result in the pore structure and rock permeability variations, which cannot be neglected in the gas development process. However, the variations have not been comprehensively addressed yet, especially for the rock structure in pore scale. This work presented the quantitative results of pore structure in microscale and permeability variations during gas displacement in unconsolidated sandstone reservoirs through computed tomography (CT) reconstruction analysis. The results indicated that a more than 3% increase in porosity after gas displacement resulted from the enlargement of the pore and throat with a diameter of more than 20 μm and 3 μm, respectively, owing to the release and migration of clay and fine particles, in spite of the distribution frequency decline of both pore and throat with a small diameter. The pore connectivity would be enhanced by the increase of the connected pores as well as the enlargement of the pore and throat sizes. However, the pore-throat coordination number could only change with slight improvement. In terms of permeability and relative permeability changes with pore structure, the improvement of permeability after gas displacement was higher than that of porosity, and the continuous gas displacement would broaden gas-water flow region and lower irreducible water saturation and residual gas saturation, and then, the equal phase relative permeability point would shift to the right. These investigations will contribute to more accurate reserve evaluation and productivity prediction.

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Characterization of the reservoir property time-variation based on ‘surface flux’ and simulator development

Cited by 11 publications

References 11 publications

Numerical Simulation of Oil-Water Two-phase Conductivity in Hydraulic Fracturing Considering Proppant Crushing

Numerical Simulation of Oil-Water Two-phase Conductivity in Hydraulic Fracturing Considering Proppant Crushing

The numerical simulation study on the dynamic variation of residual oil with water drive velocity in water flooding reservoir

Pore Structure and Permeability Variations during Gas Displacement in Unconsolidated Sandstone Reservoirs through CT Reconstruction Analysis

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