Effects of microstructural and petrophysical properties on spontaneous imbibition in tight sandstone reservoirs

Xia, Yuxuan; Tian, Zhenhua; Xu, Sai; Wei, Wei; Cai, Jianchao

doi:10.1016/j.jngse.2021.104225

Cited by 27 publications

(8 citation statements)

References 40 publications

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“…These factors include not only the physical properties of the reservoir itself, such as porosity, permeability, mineral composition, etc., but also external conditions such as temperature, pressure, fluid properties, etc. , The comprehensive effect of these factors determines the flow and absorption behavior of fracturing fluid in tight sandstone, thus affecting the imbibition effect. For example, Liu et al , considered that adsorption thickness and pore throat connectivity are the key factors affecting matrix permeability and spontaneous imbibition displacement efficiency. The difference in the imbibition methods determines the degree of influence of permeability on the imbibition rate.…”

Section: Introductionmentioning

confidence: 99%

Imbibition Characteristics and Influencing Factors of the Fracturing Fluid in a Tight Sandstone Reservoir

Li,

Ren,

Sun

et al. 2024

ACS Omega

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The strong reservoir heterogeneity and complex microscopic pore structure in the Linxing area make it prone to water block damage during imbibition development. In order to explore the influence of reservoir microscopic characteristics on imbibition efficiency, taking the tight sandstone gas reservoir in the Linxing area of Ordos Basin as an example, the heterogeneity of the tight sandstone reservoir in the study area is characterized in terms of physical and chemical characteristics as well as the microscopic pore structure. Using nuclear magnetic resonance, high-pressure mercury pressure, and other testing methods, spontaneous seepage experiments in real sandstone were carried out to study the distribution law of different pore structures and seepage characteristics at different times and to systematically evaluate the microscopic pore characteristics of dense sandstone reservoirs and the factors affecting seepage and suction. The results show that due to the strong microscopic heterogeneity of tight sandstone, the macroscopic properties cannot directly reflect the microscopic characteristics, and the response to imbibition efficiency is stronger. The pore size is the main controlling factor affecting imbibition, and the contribution rate of the micropore and mesopore mainstream pore size spaces is higher than that of the macropore. Micropores provide imbibition power, and mesopores provide an imbibition interval. High-porosity and high permeability reservoirs are more conducive to imbibition replacement. The intercrystalline pores have a great influence on the imbibition efficiency, and the influence of intergranular pores and dissolution pores on the imbibition cannot be underestimated. The smaller the relative sorting coefficient, interfacial tension, and contact angle, the better the imbibition effect of fracturing fluid. Research results have theoretical guiding significance for spontaneous imbibition to improve oil recovery.

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Section: Introductionmentioning

confidence: 99%

Imbibition Characteristics and Influencing Factors of the Fracturing Fluid in a Tight Sandstone Reservoir

Li,

Ren,

Sun

et al. 2024

ACS Omega

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“…Spontaneous imbibition depends on the interaction between oil/water/rock multiphase flows. Imbibition usually involves complex forces between capillary, gravity, and viscous forces [10,[22][23][24]. Spontaneous imbibition leads to low flow back rates in tight reservoirs as the fluid stays within the formation and is replaced by imbibition fluid due to capillary forces.…”

Section: Introductionmentioning

confidence: 99%

Investigating the Influencing Factors of Imbibition of Fracturing Fluids in Tight Reservoirs

Liu,

Qu,

Wang

et al. 2024

Processes

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Tight reservoirs are the focus of unconventional oil and gas resource development, but most tight reservoirs exhibit complex pore structures, strong non-homogeneity, and limited water drive development. Fracturing fluid imbibition is a critically important way to improve the recovery of tight reservoirs. In this paper, an NMR experimental device was used to conduct imbibition experiments in tight reservoirs, and the relationship between temperature, pressure, matrix permeability, and imbibition recovery was investigated. Based on the fracturing fluid imbibition recovery curve, the imbibition process is divided into the fast imbibition stage, slow imbibition stage, and imbibition equilibrium. In addition, based on the pore structure division, the recovery changes of each pore under different experimental conditions were quantitatively analyzed. The results indicate that the highest imbibition recovery is achieved at an experimental pressure of 5 MPa within the range of 0 MPa to 15 MPa. Increasing the experimental pressure can increase the imbibition rate but will not increase imbibition recovery. Within the investigated range in this paper, fracturing fluid imbibition increases with rising temperature and matrix permeability. Moreover, the recovery of each pore gradually increases with the experimental pressure ranging from 0 MPa to 5 MPa. The recovery of each pore is positively correlated with matrix permeability and temperature. During the experiment, micropores contributed the most to the recovery, while macropores contributed the least. The study in this paper guides the efficient development of tight reservoirs.

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“…Core experiments that effectively represent natural conditions are usually performed with the help of techniques such as nuclear magnetic resonance, , X-ray CT scanners, and neutron imaging to detect the fluid distribution and the pore structure characteristics during imbibition. The researchers conducted core experiments to explore the influence of the number of pores and complex structure characteristics , on the mass transfer process. They also examined the relationship between viscosity and surfactant concentration in correlation with the imbibition rate.…”

Section: Introductionmentioning

confidence: 99%

Spontaneous Imbibition in Nanomatrix–Fracture of Low Permeability Using Multiscale Nanofluidic Chips

Qin,

Guo,

Sun

et al. 2023

Langmuir

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Effects of microstructural and petrophysical properties on spontaneous imbibition in tight sandstone reservoirs

Cited by 27 publications

References 40 publications

Imbibition Characteristics and Influencing Factors of the Fracturing Fluid in a Tight Sandstone Reservoir

Imbibition Characteristics and Influencing Factors of the Fracturing Fluid in a Tight Sandstone Reservoir

Investigating the Influencing Factors of Imbibition of Fracturing Fluids in Tight Reservoirs

Spontaneous Imbibition in Nanomatrix–Fracture of Low Permeability Using Multiscale Nanofluidic Chips

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