Mechanisms of fracturing fluid spontaneous imbibition behavior in shale reservoir: A review

Hu, Yongquan; Zhao, Chaoneng; Zhao, Jinzhou; Wang, Qiang; Zhao, Jin; Dong, Gao; Fu, Chunyun

doi:10.1016/j.jngse.2020.103498

Cited by 67 publications

(31 citation statements)

References 102 publications

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“…At the same time, generally speaking, the imbibition rate of group B is significantly higher than that of group A, which may be due to the stronger hydrophilicity of group B. However, spontaneous imbibition is actually a complex process, involving quite a few factors such as porosity, absolute permeability, interfacial tension, pore size, fluid viscosity, and so on, and different curve shapes and different spontaneous imbibition recovery rates can be obtained even for cores with the same physical properties (Hu et al, 2020).…”

Section: Imbibition Efficiency On Standard Core Plugsmentioning

confidence: 99%

Differences in Imbibition Efficiency Between Bedding and Tectonic Fractures in the Lucaogou Formation in the Jimusar Sag: Evidence From Simulation Experiments

Liang

Liu²,

Li³

et al. 2022

Front. Earth Sci.

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In addition to tectonic fractures, the ubiquitous and important bedding fractures are often overlooked in the imbibition processes. Based on the identification of different fracture types in tight sandstone from the middle Permian Lucaogou Formation in the Jimusar Sag, NW China, spontaneous imbibition of water experiments was carried out, aiming to investigate the effect of tectonic and bedding fractures on hydrocarbon recovery efficiency in tight reservoir rocks. The results show that the difference in connectivity between the vertical (tectonic fractures) and horizontal (bedding fractures) directions of pores and pore throats is the main reason for the distinction in microscale permeability and, hence, fluid imbibition. The difference in the time required for imbibition between bedding and tectonic fractures is subtle, but the former is slightly lower than the latter in terms of imbibition depth and efficiency. Higher temperatures can shorten the reaction time of imbibition. On the basis that the tectonic fractures are opened, opening the same scale of bedding can increase the imbibition effectiveness by 8.7% at reservoir conditions (27 MPa, 80°C), and the closer to the fracture, the higher the imbibition efficiency in the matrix. The samples with higher porosity and permeability per unit volume have high imbibition oil recovery. However, the imbibition efficiency of the samples with lower porosity and permeability is higher, i.e., the final imbibition efficiency is inversely proportional to porosity and permeability.

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Section: Imbibition Efficiency On Standard Core Plugsmentioning

confidence: 99%

Differences in Imbibition Efficiency Between Bedding and Tectonic Fractures in the Lucaogou Formation in the Jimusar Sag: Evidence From Simulation Experiments

Liang

Liu²,

Li³

et al. 2022

Front. Earth Sci.

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show abstract

“…There is so much literature that focuses on using this method to extract tight oil and enhance oil recovery. However, the spontaneous imbibition efficiency is not very high [7]. In addition, understanding of the spontaneous imbibition mechanism cannot catch up with the development of tight sandstones oil.…”

Section: Introductionmentioning

confidence: 99%

Control Mechanism and Parameter Simulation of Oil-Water Properties on Spontaneous Imbibition Efficiency of Tight Sandstone Reservoir

Ren

Ma²,

Liu

et al. 2022

Front. Phys.

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Spontaneous imbibition is an effective method of tight sandstone reservoirs development. However, their underlying mechanisms are still unclear due to the representative issue caused by strong heterogeneity and complex oil-brine properties. In this research, physical properties and thin-section images were systematically analyzed, and the spontaneous imbibition efficiency was examined from core tests. The results show that quartz and feldspar predominantly contribute to mineralogy. Low brine salinity, high oil viscosity, and high interfacial tension corresponded to strong spontaneous imbibition ability and fast process. High interfacial tension is the dominant controlling factor in this field. Furthermore, the parameter simulation model established by the dimension reduction method could catalyze the prediction of spontaneous imbibition efficiency, which is confirmed by higher reliability.

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“… 6 , 7 After the fracturing operation is complete, only 20–40% of the injected fluid flows back and more than 60% remains in the subsurface. 8 The retained fracturing fluid can damage the pore throats and fractures of the shale formation. 9 Therefore, efforts to increase shale gas production improve the importance of interactions between shale and injected fracturing fluid.…”

Section: Introductionmentioning

confidence: 99%

Impact of Pyrite Oxidation on the Pore-Structure Characteristics of Shale Reservoir Rocks under the Interaction of Fracturing Fluid

Sun

et al. 2022

ACS Omega

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Hydraulic fracturing combined with horizontal drilling is widely used to develop shale gas resources, and huge amounts of fracturing fluid are injected into shale reservoirs. However, the fracturing fluid is ineluctably retained in reservoir rocks after fracturing, resulting in the alteration of shale pore systems and further affecting the hydrocarbons production efficiency. In this work, two types of shales with different pyrite contents, namely, pyrite rich (PR, Niutitang Formation) and pyrite poor (PP, Xiamaling Formation), were emphasized to illustrate the effect of pyrite oxidation on pore structure after fracturing operation. Slickwater fracturing fluid was used to treat the shale samples for a period of 3 days, under the condition of 100 °C and 50 MPa. The field emission scanning electron microscopy (FE-SEM) and X-ray diffraction (XRD) were utilized to determine the surface morphology and mineral composition. The low-temperature N 2 adsorption was performed to quantify the pore structure. The results showed that the pyrite oxidation induced the dissolution of both the pyrite and calcite and generated many dissolution pores for the pyrite-rich shale after slickwater treatment. The mineral dissolution led to an increase in the number of mesopores, enlarged the total specific surface area (TSSA) and total pore volume (TPV), and strengthened the pore-structure complexity. On the other hand, the pyrite-poor shale only experienced clay swelling after slickwater treatment. Its pore surface roughness and pore-structure complexity degraded with the loss of nanopores and the reductions in TSSA and TPV. The results of this study enhance the understanding of the impact of pyrite oxidation on the pore structure and provide new insight into the optimization of fracturing operation conditions based on shale’s mineral composition characteristics.

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Mechanisms of fracturing fluid spontaneous imbibition behavior in shale reservoir: A review

Cited by 67 publications

References 102 publications

Differences in Imbibition Efficiency Between Bedding and Tectonic Fractures in the Lucaogou Formation in the Jimusar Sag: Evidence From Simulation Experiments

Differences in Imbibition Efficiency Between Bedding and Tectonic Fractures in the Lucaogou Formation in the Jimusar Sag: Evidence From Simulation Experiments

Control Mechanism and Parameter Simulation of Oil-Water Properties on Spontaneous Imbibition Efficiency of Tight Sandstone Reservoir

Impact of Pyrite Oxidation on the Pore-Structure Characteristics of Shale Reservoir Rocks under the Interaction of Fracturing Fluid

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