A three-dimensional numerical pressure transient analysis model for fractured horizontal wells in shale gas reservoirs

Hu, Peng; Geng, Shaoyang; Liu, Xianshan; Li, Chengyong; Zhu, Runhua; He, Xing

doi:10.1016/j.jhydrol.2023.129545

Cited by 12 publications

(3 citation statements)

References 46 publications

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“…The relationship between fracture width and porosity is given using the Carman-Kozeny equation [20]:…”

Section: Flow Conservation In Fractured Shale Reservoirsmentioning

confidence: 99%

Diagnostics of Secondary Fracture Properties Using Pressure Decline Data during the Post-Fracturing Soaking Process for Shale Gas Wells

Wu,

Ren,

Chang

et al. 2024

Processes

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In addition to main fractures, a large number of secondary fractures are formed after the volumetric fracturing of shale gas wells. The secondary fracture properties are so complex, that it is difficult to identify and diagnose by direct monitoring methods. In this study, a new approach to model and diagnose secondary fracture properties is presented. First, a new pressure decline model, which is composed of four interconnected domains, i.e., wellbore, main fractures, secondary fractures, and reservoir matrix pores, is built. Then, the fracturing fluid pumping and post-fracturing soaking processes are simulated. The simulated pressure derivatives reflect five fracture-dominated flow regimes, which correspond to multiple alternating positive and negative slopes of the pressure decline derivative. The results of sensitivity simulation show that the density, permeability, and width of secondary fractures are the main controlling factors affecting the size ratio. Finally, based on the simulated pressure decline characteristics, a diagnostic method for the identification and analysis of secondary fracture properties is formed. This method is then applied to three platform wells in the Changning shale gas field in China. This study builds the correlation between the secondary fracture properties and the shut-in pressure decline characteristics, and also provides a theoretical method for comprehensive post-fracturing evaluation of shale gas horizontal wells.

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“…The relationship between fracture width and porosity is given using the Carman-Kozeny equation [20]:…”

Section: Flow Conservation In Fractured Shale Reservoirsmentioning

confidence: 99%

Diagnostics of Secondary Fracture Properties Using Pressure Decline Data during the Post-Fracturing Soaking Process for Shale Gas Wells

Wu,

Ren,

Chang

et al. 2024

Processes

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“…Table 1 and Figure 6 show that the embedment of ceramsite in marl increases with the increase in ceramsite diameter. If the ceramsite is embedded deeply, it will affect the conductivity of the fracture [43]. In this paper, the conductivity of different combinations of proppant is evaluated using the conductivity tester, and the optimal proppant combination is selected by comparing their conductivity differences.…”

Section: Study On the Conductivity And Placement Form Of Proppantmentioning

confidence: 99%

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

Wang,

Fan,

et al. 2023

Processes

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China’s argillaceous limestone reservoir has a lot of oil and gas resources, and hydraulic fracturing of the argillaceous limestone reservoir faces many difficulties. The first problem is that the heterogeneity of the argillaceous limestone reservoir is strong, and it is difficult to optimize fracturing parameters. The second problem is that there are a lot of natural fractures in the argillaceous limestone reservoir, which leads to a lot of fracturing fluid loss. The third problem is that the closure pressure of the argillaceous limestone reservoir is high, and the conductivity of fractures decreases rapidly under high closure pressure. The last problem is that the fracture shape of the argillaceous limestone reservoir is complex, and the law of proppant migration is unclear. The main research methods in this paper include reservoir numerical simulation, fluid-loss-reducer performance evaluation, flow conductivity tests and proppant migration visualization. To solve the above problems, this paper establishes the fracturing productivity prediction model of complex lithology reservoirs and defines the optimal hydraulic fracturing parameters of the argillous limestone reservoir in the Sichuan Basin. The 70/140 mesh ceramide was selected as the fluid loss additive after an evaluation of the sealing properties of different mesh ceramides. At the same time, the hydraulic fracture conductivity test is carried out in this paper, and it is confirmed that the fracture conductivity of 70/140 mesh and 40/70 mesh composite particle-size ceramics mixed according to the mass ratio of 5:5 is the highest. When the closure pressure is 40 MPa, the conductivity of a mixture of 70/140 mesh ceramic and 40/70 mesh ceramic is 35.6% higher than that of a mixture of 70/140 mesh ceramic and 30/50 mesh ceramic. The proppant migration visualization device is used to evaluate the morphology of the sand dike formed by the ceramsite, and it is clear that the shape of the sand dike is the best when the mass ratio of 70/140 mesh ceramsite and 40/70 mesh ceramsite is 6:4. The research results achieved a good stimulation effect in the SC1 well. The daily oil production of the SC1 well is 20 t, and the monitoring results of the wide-area electromagnetic method show that the fracturing fracture length of the SC1 well is up to 129 m.

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“…When selecting layers for carbon storage, the physical properties of the reservoir are critical factors to consider. However, existing studies focus on specific models to address this issue, with relatively few exploring the impacts of significant changes in reservoir physical properties on CO 2 storage [19][20][21].…”

Section: Introductionmentioning

confidence: 99%

Numerical simulation study of CO₂ storage capacity in Deep Saline aquifers

Wang,

Zhang,

et al. 2024

Sci. Tech. Energ. Transition

Self Cite

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The storage of supercritical CO2 in deep saline aquifers is essential for reducing carbon emissions, and selecting an appropriate reservoir is a primary task for carbon sequestration. To investigate the impact of reservoir physical properties on the CO2 storage capacity of saline aquifers, this study establishes a numerical simulation model of CO2 storage in deep saline aquifers anuses the MRST toolbox to solve it by the finite volume method. This research analyzes in detail the influence of reservoir physical properties on the CO2 migration process and CO2 storage capacity of the saline aquifers layer. The results show that CO2 injection for a long time is a process of first suppressing the pressure and then slowly diffusing it to the surroundings. Furthermore, the physical properties of the reservoir and the reservoir pressure significantly influence CO2 burial in deep saline aquifers. Higher reservoir permeability and deeper burial depth lead to more excellent CO2 storage and faster CO2 plume migration. However, the porosity and temperature of the reservoir have little impact on CO2 storage. Our research work provides a precise understanding of the selection of suitable layers for CO2 storage in deep saline aquifers, which offers strong support for early predictions of carbon capture, utilization, and storage (CCUS).

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A three-dimensional numerical pressure transient analysis model for fractured horizontal wells in shale gas reservoirs

Cited by 12 publications

References 46 publications

Diagnostics of Secondary Fracture Properties Using Pressure Decline Data during the Post-Fracturing Soaking Process for Shale Gas Wells

Diagnostics of Secondary Fracture Properties Using Pressure Decline Data during the Post-Fracturing Soaking Process for Shale Gas Wells

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

Numerical simulation study of CO₂ storage capacity in Deep Saline aquifers

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A three-dimensional numerical pressure transient analysis model for fractured horizontal wells in shale gas reservoirs

Cited by 12 publications

References 46 publications

Diagnostics of Secondary Fracture Properties Using Pressure Decline Data during the Post-Fracturing Soaking Process for Shale Gas Wells

Diagnostics of Secondary Fracture Properties Using Pressure Decline Data during the Post-Fracturing Soaking Process for Shale Gas Wells

A New Fracturing Method to Improve Stimulation Effect of Marl Tight Oil Reservoir in Sichuan Basin

Numerical simulation study of CO2 storage capacity in Deep Saline aquifers

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Numerical simulation study of CO₂ storage capacity in Deep Saline aquifers