Laboratory investigation and evaluation of the hydraulic fracturing of marine shale considering multiple geological and engineering factors

Abstract

Hydraulic fracturing is widely implemented in the exploration of marine shale gas. Affected by various geological and engineering factors, gas production after stimulation is not always satisfactory. To reveal the influential effect of multiple factors, laboratory hydraulic fracturing experiments are performed on Longmaxi marine shales by considering key parameters (deviatoric stress, confining pressure, pumping rate, fracturing fluid type, and bedding angle). The variation of breakdown pressures and the characteristics of hydraulic fractures are recorded and analyzed. The results show that the breakdown pressure increases with increasing deviatoric stress, confining pressure, pumping rate, and viscosity of the fracturing fluid. As the bedding angle varies from 0° to 90°, the breakdown pressure declines first and increases again. Furthermore, parameter sensitivity analysis indicates that geological factors (confining pressure, bedding angle, and deviatoric stress) would largely determine the breakdown pressure, while engineering factors (pumping rate, fracturing fluid type) could only affect it to a lesser extent. Computed tomography measurements show that natural fractures, originating from tectonic shear failure, could possess greater width than tension-dominated hydraulic and bedding fractures. Statistical analysis shows that the length of the hydraulic fractures alone is only approximately 150 mm. However, the fully activated natural and/or bedding fractures could help substantially increase the total fracture length to 600 mm. Low deviatoric stress, low confining pressure, low viscous slick-water, and high bedding angle are conducive to activating natural and bedding fractures and forming a complex fracture network. The aforementioned findings are valuable for the optimal design of field hydraulic fracturing.

Study on multi-cluster fracturing simulation of deep reservoir based on cohesive element modeling

“…However, the current size of cube specimens in the laboratory is usually 100 mm × 100 mm × 100 mm or 300 mm × 300 mm × 300 mm, with few experimental specimens reaching the meter level in size, far smaller than the actual reservoir modification area (Shang et al, 2018;Liu et al, 2021;Qiu et al, 2023). Therefore, there are still significant size limitations in the physical simulation research of multi-cluster fracturing based on indoor experiments (Wang, et al, 2022;Yang et al, 2023b). Meanwhile, it is worth mentioning that conducting physical simulation research on the fracturing of meter-scale experimental specimens is usually very expensive, making it difficult to conduct a comprehensive analysis.…”

Study on the influence of stress difference coefficient on hydraulic fractures in deep shale reservoir and the formation method of complex fracture network

“…With the continuous progress and maturity of exploration and development technology of middle-shallow shale reservoir, the focus of scientific research is gradually expanding from middle-shallow shale to deep shale (Wang 2022). This is because the exploration and development of middle-shallow shale reservoirs has achieved certain results and experience, and the technology is relatively mature, so that researchers focus on the more challenging and cutting-edge deep shale field.…”