Energy-Based Fracture Network Reconstruction of Shale Gas Reservoir
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Abstract Microseismic monitoring is a commonly used technique in characterizing hydraulic fractures. However, fracture network reconstruction remains challenging due to the heterogeneity and complex stress field of shale gas reservoirs. An Energy-based 3D Fracture Reconstruction method (EFR3D) is proposed to derive the complex fracture network from microseismic data in a shale gas reservoir. The EFR3D method mainly combines the Propose Expand and Re-Estimate Labels algorithm (PEARL), the Density-Based Spatial Clustering of Applications with Noise algorithm (DBSCAN), and the Alpha-shape algorithm to detect the fracture orientation and fracture shape. This method formulates fracture orientation detection as an energy minimization task to improve reconstruction accuracy. The effectiveness of the proposed method was evaluated by performing a verification procedure against different fracture numbers, fracture orientations, and fracture scales using the Monte Carlo simulation. The results show that the proposed method has good adaptability and high accuracy in various fracture configurations. Furthermore, a field application of six horizontal wells located in the southern Sichuan basin, southwest China, was conducted to illustrate the robustness and practicability of the proposed method. The proposed method can serve as a practical and reliable approach to characterize hydraulic fractures.Keywords:
Microseism
Stress field
Summary In spite of the wide use of hydraulic fracturing in Ukraine, microseismic monitoring of hydraulic fracturing is used to a very limited extent. This can lead to situations where the fracture zone does not meet the design objectives. The lack of microseismic control reduces the economic efficiency of hydraulic fracturing. To solve this problem, specialists from the Institute of Geology of the Taras Shevchenko National University of Kyiv have initiated a development and production program of modern methods of microseismic monitoring of hydraulic fracturing. One of the areas of work is the creation of technology and software for the imaging of microseismic events using the continuation of the microseismic wave field in the geological environment.
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Microseismic Imaging of Hydraulic Fracturing: Improved Engineering of Unconventional Shale Reservoirs (SEG Distinguished Instructor Series No. 17) covers the use of microseismic data to enhance engineering design of hydraulic fracturing and well completion. The book, which accompanies the 2014 SEG Distinguished Instructor Short Course, describes the design, acquisition, processing, and interpretation of an effective microseismic project. The text includes a tutorial of the basics of hydraulic fracturing, including the geologic and geomechanical factors that control fracture growth. In addition to practical issues associated with collecting and interpreting microseismic data, potential pitfalls and quality-control steps are discussed. Actual case studies are used to demonstrate engineering benefits and improved production through the use of microseismic monitoring. Providing a practical user guide for survey design, quality control, interpretation, and application of microseismic hydraulic fracture monitoring, this book will be of interest to geoscientists and engineers involved in development of unconventional reservoirs.
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Summary Hydraulic fracture monitoring using microseismic technology is becoming a very popular tool to develop unconventional reservoirs. Microseismic source locations and attributes provide valuable information about hydraulic fracturing growth and containment, and the response of reservoir rock to fluid injection. Such information can be utilized to assess fracturing efficiency, optimize fracturing and completion designs and guide placement of future wells. In this paper we utilise microseismic data acquired during a horizontal well hydraulic fracturing job in a deep tight sandstone gas reservoir located in the Sultanate of Oman. The objective is to assess completion design and fracturing efficiency. The microseismic data is analysed in space and time and the results are compared to the hydraulic stimulation models based on the reservoir geomechanical properties.
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Fracture reorientation affects hydraulic fracturing much in perforated wells. A finite element model used for investigating fracture reorientation is established using the extended finite element method with ABAQUS software. Based on this, both fracture reorientation and fracture propagation during fracturing operation in shale reservoirs are analyzed. Meanwhile, the effect of the difference between the maximum and minimum principal stresses on fracture reorientation during fracturing in shale reservoirs has also been studied. The results demonstrate that the fracture reorients to the direction of the maximum principal stress gradually, and the difference between the maximum and minimum principal stresses impacts the fracture reorientation more than fracture propagation.
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Summary We present results of application of stress field inversion on microseismic monitoring data. We inverted regional principal stress directions from the source mechanisms of microseismic events induced by hydraulic fracturing in a shale reservoir. We compare results of stress inversion from several groups of microseismic events and inversions. We compare inversions using source mechanisms inverted from manually picked amplitudes and automatically inverted source mechanisms. We show changes in the stress field orientation based on subset of dataset created according to observed type of source mechanisms and depth of microseismic events. The resulting stress fields are stable, highly similar and consistent with regional stress field. We get maximum regional stress in the vertical direction, which is typical for most of sedimentary basins, and maximum horizontal stress oriented approximately 75o from the direction of the drilled wells. The fact that we obtained the regional stress indicates that the regional stress determined the source mechanisms of induced microseismic events and we use Mohr diagrams to determine most likely fault planes of these events.
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Hydraulic fracturing using heavy brine was conducted to stimulate the deeper part of the completion interval in the naturally<br>fractured reservoir, Yufutsu Japan. The microseismic monitoring and the temperature surveys showed that the deeper part was<br>stimulated effectively as expected.
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