Numerical Simulation of Complex Fracture Propagation in Shallow Shale Gas Fracturing in Zhaotong
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摘要:
昭通浅层页岩气田主体埋深在1 000～2 200 m，地层压力系数低，效益开发难度较大，水力压裂是唯一增产措施，但目前国内尚无对中浅层页岩储层实施规模开发的经验可供借鉴，水力压裂工艺参数仍有优化空间。为明确目标昭通浅层页岩气田裂缝扩展主控影响因素，优化页岩气水平井压裂参数，针对该页岩气田储层天然裂缝发育、水平应力差小，主体改造工艺射孔簇较多等地质、工程特点，开展了昭通浅层页岩气压裂复杂裂缝扩展数值模拟研究。采用位移不连续法，考虑天然裂缝和水力裂缝的相互作用模式，基于压裂裂缝流动方程、裂缝宽度方程和物质平衡方程，推导了复杂裂缝扩展数学模型；针对昭通浅层页岩气实际地质特点，基于建立的数学模型优化了施工参数，明确了天然裂缝内聚力、射孔簇数是影响改造体积的主要因素。同时，通过暂堵数值模拟，明确得出：暂堵有利于提高裂缝开启效率，暂堵位置、暂堵时机及暂堵次数对暂堵效果有明显影响。通过现场试验对比模拟结果，发现采取优化后的压裂措施可使单井日产气量提高30.3%。该研究成果对昭通浅层页岩气后续压裂施工具有良好的借鉴意义。
Abstract:The main burial depth of the shallow shale gas field in Zhaotong is 1000-2200 m. The formation pressure coefficient is low, making the benefit development challenging. Hydraulic fracturing technology remains the only stimulation measure. However, there is no prior experience of large-scale development of medium and shallow shale reservoirs in China for reference. Therefore, there is still room for optimizing hydraulic fracturing parameters. In consideration of the geological and engineering characteristics, such as natural fracture development, small horizontal stress differences, and large perforation cluster numbers of the main stimulation, a numerical simulation of complex fracture propagation in shallow shale gas fracturing in Zhaotong was conducted. The displacement discontinuity method was employed, with the interaction mode of natural and hydraulic fractures considered. Based on the fracture flow equation, fracture width equation, and mass balance equation, the mathematical model of complex fracture propagation was derived. Based on the model, construction parameters were optimized according to the actual geological characteristics of shallow shale gas in Zhaotong. It was determined that natural fractures and perforation cluster numbers were the main factors affecting the stimulated reservoir volume (SRV). At the same time, through the temporary plugging numerical simulation, it is clarified that temporary plugging is conducive to improving the fracture opening efficiency, and the location, timing and times for temporary plugging have obvious effects on the temporary plugging effect. The simulation results were compared with on-site test results, demonstrating that the optimized fracturing measures increased daily single gas production by 30.3%. Consequently, this study provides valuable insights for the subsequent fracturing treatment of shallow shale gas in Zhaotong.
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图 1 水力裂缝与天然裂缝相交后的扩展路径
Figure 1. Propagation path after the intersection of hydraulic and natural fractures
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图 2 天然裂缝内聚力对页岩SRV的影响
Figure 2. Effect of cohesion of natural fractures on SRV of shale fracturing
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图 3 不同天然裂缝内聚力条件下改造区域的平面展布
Figure 3. Plane layout of stimulated region under different natural fracture cohesion conditions
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图 5 不同泵注排量下改造区域的平面展布
Figure 5. Plane layout of stimulated region with different pumping rate
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图 6 射孔簇数对页岩SRV的影响
Figure 6. Effect of perforation cluster number on SRV of shale fracturing
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图 7 不同射孔簇数下改造区域的平面展布
Figure 7. Plane layout of stimulated region with different number of perforation clustersrs
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图 8 不同暂堵时机下裂缝的扩展形态
Figure 8. Fracture propagation morphology under different temporary plugging timing
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图 9 不同暂堵次数下裂缝的扩展形态
Figure 9. Fracture propagation morphology under different temporary plugging times
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图 10 不同水平应力差下暂堵后裂缝扩展形态
Figure 10. Fracture propagation morphology after temporary plugging under different horizontal stress difference
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图 11 同平台不同簇间距对比
Figure 11. Comparison of different cluster spacing on the same platform
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图 12 稳产条件下折算百米段长日产气量对比
Figure 12. Comparison of daily production per 100 m under stable production condition
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