Abstract
In this study, variable injection-rate technology was numerically investigated in a pre-existing discrete fracture network (DFN) formation, the Tarim Basin in China. A flow-stress-damage (FSD) coupling model has been used in an initial attempt towards how reservoir response to variable injection-rates at different hydraulic fracturing stages. The established numerical model simultaneously considered the macroscopic and microscopic heterogeneity characteristics. Eight numerical cases were studied. Four cases were used to study the variable injection-rate technology, and the other four cases were applied for a constant injection-rate in order to compare with the variable injection-rate technology. The simulation results show that the variable injection-rate technology is a potentially good method to a form complex fracturing networks. The hydraulic fracturing effectiveness when increasing the injection-rate at each stage is the best, also, the total injected fluid is at a minimum. At the initial stage, many under-fracturing points appear around the wellbore with a relatively low injection-rate; the sudden increase of injection rate drives the dynamic propagation of hydraulic fractures along many branching fracturing points. However, the case with decreasing injection rate is the worst. By comparing with constant injection-rate cases, the hydraulic fracturing effectiveness with variable flow rate technology is generally better than those with constant injection-rate technology. This work strongly links the production technology and hydraulic fracturing effectiveness evaluation and aids in the understanding and optimization of hydraulic fracturing simulations in naturally fractured reservoirs.
Highlights
The combination of horizontal drilling and massive multi-stage hydraulic fracturing (MMHF)technology has made possible the current flourishing gas production from shale gas formations in the USA, as well as the fast increasing global investment in shale gas exploration and development.In shale fracturing, micro-seismic observations have illustrated that extreme fracture complexity may result from the interaction between created hydraulic fractures and the pre-existing fracture network.operators could change the stimulation design by changing the injection rate, viscosity, or other parameters, in order to improve the effectiveness of the stimulation in shale gas plays
Micro-seismic observations have illustrated that extreme fracture complexity may result from the interaction between created hydraulic fractures and the pre-existing fracture network
The aim of this work is on the numerical investigation of how variable fluid injection-rate technology affects natural fracture shear slippage, the hydraulic fracture (HF) interaction with the discrete fracture network (DFN) and hydraulic fracturing effectiveness using a flow-stress-damage (FSD) coupled model realistic failure process analysis (RFPA)-Flow
Summary
The combination of horizontal drilling and massive multi-stage hydraulic fracturing (MMHF)technology has made possible the current flourishing gas production from shale gas formations in the USA, as well as the fast increasing global investment in shale gas exploration and development.In shale fracturing, micro-seismic observations have illustrated that extreme fracture complexity may result from the interaction between created hydraulic fractures and the pre-existing fracture network.operators could change the stimulation design by changing the injection rate, viscosity, or other parameters, in order to improve the effectiveness of the stimulation in shale gas plays. The combination of horizontal drilling and massive multi-stage hydraulic fracturing (MMHF). Technology has made possible the current flourishing gas production from shale gas formations in the USA, as well as the fast increasing global investment in shale gas exploration and development. Micro-seismic observations have illustrated that extreme fracture complexity may result from the interaction between created hydraulic fractures and the pre-existing fracture network. A large stimulated interaction volume between natural fractures and hydraulic fractures plays a major role in economic shale gas production. In the successful economic gas production, it is crucial to maximize the total stimulated reservoir volume (SRV). Despite the recent success in shale gas development, the cost of hydraulic fracturing treatment remains very high.
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