Numerical Simulation on Controlling and Optimizing of Fracture Behaviors for Hydraulic Fracturing in Low Permeability Formation
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Abstract
The key technologies used to unlock the unconventional resources now a days are horizontal drilling and single or multi-stage fracturing. It’s often verified with utilization of micro-seismic data, hydraulic fracturing in shale reservoirs typically created highly complex fracture network due to their complex geology and activation of pre-existing natural fractures that can’t be realistically captured when the classic planner bi-wing fracture models are implemented.
In this paper, a data set of reservoir properties, petro-physical properties and fracture treatment is used to build a new, advanced, and improved simulation model, which shows the improved methods for maximizing the production of oil and gas. The main factors that are investigated and that result in the main effect on fracture behavior are flow rate, proppants type and fracturing fluid.
Fracturing behavior, it’s controlling and optimizing are the main factors used to enhance production. FracproPT software is used, which shows the effect of proppant, the flow rate and fracturing fluid.
A comparison (between a real and simulation model) is shown, since the stimulated well’s production can be enhanced as a better simulated models should be implemented in future well’s stimulation.
A final fracture treatment that achieves maximum fracture length, fracture width and fracture height are determined to be optimal.
In this work, laboratory data is presented for various fracturing fluids with different surface activity pumped into the assembly chamber. Recent fracture treatments have been successfully utilizing a slick water treatment consisting of water and dry polymer with and without surfactant (Tri-ethanol Amine- TEA). Commonly used surfactants as well as a microemulsion system are evaluated in this study.
Results from simulations show that the optimal fracture geometry and fracture conductivity based on pumping limitation is obtained at an injection rate of 100bpm, gel loading of 50ppg and proppant size of 20/40 mesh sand. This paper brings new understanding of fracture behavior in reservoirs and serves as a guide for improved hydraulic fracturing practices.
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References
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