## A Novel Hydraulic Fracturing Method Based on the Coupled CFD-DEM Numerical Simulation Study  
**[PERSON] 1,**2**, **[PERSON] 1**, [PERSON] 2, [PERSON] 1, [PERSON] 1**, [PERSON] 3,**  
**[PERSON] 3 and [PERSON] 1**  
State Key Laboratory of Oil & Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China; [EMAIL_ADDRESS] (L.M.); [EMAIL_ADDRESS] (F.H.); [EMAIL_ADDRESS] (C.H.); [EMAIL_ADDRESS] (J.G.)  
The 4 th Producing Plant, the Southwest Oil & Gas Company of SINOPEC, Chongqing 402160, China; [EMAIL_ADDRESS]  
Sinopec Shengli Oil field Luming Oil-Gas Exploration & Development Ltd., Dongying 257000, China; [EMAIL_ADDRESS] (H.Y.); [EMAIL_ADDRESS] (Z.T.)  
Correspondence: [EMAIL_ADDRESS]; Tel.: +86-138-8096-0896  
Received: 15 February 2020; Accepted: 24 April 2020; Published: 26 April 2020  
**Featured Application: Based on a coupled CFD-DEM numerical simulation and an experimental study, a novel hydraulic fracturing method for the development of tight reservoirs is proposed.**  
**Abstract:** For the development of tight oil reservoirs, hydraulic fracturing employing variable fluid viscosity and proppant density is essential for addressing the problems of uneven placement of proppants in fractures and low propping efficiency. However, the influence mechanisms of fracturing fluid viscosity and proppant density on proppant transport in fractures remain unclear. Based on computational fluid dynamics (CFD) and the discrete element method (DEM), a proppant transport model with fluid-particle two-phase coupling is established in this study. In addition, a novel large-scale visual fracture simulation device was developed to realize the online visual monitoring of proppant transport, and a proppant transport experiment under the condition of variable viscosity fracturing fluid and proppant density was conducted. By comparing the experimental results and the numerical simulation results, the accuracy of the proppant transport numerical model was verified. Subsequently, through a proppant transport numerical simulation, the effects of fracturing fluid viscosity and proppant density on proppant transport were analyzed. The results show that as the viscosity of the fracturing fluid increases, the length of the \"no proppant zone\" at the front end of the fracture increases, and proppant particles can be transported further. When alternately injecting fracturing fluids of different viscosities, the viscosity ratio of the fracturing fluids should be adjusted between 2 and 5 to form optimal proppant placement. During the process of variable proppant density fracturing, when high-density proppant was pumped after low-density proppant, proppants of different densities laid fractures evenly and vertically. Conversely, when low-density proppant was pumped after high-density proppant, the low-density proppant could be transported farther into the fracture to form a longer sandbank. Based on the abovementioned observations, a novel hydraulic fracturing method is proposed to optimize the placement of proppants in fractures by adjusting the fracturing fluid viscosity and proppant density. This method has been successfully applied to more than 10 oil wells of the Bohai Bay Basin in Eastern China, and the average daily oil production per well increased by 7.4 t, significantly improving the functioning of fracturing. The proppant settlement and transport laws of proppant in fractures during variable viscosity and density fracturing can be efficiently revealed through a visualized proppant transport experiment and numerical simulation study. The novel fracturing method proposed in this study can significantly improve the hydraulic fracturing effect in tight oil reservoirs.  
**Keywords: tight oil reservoirs; hydraulic fracturing; proppant transport; CFD-DEM; numerical simulation** +
Footnote †: journal: Journal of Computational Physics