水力压裂作为页岩气藏开发的重要技术，如何有效提高深层页岩储层“狭长缝”内的支撑剂铺置效果成为目前亟须解决的难题。研究基于模拟深层页岩储层狭长裂缝的平板实验装置，对压裂液黏度、注入排量、支撑剂粒径、加砂质量浓度、裂缝宽度、支撑剂类型等参数进行对比实验，以了解支撑剂颗粒在深层页岩储层狭长裂缝内的沉降运移规律。结果表明：与宽缝相比，相同条件下支撑剂颗粒在深层页岩狭长缝内形成的砂堤前缘坡度降低，前后砂堤高度差距减少，支撑剂颗粒的整体铺置效果更加均匀平缓；在深层页岩狭长缝内，末端砂堤面积占整体砂堤面积的比重随压裂液黏度、注入排量的增大而增大，而加砂质量浓度对其影响程度较低；微小粒径支撑剂颗粒同样对末端砂堤的铺置具有促进作用，并且更有利于整体砂堤的均匀铺置；深层页岩狭长缝内裂缝宽度的收缩对收缩前裂缝内的砂堤铺置无明显影响，但会阻碍收缩后裂缝内支撑剂颗粒的流动铺置。收缩后裂缝内砂堤的覆盖面积减小，平衡高度降低，砂堤整体铺置更加均匀。但支撑剂的沉降量减少，同时增大了深层页岩储层裂缝有效压裂支撑的难度。该实验研究成果可为深层页岩储层的压裂改造设计提供有力的支撑。

Shale gas, an unconventional natural gas resource, has become an important supplement to global conventional oil and gas resources. With the increasing development of shale gas resources, deep shale gas reservoirs have emerged as key targets for exploration and production. These reservoirs are characterized by complex geological structures, high rock plasticity, and significant vertical and horizontal stress differences. Such conditions hinder the formation of complex fracture networks during hydraulic fracturing, often resulting in simple, narrow, and long fractures. The narrow width of these fractures significantly affects the settlement and migration of proppants, which in turn influences fracture conductivity and determines the effectiveness of reservoir stimulation. Therefore, investigating the settlement and migration behaviors of proppants in long narrow fractures is essential for the safe and efficient production of deep shale gas wells. Current experimental studies on proppant migration commonly use parallel-plate simulation devices made of organic glass. Research indicates that proppant settlement and migration are substantially influenced by viscous fluid drag, with the drag coefficient depending on factors such as particle shape, concentration, and flow rate. Additionally, proppant type, density, and concentration further affect proppant distribution. However, most existing studies are based on the fracture geometries of medium and shallow shale reservoirs, which differ from those of deep shale formations in both fracture width and suitable proppant size. To address this gap, this study employed a large-scale visualized simulation device to examine the settlement and migration of proppants in long narrow fractures in deep shales. The objective is to clarify the effects of different proppant properties and fracturing parameters on proppant distribution, thereby providing theoretical support for fracturing stimulation in deep shale reservoirs. The experimental setup included a fracture simulation device, a mixing unit, and a circulation system. The fracture simulation device was composed of interconnected organic glass plates, with adjustable fracture widths between 2-3 mm to replicate the fractures in deep shale. Slickwater fracturing fluids were prepared with three viscosities: 3 mPa·s, 6 mPa·s, and 9 mPa·s. Selected proppants included 40/70 mesh, 70/140 mesh, and 100/200 mesh quartz sand, along with 70/140 mesh coated ceramic proppants, representing micro-sized particles. A total of 11 experimental groups were designed to investigate the effects of fracturing fluid viscosity, injection rate, proppant concentration, proppant particle size, proppant type, and fracture width variation. Experimental results indicated that, compared with the wider fractures of medium and shallow shales, under the same conditions, long narrow fractures in deep shale promote the agglomeration of proppant particles, causing a rapid settlement near the inlet. This led to a reduced leading-edge slope of the sand bank and a smaller height difference between the front and rear of the sand bank compared to wider fractures. The overall proppant distribution tends to be more uniform and smoother. In long narrow fractures of deep shale, the proportion of terminal sand bank area to the total sand bank area increases with higher fracturing fluid viscosity and injection rate, while the effect of proppant concentration is relatively limited. Micro-sized proppants are more prone to settling at the far end of the narrow fracture and contribute to a more uniform overall distribution. Moreover, the contraction of fracture width has no significant effect on sand bank placement before contraction, but it hinders the flow and placement of proppant particles after contraction, resulting in decreased proppant settlement. Due to the high closure pressure in deep shale reservoirs, fractures are prone to closure, and the reduction in proppant settlement after fracture contraction further increases the difficulty of effective fracture support. This experimental study reveals the settlement and migration patterns of proppants in long narrow fractures in deep shale, providing a theoretical foundation for optimizing fracturing simulation strategies. The findings have practical significance for selecting proppant types and optimizing fracturing parameters to enhance the production efficiency of deep shale gas wells.