Suspensions of non-Brownian particles are ubiquitous in natural processes such as debris flows, magma flows, and sediment transport in river systems. Non-Brownian suspensions are used in engineering applications such as the injection of slurries for environmental remediation, mud injection during well drilling, cosmetics, and hydraulic fracturing. Suspensions are especially important in hydraulic fracturing, a technique developed in the 1940's by the oil industry to increase production rates from wells. The goal of hydraulic fracturing in oil and gas applications, is to enhance the permeability of subsurface rock formations by injecting a pressurized fluid to create a network of conductive pathways, i.e., fractures. The fluid used in hydraulic fracturing is composed of solids, chemical additives, and water. The solids (e.g., proppants) are used to \textit{prop} open the fracture and allow hydrocarbons to flow through the fracture. The hydrocarbons flow through the pore spaces between proppant particles, which means the fracture conductivity is limited by the amount and distribution of proppants delivered to the fracture.
The work presented in this dissertation explores the behavior of two different proppant mixtures (suspensions). The first suspension is a conventional proppant mixture (sand only) with a high solid volume fraction, $\phi_s=0.5$, which may increase fracture permeability by increasing the amount of sand delivered to the fracture. The second suspension is made up of sand ($\phi_s = 0.177$) and polymeric fibers ($\phi_f=0.0038$), which may create a proppant distribution that may enhance fracture permeability. I used transparent, laboratory-scale (15.2 cm $\times$ 15.2 cm), fractures to understand the behavior of these suspensions as they flow through and settle inside hydraulic fractures.
Concentrated suspensions flowing through idealized parallel-plate fractures exhibited complex flow behavior. Concentrated suspensions flowing through parallel fractures developed a non-uniform velocity distribution across the fracture width (in the plane of the fracture). As the concentrated suspension flowed through a confined rectangular channel (e.g., fracture) the suspension developed regions of high velocity near the no-flow boundaries where velocity was expected to be the lowest. These high-velocity regions were $\sim$2cm wide and were observed regardless of upstream boundary conditions. Furthermore, the observed non-uniform velocity distribution persisted irrespective of flow rate and fracture geometry. Through further experiments it was observed that these high-velocity regions were due to non-uniform $\phi$ distribution in the plane of the fracture. Additionally, the pressure gradient across the fracture, $\nabla P$, exhibited behavior that defied simple relationships between applied pressure gradient and flow rate. It was observed that the timescale required for $\nabla P$ to reach a steady state was significantly longer than expected. The cause of the transient $\nabla P$ was explored using a two-dimensional numerical model of concentrated suspensions flowing through a fracture of the same dimension as our experiments.
I explored the flow and settling behavior of multi-component (sand-fiber) proppant mixtures inside a fracture subjected to an applied stress. The experiments presented here show that adding fibers to conventional proppants leads to heterogeneous proppant distribution inside the fracture. This heterogeneous proppant distribution led to the formation of sand-fiber \textit{clusters} capable of supporting the applied stress and maintained the fracture open. Additionally, it was observed that injecting solids-free fluid (flowback) led to the mobilization of some solids within the proppant pack. Solid mobilization and flowback was explored through the use of a non-Newtonian flow solver that simulates flow through a mixed fracture-porous matrix medium. The experimental and numerical results suggest that adding polymer fibers to conventional proppants leads to highly heterogeneous proppant distribution which may lead to higher fracture permeability.