Hydraulic fracturing has been widely used for producing oil and gas from tight reservoirs. During hydraulic fracturing, a large volume of fracturing fluid mixed with proppant are pumped downhole to create large propped fractures with high conductivity which greatly increases the contact area between the wellbore with the reservoir matrix. Proppant placement needs to be optimized in order to obtain the maximum propped surface area. In this paper, we introduce a lifecycle modeling framework, which simulates hydraulic fracturing, shut-in, and production scenarios, with an emphasis on proppant transport. In the simulator, proppant distribution among perforation clusters, proppant transport with the fracturing fluid inside the fracture, proppant settling during treatment and shut-in, coupled proppant embedment into the rock matrix and fracture closure, are all handled accurately and elegantly and are shown to play and important role in controlling the well performance. An example well lifecycle simulation case is demonstrated to showcase the modeling capability of the integrated hydraulic fracturing and reservoir simulator. 1. INTRODUCTION Hydraulic fracturing is a successful technique for increasing the productivity of unconventional reservoirs. The impact of fractured well performance and the corresponding cost are greatly influenced by the stimulation design. Hydraulic fracture closure is a crucial process during shut-in and production. Fracture closure characteristics define the productivity of the created fractures, which has a direct impact on fractured well productivity. Fracture closure and proppant settling are two fully coupled processes during both shut-in and production. Proppant distribution greatly affects the residual fracture width and conductivity evolution whereas fracture closure may limit proppant settling and force the proppant to crush or embed into the rock. Modeling fracture closure with the complex behavior of proppant in the lifecycle of an unconventional well is numerically challenging due to the multiple coupled physical processes, large time-scale differences, and extreme non-linearity in the coupling of the processes. Conventional fracture closure models either use over-simplified analytical estimates of the stress dependent permeability of the reservoir or explicitly calculate the fracture width using empirical relationships, without considering the effect of fluid leak-off and dynamic non-uniform proppant distribution in the fracture.