Microseismic evidence of fracture complexity has lead to the recent development of new modeling tools to simulate the growth of complex fracture networks. Typically these complex fracture models rely on calibration from microseismic location information, although microseismic source mechanics can also provide additional model verification. Modeled geomechanical deformation associated with hydraulic fracture stimulation of a complex hydraulic fracture provides information that can be compared with observed microseismic deformation. Partitioning of modeled strains into shear and dilatational components allows relative comparison of the appropriate displacement mode with observed cumulative microseismic moments. A number of simple fracture geometries are investigated to illustrate the deformation modes of the modeled fracture displacements. A workflow is also described where the input parameters of the simulation are varied to match both the footprint and deformation of the microseismicity, which then results in an estimate of the complete fracture network volume and proppant placement. In this way the effective stimulated volume can be assessed and used as input to a reservoir simulation to investigate well performance and reservoir drainage.