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Abstract The success of enhanced geothermal systems (EGS) depends critically on the hydraulic connections established between injection and production wells. The Utah FORGE site features an EGS well pair that has a wide range of fracture and flow diagnostic measurements, such as fiber optics, tracers and a full suite of logs. This paper combines fiber optic data with fluid tracer and FMI data during well stimulation and fluid circulation to establish an integrated view of fracture growth for each stage, production / injection profiles for the well pair and inter-well connectivity. During the stimulation of the injector (16A), fiber optic data was used to assess fracture growth and intersections along the producer (16B). Fracture driven intersections (FDIs) within the strain-rate waterfall are mapped against the formation micro-resistivity imaging (FMI) log to investigate fracture reorientation by stress shadow effects and interaction with pre-existing natural fractures/faults. During fluid circulation, data from multiple tracers injected during stimulation were combined with fiber optic thermal slugging signals to estimate the production allocation between different stages along the production well. The fiber optic monitoring of well stimulation reveals distinct shifts between the locations of injector perforations and the FDIs (fracture intersections) detected along the production well. Numerical analysis reveals that the observed FDIs can be caused by fault reactivations or fracture reorientation due to interaction with natural fractures. The FMI data shows that the locations of reactivation and reorientation FDIs in the fiber optic data match the locations of pre-existing faults. During fluid circulation (after hydraulic fracturing both wells), fiber optic data shows a flow allocation along the well that is consistent with tracer data. Production allocation estimated from the thermal slugging signals from the fiber optic data also aligns closely with that calculated from the tracer interpretation. These data sets are shown to be consistent, and they provide an excellent estimation of inter-well connectivity for each stage. The results presented in this paper, for the first time, show an integrated view of EGS field development linking hydraulic fracturing with fluid circulation through fiber optic measurements. We demonstrate that advancements in downhole diagnostic tools enable the combined analysis of various monitoring data in geothermal reservoirs to provide extremely valuable insights into the geometry and connectivity of hydraulic fractures in geothermal wells thereby allowing us to optimize EGS design and performance.