We introduce a hybrid two-stage energy-recovery approach to sequester CO2 and produce geothermal energy at low environmental risk and low cost by integrating geothermal production with CO2 capture and sequestration (CCS) in saline, sedimentary formations. Our approach combines the benefits of the approach proposed by Buscheck et al. (2011b), which uses brine as the working fluid, with those of the approach first suggested by Brown (2000) and analyzed by Pruess (2006), using CO2 as the working fluid, and then extended to saline-formation CCS by Randolph and Saar (2011a). During stage one of our hybrid approach, formation brine, which is extracted to provide pressure relief for CO2 injection, is the working fluid for energy recovery. Produced brine is applied to a consumptive beneficial use: feedstock for fresh water production through desalination, saline cooling water, or make-up water to be injected into a neighboring reservoir operation, such as in Enhanced Geothermal Systems (EGS), where there is often a shortage of a working fluid. For stage one, it is important to find economically feasible disposition options to reduce the volume of brine requiring reinjection in the integrated geothermal-CCS reservoir (Buscheck et al. 2012a). During stage two, which begins as CO2 reaches the production wells; coproduced brine and CO2 are the working fluids. We present preliminary reservoir engineering analyses of this approach, using a simple conceptual model of a homogeneous, permeable CO2 storage formation/geothermal reservoir, bounded by relatively impermeable sealing units. We assess both the CO2 sequestration capacity and geothermal energy production potential as a function of well spacing between CO2 injectors and brine/CO2 producers for various well patterns and for a range of subsurface conditions.