Stratigraphic reservoirs are attractive candidates for geothermal power production due to their high permeability and large areal extent, compared to typical hydrothermal geothermal reservoirs. Because they are often associated with a conductive thermal regime that require greater depths to reach economic temperatures, the commercial viability of stratigraphic reservoir systems will depend on leveraging greater fluid production rates per well and on limiting the parasitic costs associated with fluid recirculation. We present an approach to address these challenges. To increase fluid-recirculation efficiency and fluid production rates, we inject supplemental working fluids (CO2 and/or N2) with advantageous properties to augment reservoir pressure. Because N2 can be readily separated from air, pressure augmentation can occur during periods of low grid power demand, which will reduce parasitic costs and enable bulk energy storage. A well pattern consisting of four concentric rings of horizontal producers and injectors is used to store pressure and supplemental fluids, segregate the supplemental fluid and brine production zones, and generate large artesian flow rates to better leverage the productivity of horizontal wells. We present simulations of this approach for an idealized reservoir model, consisting of a permeable sedimentary formation, vertically confined by two impermeable seal units. Because the parasitic costs associated with compressing and injecting supplemental fluids and brine increase with reservoir overpressure, net power production is found to be more efficient at moderate supplemental-fluid injection rates.