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requirements for well completion reporting, and the relatively wide availability of these data, results in a much higher degree of certainty regarding site-specific conditions to inform simulation assumptions. In addition to the enormous value of the existing data, the wells themselves represent a considerable stock of stranded capital. While many wells have already been plugged and abandoned, many others are approaching their required closure dates, should production not resume in the interim. Leveraging this infrastructure for energy storage during periods of low commodity prices that make the wells uneconomical to produce could preserve the wells for future use, should CAES wells be revised for reversibility. For wells that will not be produced again, more permanent revision options could allow field operators to derive additional value from sunk and heavily depreciated capital. 1.3 Hybrid GT-CAES Conventional CAES projects use stored air to increase efficiency in a natural-gas-fired power cycle by preheating the compressed air with gas and introducing it directly into the expansion (power) turbine. Previous evaluations have considered both natural-gas-based CAES facilities and geothermally driven configurations using subsurface reservoirs for compressed air storage (McGrail et al., 2015). Due to the difficulty of finding both a geothermal resource and a thick, permeable subsurface storage reservoir with high porosity and some degree of structural closure consistent with the configuration(s) evaluated for reservoir-based storage, this study considers using abandoned or existing, low-production geothermal wells that, when repurposed, could act as subsurface pressure vessels, replacing the need to find acceptable sedimentary-based subsurface CAES reservoirs evaluated in previous projects. The hybrid GT-CAES unit proposed could be developed and operated as a standalone unit or in complement to established steam-based power production facilities by adding unit processes for air compression, heat exchange, a backpressure steam turbine, a three-stage expansion turbine, ancillary piping, and geothermal well repurposing/refurbishment requirements. For design and costing purposes, the only substantive difference between the two (standalone vs. complementary) is a modest backpressue turbine (~520 kW), and the components (ancillary piping, instrumentation, controls, etc.) associated with that unit. For completeness, both operational configurations are addressed, captured as the functional difference between gross and net capacities and energy. As visualized, during “off-peak” hours, excess or low-cost power from the grid would be used to operate a centrifugal air compressor filling repurposed geothermal well casings to an acceptable storage pressure. During peak hours, extraction steam from an existing geothermal well or from an existing steam turbine would be used to reheat compressed air recovered from the repurposed well casings, and expanded across a three-stage expansion turbine. Though the hybrid GT-CAES unit would parasitize the existing steam turbine, due to energy supplied by the compressed air and the modest reheat steam requirements, the power output of the combined system would have a net increase of 13.4 MW as modeled, taking the traditional Rankine cycle steam system to a round trip efficiency well over 50%, contingent on the amount of extraction steam consumed. The conceptual system is illustrated in the following block flow diagram (Figure 1.1), which includes basic unit operations, process flow(s), and storage reservoirs for the compressed air and geothermal resources. 2PDF Image | Geothermally Well Based Compressed Air Energy Storage
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