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Coproduced Resources Coproduced geothermal resources are directly integrated into the production of oil and gas. Coproduction uses a well for the purpose of both the extraction of oil and/or gas and the heat from the fluids for electricity. The electricity can be used on-site or sold to the grid. Traditionally the fluid (brine) is trucked off or directly reinjected at an expense to the project. Locations where the fluids are directly injected on-site are the “low hanging fruit” for coproduction sites. The business plan incorporates the brine water as an economic commodity to allow for longer hydrocarbon production from a well. This type of development is the best case scenario for the utilization of the geothermal resource from an oil and gas field because of the minimal additional expense - primarily the installation of binary turbines. Fields which currently use waterflooding to increase hydrocarbon production from deep formations could be an initial focus point for geothermal development. The second scenario for coproduction is the end of the life of oil and/or gas wells or “stripper’ wells. In these cases the well produces adequate hydrocarbon volumes to be economically viable until at some point of increasing production of brine water it is no longer economic. Rather than abandoning the well, to keep it economical the well could be converted to coproduction to recover the additional expense of the produced brine. This conversion allows a greater percentage of the hydrocarbons from the field to be extracted while producing a renewable energy to run field applications and/or to sell to the grid. For the transition from an oil/gas well to a coproduced well, additional treatment of the well may be necessary since the quantity of fluid needed for geothermal electrical production is often much greater than the capping/abandonment point for oil/gas wells. The third scenario is to work with oil and gas companies drilling new wells. When a well is drilled that produces too much water to develop as an economic hydrocarbon well, the well would be immediately completed as a geothermal well to maximize water production and the electrical power capability. Lastly, as oil and gas fields are developed, drilling is designed to avoid all formations with water and to perforate only the zones with hydrocarbons. Because of this pattern, the geothermal resources (brine water) are left behind, “stranded” (Erdlac, 2008). The extent of stranded water in Texas fields is not readily determined because companies are not focusing on those zones and records of possible water production are not required by the Texas Railroad Commission. The 47PDF Image | Texas Geothermal Assessment for the I35 Corridor East
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