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(131°C) and a gas content of 29 cubic feet per barrel. At this production rate (600 Mcf/day) the natural gas produced with the geopressured brine is roughly two and a half times higher than the average (230 Mcf/day) natural gas well in Texas.25 The five-year geopressure well test revealed a large sandstone aquifer estimated to contain enough fluid for a three MW power plant to operate at least 10 years.26 Other wells used in the DOE “Wells-of-Opportunity” program (oil and gas wells drilled by industry and used for short-term tests) revealed that the brine in Gulf Coast deposits contained natural gas in quantities close to saturation. Results showed that it is feasible to produce brine at rates of thousands of barrels per day and to inject the spent brine into relatively shallow saline aquifers for disposal without adverse environmental impact.26 The temperatures prevailing within this large geopressure reservoir represent a significant amount of heat. It has been estimated that over 5,100 EJ are contained within the Texas sandstone deposits.37, 28 Uncertainties remain about the reservoir mechanics, particularly the capability of these aquifers to produce brine for extended periods of time, and the amount of energy recoverable. Models of conventional reservoir dynamics must be modified to account for the pressures prevailing in geopressurized zones and the system interconnectivity through faults. The hot brine temperatures (200 to 400°F (93—204°C) could be best used for binary cycle conversion power plants. There are other, less studied geopressured reservoirs in Texas. The geopressured Delaware Basin of West Texas (Exhibit 7-3) extends from 8,000 ft to a depth of nearly 30,000 ft (2.4—9 km), with pressures of 0.65 to 0.94 psi/ft and temperatures from 140 to 400°F (60—200°C).31, 32 Recent funding by the DOE and SECO assisted in expanding existing data to over 5,000 wells and over 8,000 temperature-depth points for analysis as part of an investigation of the Delaware and part of the Val Verde Basins.31, 32 The counties included in this study are Ward, Loving, Winkler, Reeves, Pecos, Terrell, Crockett and Hudspeth. Analysis of the temperature data suggests there is complex variability in the thermal gradient throughout the region. Numerous strata from the Devonian 31 formation through the Ordovician Ellenberger formation show porosity and permeability sufficient for heat extraction for absorption chillers and electrical power generation. A small fraction of the Anadarko Basin extends into the Panhandle of Texas from Oklahoma (Exhibit 7-3). The basin contains between 6,000 to 30,000 ft of sediment and has a fluid-pressure range of 0.52 to 0.85 psi/ft, and a temperature range from 140 to 425°F (60—220°C).32 A recent geothermal investigation of South—Central U.S., including this basin, has been conducted by Negraru, Blackwell, and Erkan, (2008).49 Coproduced and Stranded Resources Within sedimentary basins, two distinct geothermal resource categories are found: coproduced and stranded.31, 32 Stranded geothermal resources are geothermal fluids left in an oil and gas field after the extraction of hydrocarbons is completed. Oil and gas companies try to avoid water production due to the additional expenses for separation and disposal. This resource estimate is included in the overall geopressure and Enhanced Geothermal Systems (EGS) estimates, but is unique in that it is a resource known in detail from drilling, but currently being avoided by oil and gas companies rather than developed. The use of horizontally drilled wells are specifically of interest in developing Texas geothermal resources, since their large intercepted area makes them good heat exchangers for EGS designs. Coproduced fluids occur when oil and/or gas is pumped from a well along with hot water and economically extracting all of them at the same time. In these cases the well produces adequate hydrocarbon volumes for the well to remain economical with the additional expense of water disposal. In other instances, a well is drilled primarily for gas but the reservoir is water wet and the gas is dissolved in the water. Production of the gas results in excessive amounts of water. If the water is sufficiently hot (~200°F/93°C or more) and the flow volume is suitably high, then electric power can be produced. By developing electrical energy from these fluids, it extends the life of the well through the value added of the electricity. Temperatures at 10,000 to 12,000 ft (3 to 3.7 km) have been calculated using uncorrected bottom-hole temperatures from oil and gas well logs (Exhibit 7-4). Actual temperatures in the ground are normally higher than the well log bottom-hole temperature because the circulation of drilling fluids cools the deep formations. The Permian Basin is the coldest region with temperatures starting at 120°F (49°C) at 10,000 feet (3 km). South Texas has the highest temperatures at 10,000 ft, reaching 282°F (138°C) (Figure 8.3).36 At 12,000 ft (3.6 km) the South Texas uncorrected temperatures reach 318°F (159°C). The areas shown in yellow to brown are zones with the highest initial potential for stranded and coproduced geothermal resources. McKenna et al. (2005)34 point out that numerous states produce substantial amounts of water in conjunction with hydrocarbon production. In Texas, approximately 12 billion barrels of water (1 barrel equals 42 gallons) are produced and injected each year. If this coproduced water has temperatures of 212°F (100°C), then over 1,099 MW of electrical power could be generated from the heat extraction before the water is reinjected into the ground.39 This is enough energy to power at least 275,000 homes. Texas Renewable Energy Resource Assessment Geothermal Energy 7-7PDF Image | GEOTHERMAL ENERGY Texas
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