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Allis and Moore cally high permeability. These units represent a potential reservoir section more than 500 m thick. In addition, faults may enhance the permeability in this section of the Placid Oil well. About 20 km to the south, Hunt Energy Corp. conducted some temperature gradient drilling in the late 1970s and then drilled two geothermal exploration wells (Chovanec, 2003). The deepest well (74-23) had a temperature of 198°C at its total depth of 3308 m. The continuous temperature profile in this well is remarkably similar to the trend of corrected bottom hole temperatures (BHTs) in the two wells in the center of the valley to the north. Well 74-23 penetrated a quartz monzonite intrusion below about 1700 m depth, confirm- ing the gravity anomalies suggesting the basin is slightly deeper extending at least 20 km farther north. Based on the present information, the prospective area with attractive temperatures at about 3 km depth extends over at least 200 km2. More detailed gravity is required to better define the base of the surface fill, and some modern seismic reflection surveying is also required to image the lower-Paleozoic carbonate section (i.e., beneath the Chainman Shale) and faults such as the one suspected at 3200 m in well 17-14 (Figure 5c). Some oil industry seismic lines have been collected in this valley, but unfortunately the quality of the reflections from beneath the valley fill is poor (Schelling et al., 2013). However, based on the known potential reservoir section at 3 km depth in the middle of the valley, and the apparent uniformity of the thermal regime across the basin, even with a conservative power density of 3 MWe/km2, half of the propective reservoir area in Figure 5 may support a power plant of several hundred MWe. NVEnergy has just completed a 500 kV transmission line with 600 – 800 MW capacity, linking a substation at Robinson Summit (just west of the Egan Range, Figure 5) and Las Vegas (NWEnergy, 2014), so transmission is- sues should not be a major problem. Results similar to North Steptoe Valley are expected in many of the sub-basins identified so far by Moore and Allis (2013) as having a thermal regime that satisfies the target stratigraphic res- ervoir zone (shown in Figure 1). The ongoing evaluation of the thermal regime and stratigraphic, high-permeability, candidate reservoirs within the Great Basin is expected to reveal many more sub-basins with attractive development characteristics. Figure 5. (a) Temperature-depth trends from wells in North Steptoe Valley, with the potential reservoir interval highlighted. (b) Location of wells drilled in North Steptoe Valley; well 17-14 close to the Shell-1 well was drilled by Placid Oil. (c) Detailed lithology, porosity, and drilling events for the Paleozoic section of the Placid 17-14 well. All three figures have been slightly modified from Allis et al., (2012), where more details can be found. Temperature (°C) 0 50 100 150 200 250 74-23 (90 Days Static) 37-23 BHTs (Uncorrected) 17-14 BHT Shell Unit 1 BHT 17-14/Shell 1 USA 1 BHT USA 1 Gradient Well 01 Gradient Well 02 Gradient Well 04 Gradient Well 33 Gradient Well 54 17-14 lost circulation (2860-3040 m) 95 mW/m2 0 1000 2000 3000 Error Bars ± 10° C 95 mW/m2 4000 Potential (a) Reservoir (a) Interval (c) (b) 1014 Depth (m)PDF Image | Can Deep Stratigraphic Reservoirs Sustain 100 MW Power Plants
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