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very high backpressure, and then for 8 hours at a very high flow and a low backpressure (Brown and DuTeau, 1995). During the 1993 cyclic testing, the pressure at the injection well had been maintained at about 27.3 MPa by injection at a controlled, but variable, rate. The most striking feature of the 1993 cyclic production testing was the degree of enhanced production flow that was obtained for a period of 8 hours each day -- an average of about 9.15 l/s compared to a previous steady-state level of 5.7 l/s near the end of the LTFT in April 1993, for very similar injection conditions Funding limitations prevented further experimental investigation of this enhanced flow phenomenon until the summer of 1995. Fluid Storage in Pressurized Joints Near the Production Well. Based on the results of extensive transient and steady-state flow and pressure testing over the past 10 years, it is apparent that the HDR reservoir at Fenton Hill is comprised of a sparse, multiply interconnected set of open joints in a very large volume of hot crystalline rock. The ratio of fluid to rock volume is of the order of 10-4 Within the body of the HDR reservoir, fluid is stored primarily in dilated joints which are mostly jacked open by fluid pressures that are well above the least principal earth stress. Therefore, the major part of the reservoir fluid storage arises from the elastic compression of the rock blocks between pressurized joints. The pressure gradient across the body of the reservoir, from the inlet to near the outlet, is reasonably gradual However, within the 10-m ± region surrounding the production wellbore, the pressure gradient steepens markedly as the pressure drops to the level of the imposed pressure in the wellbore (imposed by the backpressure regulating valve at the surface) As a result, the joints are progressively more tightly closed by the earth stresses as the flow converges toward the pressure sink represented by the production wellbore This near-wellbore pressure gradient for the production well can be inferred from the set of transient shut-in pressure recovery profiles shown in Figure 4 (DuTeau and Brown, 1993) Figure 4 Transient Shut-in Pressure Profiles for the Injection and Production Wells. This figure shows that when the production well was suddenly shut-in, the pressure measured at the surface (a direct measure of the downhole reservoir outlet pressure) rose from 9.65 to 20.7 MPa in less than 3 minutes, indicating that this high pressure level existed in the joint network very close to the production wellbore. 11PDF Image | Hot Dry Rock Geothermal Energy Development in the USA
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