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Subsurface System Design Issues and Approaches Chapter 5 5. Comprehensive mapping of the fracture or shear fracture cluster during hydraulic fracturing through monitoring of microearthquakes. This requires installation of a network of three component seismometers in boreholes drilled into fairly solid rock and, if possible, into the basement rock. Prior to drilling the second well in the prospect, the above collection of information should be thoroughly analyzed. Tests that obviously do not yield worthwhile information should be discarded. Test procedures that yield questionable information should be revised. In cases where information requirements emerge by virtue of the existing test results, additional test procedures should be developed to obtain such information. A test program should then be developed for the second prospective well. This process should be repeated for subsequent wells in the project. Once a deep well is completed, geophysical logs will be required to quantify the temperature profile, joint network data, in situ stress profile, sonic log, etc. In a hightemperature environment, the well may need to be circulated and cooled before these logs (except for a temperature log) can be carried out. The only useful temperature information obtained during drilling, or just after drilling, is the bottomhole temperature, as the temperature profile higher in the well will be affected by the cooling caused by the drilling. Even the bottomhole temperature may have some cooling if there is permeability on the bottom. It may take up to three months after the drilling is completed for the temperature to reach the natural equilibrium. Following the assessment of the in situ conditions from geophysical logs, smallscale injection tests (as seen at Cooper Basin in Figure 5.2) will be required to assess undisturbed hydraulic properties of the open section of the well. The quantity of water and the pressure required will depend on the state of existing flowing joints and tightness of the formation. Estimation will be made on the requirement of the water for these tests. The following tests are appropriate for evaluating the natural state of the reservoir for permeability/transmissivity and other hydrologic properties: i. Slug test A slug test involves an impulse excitation, such as a sudden withdrawal/injection of a weighted float, or a rapid injection of a small volume of water. The response of a wellaquifer to that change in water level is then measured. The slug test will also give information required to design the subsequent low rate injection test. The total amount of water used is negligible i.e., in the range of 25 m3. ii. Production test Producing formation fluid will yield important information for the future heat exchanger about the P–T conditions in the reservoir. Furthermore, the fluid chemistry and the gas content are important parameters in designing the pilot plant to minimize scaling and corrosion. These are two good reasons to perform a production test at a time when the fluid surrounding the well is not yet disturbed by a major injection. A well can be produced by using a buoyancy effect or a downhole pump. It is preferable to use a downhole submersible pump where possible. A submersible pump can be deployed at a depth of about 100150 m. Depending on the outcome of the slug test, it is probable that the well could produce nearly 1 m3/hr, which may be sufficient to get several wellbore volumes of fluid in a reasonable time of a few weeks. Additionally, a downhole pressure gauge, gas sampling (or gas trap) at the wellhead, and a surface flow meter, would add further information on the drawdown characteristic of the well. 525PDF Image | Subsurface System Design Issues EGS vs. Hydrothermal Pool
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