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58 5.8.1 Site selection Chapter 5 Subsurface System Design Issues and Approaches 5.7 Susceptibility to Induced Seismicity 5.8 Remaining Issues for Successful Stimulation One of the other aspects of project economics and of project feasibility is the potential of the site for induced acoustic emissions (Batchelor et al., 1983). At the best potential EGS sites, rocks are critically stressed for shear failure, so there is always the potential for induced seismicity that may be sufficiently intense to be felt on the surface. With current technology, it appears feasible that the number and magnitude of these induced events can be managed. In fact, based on substantial evidence collected so far, the probability of a damaging seismic event is low, and the issue – though real – is often one more of public perception. Nonetheless, there is some risk that, particularly in seismically quiet areas, operation of an EGS reservoir under pressure for sustained periods may trigger a felt earthquake. As a result, the potential for seismicity becomes an environmental factor for determining the economics of EGS project development. This and other environmental factors that would control siting of potential EGS projects are discussed in Chapter 8. 5.8.2 Instrumentation At our current level of understanding and with the technology available for stimulating potential geothermal reservoirs, preexisting fractures with some connectivity in the far field are needed to develop a connected system that can be circulated. The fractures need to be oriented with respect to the stress field in such a way that they will fail in shear; this is the case over a wide range of geologic and tectonic conditions. We can stimulate connected fractures and improve permeability. Exploration methods that can effectively tell us the stress field at depth from the surface are not currently available. We can use GPS and satellite imaging to locate and map more regional stress regimes, but it is very difficult to predict the downhole stress patterns and how they will vary with depth. Few wells have been drilled to deep depths in the areas of highest heat flow. Those wells that have been drilled to deep depths are generally oil and gas wells, and the stress data are proprietary for the most part. The heat flow data we have are limited and not very detailed. Unless an area has been extensively explored for geothermal energy, the detailed temperaturewithdepth information that we need for siting EGS exploratory wells is not available. While oil and gas wells are often logged for temperature as part of the normal assessment process, these data are again proprietary and not available. Evaluation of the geothermal system requires drilling, stimulation, mapping of the stimulated area, and then drilling into the stimulated area. Borehole imaging prior to and post stimulation is a necessity for understanding and assessing the potential system, and for design of the stimulation. Once we have drilled a well, if the rock temperature is above 225°C, the use of borehole imaging tools for characterizing natural fractures and the stress regime will require precooling of the borehole. Instrumentation for borehole imaging is difficult to protect from borehole temperatures because data passthroughs permit too much heat gain from the hot borehole environment. Hightemperature electronics that would extend the temperature range for all kinds of instrumentation for use in geothermal situations need to be developed and applied to downhole logging tools and drillingPDF Image | Subsurface System Design Issues EGS vs. Hydrothermal Pool
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