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Chapter 5 Subsurface System Design Issues and Approaches • Methods for coping with flow short circuits. An important area for engineering research is the 520 development of methods for dealing with flow short circuits that may develop during operation of the EGS reservoir. A better understanding of this will allow fluids to be directed to specified parts of the reservoir, and will prevent excessive water loss. The oil and gas industry uses fluids with controlled viscosity to accomplish some of this. Currently, the temperature limit for fluid additives to control rheology is about 175°C (350°F), well below the target temperature of 200°C for highgrade EGS projects. Increasing oil prices have resulted in renewed interest in extending the temperature limits for these fluid additives as highertemperature oil and gas fields become economical to produce. As a result, maximum temperatures for fluid additives have been increased through research by the petroleum industry. There may be other areas of research that can result in reduced risk of short circuiting, or in managing sections of the wellbore to shut off preferred pathways. Pressure management of the reservoir may be useful for longterm control of both fluid loss and too short fluid pathways causing excessive cooling. • Strategy for dealing with formation temperature decline. The current strategy for coping with temperature drop in the system is to replace the cooled fracture volume with new fractured rock. This can be accomplished by drilling new wells into previously unfractured rock or by drilling legs from existing wells into rock previously fractured but not accessed by circulation. In largescale, commercial systems, the well spacing and pattern would be designed to take advantage of as much of the created or enhanced reservoir as possible, so that no upfront fracturing cost would be wasted. However, there is bound to be some volume that is not swept on the edges of the system, which could be accessed either by redrilling wells, or by drilling new wells. The ongoing reservoir maintenance of a commercialsize system with many well groups and circulation cells would require adding new reservoir fracture area at regular intervals to maintain temperature and flow rate to the plant. This becomes part of the cost of maintaining the reservoir. • Development of hightemperature downhole tools. While downhole tools have been developed that can be used to measure temperature, pressure, flow, and natural gamma emissions on a shortterm basis, these instruments cannot be left in the well for longterm monitoring. In addition, tools for microearthquake monitoring are limited to temperatures below 120°C. New generation downhole tools need to withstand temperatures of more than 200°C for extended time periods to be useful for monitoring over the lifetime of the reservoir. • Better understanding of rock/water interactions. One important area of ongoing research is prediction and monitoring of rock/water interactions (for example, see Moller et al., 2006). Although our understanding of the chemistry of rock/water systems has improved, we are still working on predictive models of longterm behavior in an EGS operation. Past EGS field experiments have yielded only scant information on rock/water interaction because of their limited duration. Data are available from deep petroleum industry wells, but these data have not been collected and analyzed for their relevance to EGS development. Control of scale formation and rock dissolution in the reservoir are areas for technology enhancement through research. Whereas scale and corrosion in wells and surface equipment can be controlled using methods developed by the hydrothermal industry, this has not been attempted in the reservoir itself.PDF Image | Subsurface System Design Issues EGS vs. Hydrothermal Pool
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