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5.13 Conclusions – Stimulation Technologies and Estimated Costs Chapter 5 Subsurface System Design Issues and Approaches The life of the reservoir is largely controlled by the effective surface area and the total volume of rock that the circulating fluid accesses. However, other factors affecting the lifetime of the system include the amount of short circuiting of fluid between injection and production wells, the quantity of water permanently lost to the surrounding rock, and the amount and severity of seismic activity generated during reservoir operation (if any). The development of preferred pathways in the reservoir through which fluids can bypass portions of the fracture rock mass (termed “short circuiting”) is one of the major challenges facing EGS system development. To measure short circuiting, tracer testing with numerical modeling will probably yield the best metric, but more research work needs to be done in this area. The metric adopted here is the ratio of the volume of tracerdoped water before breakthrough to a producer to the total reservoir effective volume. The larger this ratio is, and the closer it is to the reservoir porosity (usually 1% to 7% for fractured hard rocks), the less the short circuiting. 519 Buoyancy effects due to the density difference between the hot production and colder injection wells work to reduce the pumping work required for fluid circulation. Given that many EGS systems will involve deep reservoirs, this effect can have a significant impact on overall system performance. Buoyancy causes a pressure gain which, in principle, can be large enough to cause the system to “self pump” as a result of a thermal siphon effect. For example, for a 250°C reservoir at 6 km, the net buoyancy gain could be as large as 10 MPa (1450 psi). Therefore, if the pressure drop in the circulating system – due to frictional losses in the wells and impedance within the fractured formation – was less than 10 MPa, the system would selfpump. Loss of fluid to the reservoir determines how much cold fluid must be added as the system is produced. Because makeup water may be expensive, low fluid loss is desirable. Minimal loss is also desirable from other considerations. Fluid that has circulated repeatedly through the reservoir will eventually come to chemical equilibrium with the reservoir rocks, neither dissolving nor depositing minerals. Also, makeup water will be colder than water injected directly from the surface plant, so addition of large amounts of makeup water will hasten the cooling of the rock volume. The analysis presented in Chapter 2 indicates that the heat stored in the earth to depths that are accessible with today’s technology is truly vast. However, the fraction of this resource base that can be economically recovered is dependent on increased understanding of reservoir behavior and, therefore, is directly connected to current research and testing of EGS. Here, we present some of the pressing needs to advance the state of the art in EGS reservoir technology. • Assessing the size of the stimulated volume and heattransfer area. Being able to determine the heat exchange area and the volume of the fractured rock in an EGS reservoir is an important part of stimulation design and operation. Conservative tracers, thermally and chemically reactive tracers, natural fluid tracers, microseismic monitoring, active seismic measurement, and advanced forms of reservoir tomography such as muon tomography are areas with potential for determining the size of the resource accessed, and for targeting and drilling further production and injection wells.PDF Image | Subsurface System Design Issues EGS vs. Hydrothermal Pool
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