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Chapter 5 Subsurface System Design Issues and Approaches 5.4 Temperature Variation with Depth The temperature gradient determines the depth of wells needed to reach specific temperatures (see also Chapter 2). Knowledge of the temperature is essential to determining the amount of heat in place and the conversion efficiency with which it can be used to generate power. The depth to the resource is a primary factor in determining the cost of the wells. To some extent, the extra cost of drilling deeper wells trades off against the benefit of reaching higher temperatures because higher temperatures result in higher conversion efficiency. Wellfield cost in hydrothermal power projects generally accounts for about 25%50% of the total project capital cost. EGS projects are associated with 56 to reduce permeability of sedimentary geothermal reservoirs, perhaps by changing the cementation of the grains. In other projects using pH lowering to control silica scale, injectivity appears to have improved over time in wells receiving the acidified fluid. of the project in determining the project economics and the ultimate amount of oil that can be recovered. On the other hand, hydrothermal geothermal projects have dealt with some of the most severe geochemical conditions on Earth and found economic methods to control scale and corrosion. Because geothermal companies are trying to operate a complex powergeneration plant attached to an even more complex natural system – while solving ongoing problems – there are few data available in the literature about their efforts to deal with the geochemistry of geothermal fluids under production. Furthermore, in the competitive marketplace, solutions to such problems are usually deemed proprietary. Governmentsponsored research in this area has quickly been absorbed by the private sector and commercialized. For instance, calcium carbonate scale in geothermal production wells, surface equipment, and in the injection wells has been controlled very successfully by use of scale inhibitors such as polymaleic acid in very small quantities. Silica scale has been more difficult to deal with. Despite research leading to several potential silicascale inhibitors, the least expensive method of controlling silica scale has been modification of pH. Acidification of the spent brine has worked to some extent, but it causes corrosion in surface equipment that then needs to be dealt with. Lowering pH probably also impacts the subsurface, but there is not much research on how the acidified fluid reacts with the rock in hydrothermal reservoirs. In some situations, high silica acidified fluids appear At Hijiori, during the longterm flow test, boiling in the wellbore and in the reservoir caused high pressure drop in the production wells that led to scale deposition and required that the wells be cleaned. At Rosemanowes, longterm circulation appeared to improve permeability in one fracture set, but it decreased heattransfer area and residence time so that a short circuit might have developed. Circulating fluid that is not in geochemical equilibrium with the rock forming the heat exchange system will have longterm impacts, both on the properties of the reservoir and on the economics of the project. Models exist to predict some aspects of rockfluid interaction. However, no EGS system has operated long enough yet to test whether the predicted behavior is observed. This is one of the areas with greatest uncertainty for EGS feasibility. Ongoing laboratory studies should help shed light on this issue, but longterm testing will be needed in several different real reservoirs to verify laboratoryscale results.PDF Image | Subsurface System Design Issues EGS vs. Hydrothermal Pool
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