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thermal front for liquid-dominated reservoirs with different rates of production and fracture spacing and highlights the sensitivity of thermal energy recovery to average fracture spacing. For representative geothermal reservoir rock and fluid properties, the Bodvarsson and Tsang model predicts that fractured reservoirs approach the uniform energy sweep possible in porous reservoirs when the average fracture spacing is approximately 50 m. As the average fracture spacing grows, a progressively larger fraction of thermal energy in the formation is bypassed by cooler water moving along fracture paths, and the geothermal recovery factor drops (Williams, 2007; Williams and others, 2007). Although these results are suggestive of the factors that determine why less heat may be recoverable from naturally-fractured reservoirs, the Bodvarsson and Tsang model fails to replicate other important features of geothermal production from fractured reservoirs. In particular, analyses of tracer tests in active geothermal fields, as well as variations in recorded flow rates from producing fractures, clearly indicate significant variation in permeability and path length among fractures connecting injection and production wells (Shook, 2005; Reed, 2007). The chemical tracer tests yield information on the variability of flow in a reservoir that can be plotted as a curve relating flow capacity to storage capacity, or the productivity of each portion of the reservoir. Examples for the Beowawe and Dixie Valley geothermal fields are shown in figure 6. In the Beowawe field approximately 50 percent of the flow comes from the most productive 10 percent of the permeable fractures, and in the Dixie Valley field approximately 35 percent of the flow comes from the most productive 10 percent of the permeable fractures. By contrast, the uniform fracture model requires an equal distribution of flow across the entire permeable fracture network (fig. 6). The spatial distributions and hydraulic properties of real fracture networks are highly heterogeneous, and the heterogeneity manifests itself in the fundamental production characteristics yielded by the moment analysis of tracer tests. Any accurate characterization of injection and production from fractured reservoirs must be able to account for this heterogeneity. Williams (2007) investigated the use of self-similar fracture distributions in a modification of the Bodvarsson and Tsang (1982) model as a means of better representing the actual fracture flow characteristics and variations in Rg observed in producing reservoirs. One simple and effective way of characterizing this heterogeneity has been through the use of models that characterize fracture properties such as permeability through a self-similar distribution (for example, Watanabe and Takahashi, 1995). If, for example, the productivity of fractures intersecting a production well follows a self-similar distribution, this distribution is described by Nk Ckkdk , (6) where k is a reference permeability, Nk represents the number of fractures intersecting the well with permeability greater than or equal to k, Ck is a constant, and dk is the fractal dimension. 11PDF Image | Assessment of Identified Geothermal Resources
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