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430 Chapter 4 Review of EGS and Related Technology – Status and Achievements The deviated well GPK4 (see Figure 4.13) was drilled, starting in August 2003, to a TVD of 5,105 m from the same platform as GPK2 and GPK3 into a target zone selected from the stimulation of GPK3. The bottom of GPK4 was separated from the bottom of GPK3 by about 650 m (a total deviation of some 1,250 m). The well was not completed until early 2004, because of problems with the mud motor, directional control, low rates of penetration, and an accident while running a casing string. During drilling of GPK4, the reservoir was tested by injecting into GPK3 and producing from GPK2. The tests established there was an excellent connection between the two wells with productivity index of 3.5 kg/s/MPa. Pressure response was observed in GPK4 during injection into GPK3. 4.7.2 Lessons learned at Soultz During testing and stimulation of GPK2 and GPK3, it became more apparent that a small number of induced seismic events were being felt by the local population. No damage was done, but the potential for larger events was unknown, and experiments were conducted to determine what conditions generated the larger events and whether they could be controlled. It was found that by using “soft” shutins after injection or production, the number of large events was reduced. Following completion, GPK4 was stimulated by injecting heavy brine to encourage development of deep fractures. While an area of enhanced reservoir developed, a linear aseismic zone was apparent, separating GPK4 from the other two deep wells. Despite a second stimulation and acidizing, no good connection yet exists between GPK4 and the rest of the reservoir. The injectivity index for this well is good, but the well is not wellconnected to the other two. The aseismic area might be a conductive fracture that prevents pressure buildup, or a barrier to fluid flow of some kind. It appears to limit the connection between GPK4 and the rest of the created reservoir, although the connection has not been thoroughly tested. Other experimental data suggest that it may be possible to inject into more than one well simultaneously to build up pressure in the EGS reservoir far from the wellbores (Baria, 2006). This and other measurements and testing of the connectivity between the wells is planned for the future. The Soultz project clearly benefited from the experience gained in other HDR/EGS projects, because it successfully created an artificially stimulated reservoir of commercial size, but with production rates still about a factor of 2 or so below required levels for a firstgeneration economical power plant operation. The Soultz project demonstrated that large fractured volumes could be created repeatedly in rock containing preexisting natural fractures that are ready to fail in shear. • Large overpressures are not needed to extend the reservoir, and fairly high productivity and injectivity can be created. • Natural fractures and the natural connectivity of these fractures seem to dominate the enhanced reservoir system. • Natural fractures can be stimulated, but there seems to be little data to support the creation of a totally artificial reservoir when no natural fractures are present. • The point at which stimulation commences in an open wellbore – and then becomes focused – depends on existing conductive fractures, the stress gradient, and fluid density.PDF Image | Review of EGS and Related Technology
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