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Rock-fluid interactions in the presence of an aqueous phase The natural Soultz fluid is of Na-Cl-Ca-HCO3 type and highly saline (~ 100 g/l) with a temperature of 200 °C and pressure near 600 bars at 5000 m (in GPK-1). The main chemical components of the brine have the following molal concentrations: [Na] = 1.27; [K] = 0.09; [Ca] = 0.17; [Cl] = 1.72; [Mg] = 6.38 10- 3; [SO4] = 1.26 10-3= [ Sr] = 5.66 10-3; [ Ba] = 4.97 10-4 ; [Fe] = 7.17 10-4 and [CO2]T = 0.019. The in situ conditions of pH and pCO2 and the thermodynamic equilibrium state of the Soultz brine have been assessed using the geochemical software SCALE2000 (Azaroual et al., 2004). A Pitzer approach was used for ion activities, and fugacity corrections were calculated from a new EOS formulation (Duan and Sun, 2003; Kervévan et al., 2005). The in situ pH and pCO2 are 5.0 and 5.6 bars, respectively. The circulating fluid in fractured granite with high contact surface with alteration mineral products is initially in thermodynamic equilibrium with respect to calcite, anhydrite, strontianite, siderite, mackinawite, and quartz. Fig. 9 shows CO2 solubility and pH of Soultz brine as a function of temperature at a constant CO2 partial pressure of 500 bar. Fig. 9. Temperature effect on the CO2 solubility and pH of CO2 enriched Soultz brine at 500 bar carbon dioxide partial pressure. The small variation of pH highlights the strong buffering capacity of Soultz brine. Fig. 10 gives a preliminary evaluation of saturation indices of major primary minerals at Soultz for CO2-enriched brine. It is seen that most minerals are undersaturated at lower temperatures, suggesting that CO2 injection would provide a significant potential for reservoir growth. Fig. 10. Temperature effect on the Saturation Indices (SI) of calcite, anhydrite, strontianite, siderite, quartz and mackinawite. CONCLUDING REMARKS At typical temperature and pressure conditions anticipated for EGS - approximately 200 ̊C and a few hundred bars - CO2 is a supercritical fluid with liquid-like density and gas-like viscosity. Its thermophysical properties make it quite attractive as a heat transmission fluid. Our exploratory studies suggest that CO2 is roughly comparable and perhaps somewhat superior to water in its ability to mine heat from an EGS reservoir. CO2 appears to offer advantages for wellbore hydraulics, which may lead to reduced power consumption for maintaining fluid circulation. Preliminary evaluation of the geochemistry of supercritical and aqueous CO2 suggests a potential for mineral transformations that would be accompanied by a reduction in volume, inducing porosity increase and reservoir growth. Fluid losses are an unavoidable aspect of engineered geothermal systems. Whereas the loss of water in a "conventional" HDR operation would be unfavorable and costly, fluid loss in a HDR system running with CO2 would offer geologic storage of CO2. Such storage may provide economic benefits and incentives in future carbon management scenarios. Combining EGS with CO2 storage could provide an additional revenue stream that would improve the economics of EGS. ACKNOWLEDGEMENT Thanks are due to Curt Oldenburg for a careful review of the manuscript and the suggestion of improvements. This work was supported by the Assistant Secretary for Energy Efficiency and Renewable Energy, Office of Geothermal Technologies, of the U.S. Department of Energy, andPDF Image | Workshop on Geothermal Reservoir Engineering Stanford Univ
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