corrosive species and scaling in wells at olkaria ... - Orkustofnun
corrosive species and scaling in wells at olkaria ... - Orkustofnun corrosive species and scaling in wells at olkaria ... - Orkustofnun
6. POTENTIAL CORROSION BY CO 2 AND HCl 6.1 Carbon dioxide The pH of geothermal water is largely controlled by silicate hydrolysis equilibria. In some cases high concentrations of dissolved carbon dioxide (CO 2 ) in geothermal fluids could have an influence on the pH. Carbonate carbon occurs mostly as dissolved CO 2 and bicarbonate. The partial pressures of CO 2 in the deep fluid of the study areas have been evaluated with the assistance of the WATCH computer code (Arnόrsson et al., 1982; Bjarnason, 1994) version 2.1A. At Olkaria CO 2 partial pressures are quite variable being very high in the Olkaria West sector compared to the other sectors of Olkaria or 10-100 bar (Table 4 of Appendix A). In Olkaria North East they are 1-3 bar, 0.5 -5 bar in Olkaria East, and 2-4 bar in Olkaria Domes. In the reservoirs at Reykjanes and Svartsengi they are 0.5-0.9 bar and 0.6-1.7 bar respectively. At Nesjavellir the CO 2 partial pressures are even lower 0.07-0.09 bar for the wells selected (Figure 13). The carbon dioxide (CO 2 ) concentrations in high-temperature Log PCO2 100 10 1 0.1 0.01 Olkaria East Olkaria West Olkaria North East Olkaria Domes Svartsengi Reykjanes Nesjavellir 180 200 220 240 260 280 300 Temperature °C FIGURE 13: Aquifer temperature vs CO 2 partial pressures in the aquifer fluids geothermal aquifer waters are highly variable. Essentially two factors control the aquifer water CO 2 concentrations, (1) the rate of supply of CO 2 to the water from magmatic heat sources and (2) equilibration with specific mineral buffers. In the study areas these buffers include epidote + prehnite + calcite + quartz and epidote + grossular + calcite + quartz (Karingithi et al., 2006; Fridriksson et al., 2006). In Olkaria West, the CO 2 in the reservoir water is considered to be controlled by the rate of supply of CO 2 from the magmatic heat source. Another possibility is that Olkaria West is on the periphery of the Olkaria geothermal system and the fluid is peripheral, i.e. it is in outflow from the system and has developed an excess CO 2 concentration. In other parts of Olkaria and in the other study areas, CO 2 aquifer water concentrations are on the other hand controlled by close approach to equilibrium with one of the mineral buffers mentioned above. Shallow groundwaters, rich in CO 2 , may form when CO 2 -rich steam rising from the deeper reservoir condenses into such shallow water. Waters of this origin exist in Olkaria West, as evidenced by the discharge of well OW-304D. The pH of such waters could be lowered by the high CO 2 concentrations (Figure 14). Waters of this type have also been reported from Broadlands in NewZealand (Hedenquist and Stewart, 1985). Shallow CO 2 -rich groundwaters may cause corrosion on the outside of casings, at least if cementing of the casing is in adequate or if the water can dissolve the cement. 20
Concentrations of CO 2 at equilibrium between water and steam can be calculated using thermodynamic data on the equilibrium partial pressures of dissolved CO 2 and a given temperature, using Henry’s law constant. The expression used is: mCO 2 = kh*Pi, where mCO 2 = concentration of CO 2 in moles/kg, Kh = Henry’s Law coefficient, P i= Partial pressure of CO 2 at equilibrium in bars. Arnόrsson et al (1996) describe the temperature dependence of Henry’s Law coefficient given by the function: CO 2 ,g = CO 2 ,aq = -59.612 + 3448.59/T - 0.68640×10 -6 T 2 + 18.847×log T where T = Temperature in Kelvin. Upon extensive boiling of geothermal water in producing aquifers and wells, the CO 2 initially dissolved in the aquifer water is largely transferred to the steam which forms. Figures 15 and 16 show how CO 2 concentrations in the boiling water and the steam change during one step adiabatic boiling of water from selected wells in the study areas. The separated water at the surface contains 0.5-5 ppm dissolved CO 2 and the separated steam 0.2-24 ppm. These are theoretically calculated using Henry’s law constants for CO 2 at equilibrium. One might expect that the separated water would cause corrosion of mild steel due to its relatively high CO 2 content. Such corrosion is, however, generally not observed in geothermal installations. The reason is considered to be the formation of protective sulphides, carbonates and silicate coating (Jones, 1996). Log PCO2 bar a 100 10 1 0.1 0.01 Olkaria East Olkaria West Olkaria North East Olkaria Domes Reykjanes Svartsengi Nesjavellir 5 6 7 8 pH FIGURE 14: Aquifer pH vs CO 2 partial pressures in the aquifer for selected wells in the study areas Upon condensation of separated steam, CO 2 rich condensate with a relatively low pH will form (Figure 17). The pH of condensate formed from the selected wells due to CO 2 in the Olkaria West sector is lower than that formed from the rest of the selected wells in the study areas. A complication that could arise is the influence of H 2 S. The problem with CO 2 corrosion is always linked to pH and the only problem to worry about is corrosion by steam condensate. Instability of sulphide minerals rendering them less protective will contribute. 21
- Page 1 and 2: GEOTHERMAL TRAINING PROGRAMME Repor
- Page 3 and 4: INTRODUCTION The Geothermal Trainin
- Page 5 and 6: ABSTRACT The Olkaria geothermal sys
- Page 7 and 8: Page 9. CONCLUSIONS ...............
- Page 9 and 10: 1. INTRODUCTION For many countries
- Page 11 and 12: deposition does not occur at depth
- Page 13 and 14: The rate of sulphide precipitation
- Page 15 and 16: the Western Sectors. The Olkaria II
- Page 17 and 18: 46.4 MWe and 125 MWt. A shallow ste
- Page 19 and 20: 3. SAMPLING AND ANALYSIS 3.1 Sample
- Page 21 and 22: 4. FLUID COMPOSITIONS The compositi
- Page 23 and 24: 5. CALCULATION OF AQUIFER FLUID COM
- Page 25 and 26: increases the difference in tNaK -
- Page 27: The procedure for calculating aquif
- Page 31 and 32: High concentrations of HCl can be g
- Page 33 and 34: variation in chloride concentration
- Page 35 and 36: A 240°C a steam cap overlies the l
- Page 37 and 38: The solubility of CO 2 in water cha
- Page 39 and 40: where it passes through mist elimin
- Page 41 and 42: Coupon holder loosened the screws a
- Page 43 and 44: Coupon # 20 (Re-injection well): A
- Page 45 and 46: 1900 1800 C #10 Well NJ-14 1700 160
- Page 47 and 48: 0,3 13 Weeks (06-07-2005 to 14-10-2
- Page 49 and 50: 8. EVALUATION OF SCALES DEPOSITED A
- Page 51 and 52: atmospheric pressure. The results d
- Page 53 and 54: The IR spectra of scale samples #1
- Page 55 and 56: 9. CONCLUSIONS Olkaria well fluids
- Page 57 and 58: REFERENCES Allegrini, G., and Benve
- Page 59 and 60: D’Amore, F., Truesdell, A.H., and
- Page 61 and 62: Hurtado, R., Andritsos, N., Mouza,
- Page 63 and 64: Saemundsson, K., and Fridleifsson,
- Page 65: APPENDIX A: Tables with analyses, c
- Page 74: APPENDIX C: Analyses of scales and
6. POTENTIAL CORROSION BY CO 2 AND HCl<br />
6.1 Carbon dioxide<br />
The pH of geothermal w<strong>at</strong>er is<br />
largely controlled by silic<strong>at</strong>e<br />
hydrolysis equilibria. In some cases<br />
high concentr<strong>at</strong>ions of dissolved<br />
carbon dioxide (CO 2 ) <strong>in</strong> geothermal<br />
fluids could have an <strong>in</strong>fluence on<br />
the pH. Carbon<strong>at</strong>e carbon occurs<br />
mostly as dissolved CO 2 <strong>and</strong><br />
bicarbon<strong>at</strong>e. The partial pressures of<br />
CO 2 <strong>in</strong> the deep fluid of the study<br />
areas have been evalu<strong>at</strong>ed with the<br />
assistance of the WATCH computer<br />
code (Arnόrsson et al., 1982;<br />
Bjarnason, 1994) version 2.1A. At<br />
Olkaria CO 2 partial pressures are<br />
quite variable be<strong>in</strong>g very high <strong>in</strong> the<br />
Olkaria West sector compared to the<br />
other sectors of Olkaria or 10-100<br />
bar (Table 4 of Appendix A). In<br />
Olkaria North East they are 1-3 bar,<br />
0.5 -5 bar <strong>in</strong> Olkaria East, <strong>and</strong> 2-4<br />
bar <strong>in</strong> Olkaria Domes. In the<br />
reservoirs <strong>at</strong> Reykjanes <strong>and</strong><br />
Svartsengi they are 0.5-0.9 bar <strong>and</strong><br />
0.6-1.7 bar respectively. At<br />
Nesjavellir the CO 2 partial pressures<br />
are even lower 0.07-0.09 bar for the<br />
<strong>wells</strong> selected (Figure 13).<br />
The carbon dioxide (CO 2 )<br />
concentr<strong>at</strong>ions <strong>in</strong> high-temper<strong>at</strong>ure<br />
Log PCO2<br />
100<br />
10<br />
1<br />
0.1<br />
0.01<br />
Olkaria East<br />
Olkaria West<br />
Olkaria North East<br />
Olkaria Domes<br />
Svartsengi<br />
Reykjanes<br />
Nesjavellir<br />
180 200 220 240 260 280 300<br />
Temper<strong>at</strong>ure °C<br />
FIGURE 13: Aquifer temper<strong>at</strong>ure vs CO 2<br />
partial pressures <strong>in</strong> the aquifer fluids<br />
geothermal aquifer w<strong>at</strong>ers are highly variable. Essentially two factors control the aquifer w<strong>at</strong>er CO 2<br />
concentr<strong>at</strong>ions, (1) the r<strong>at</strong>e of supply of CO 2 to the w<strong>at</strong>er from magm<strong>at</strong>ic he<strong>at</strong> sources <strong>and</strong> (2)<br />
equilibr<strong>at</strong>ion with specific m<strong>in</strong>eral buffers. In the study areas these buffers <strong>in</strong>clude epidote + prehnite<br />
+ calcite + quartz <strong>and</strong> epidote + grossular + calcite + quartz (Kar<strong>in</strong>githi et al., 2006; Fridriksson et al.,<br />
2006). In Olkaria West, the CO 2 <strong>in</strong> the reservoir w<strong>at</strong>er is considered to be controlled by the r<strong>at</strong>e of<br />
supply of CO 2 from the magm<strong>at</strong>ic he<strong>at</strong> source. Another possibility is th<strong>at</strong> Olkaria West is on the<br />
periphery of the Olkaria geothermal system <strong>and</strong> the fluid is peripheral, i.e. it is <strong>in</strong> outflow from the<br />
system <strong>and</strong> has developed an excess CO 2 concentr<strong>at</strong>ion. In other parts of Olkaria <strong>and</strong> <strong>in</strong> the other<br />
study areas, CO 2 aquifer w<strong>at</strong>er concentr<strong>at</strong>ions are on the other h<strong>and</strong> controlled by close approach to<br />
equilibrium with one of the m<strong>in</strong>eral buffers mentioned above.<br />
Shallow groundw<strong>at</strong>ers, rich <strong>in</strong> CO 2 , may form when CO 2 -rich steam ris<strong>in</strong>g from the deeper reservoir<br />
condenses <strong>in</strong>to such shallow w<strong>at</strong>er. W<strong>at</strong>ers of this orig<strong>in</strong> exist <strong>in</strong> Olkaria West, as evidenced by the<br />
discharge of well OW-304D. The pH of such w<strong>at</strong>ers could be lowered by the high CO 2 concentr<strong>at</strong>ions<br />
(Figure 14).<br />
W<strong>at</strong>ers of this type have also been reported from Broadl<strong>and</strong>s <strong>in</strong> NewZeal<strong>and</strong> (Hedenquist <strong>and</strong> Stewart,<br />
1985). Shallow CO 2 -rich groundw<strong>at</strong>ers may cause corrosion on the outside of cas<strong>in</strong>gs, <strong>at</strong> least if<br />
cement<strong>in</strong>g of the cas<strong>in</strong>g is <strong>in</strong> adequ<strong>at</strong>e or if the w<strong>at</strong>er can dissolve the cement.<br />
20