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Chena Geothermal Power Plant Project Final Report Prepared for the Alaska Energy Authority January, 2007 7.4 Geothermal Injection System Developing a successful injection strategy is integral to the success of any large scale geothermal project. Chena has been working on characterizing its wells for nearly 2-1/2 years, largely in anticipation of minimizing the stresses placed on the reservoir due to this power generation project (see Section 3) Initial injection candidates Well#1 and Well#2 were chosen primarily due to their distance from the proposed production area. However, additional testing during this Quarter has shown that while these wells are both unequivocally linked to the geothermal system/ reservoir, both have low injectivity indexes which make them poor candidates for injection of any substantial volume of fluid under the low wellhead pressures planned. In fact, further testing of Well#1 showed it was capable of drinking only 20-30gpm, and so it was eliminated as an injection site. Well #2, cased to 300ft and open hole to 820ft is being used for injection, but is capable of drinking less than 100gpm. This well has been well characterized in terms of fracture zones. TG#7 has replaced Well#1 as the primary injection well. This well was drilled to 702ft, and injection testing conducted in December 2005 indicated a very high injectivity index which has subsequently been verified through actual injection of spent fluid. The well was cemented in July, 2006 and has been used successfully for injection ever since the first unit began operating. The geothermal field is still being monitored, and changes to the injection strategy over the long term is expected to minimize cooling of the resource. A map showing the locations of all the existing wells and TG (temperature gradient) holes at Chena is included on the following page. 26PDF Image | 400kW Geothermal Power Plant at Chena Hot Springs
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