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Innamincka. The stimulation followed an exhaustive re-design of the Jolokia 1 completion following the Habanero 3 casing failure in 2009. Although temperature and stress conditions were determined as expected, the stimulation was less successful than predicted. Injectivity was low and higher pressures, afforded by concentrated brine, were needed to achieve a rate of injection capable of returning micro-seismic activity. Despite the overthrust stress environment, only steeply dipping fractures were activated. It was concluded that optimally oriented, shallowly dipping fractures were not available in the depth interval stimulated (between 4,325 m and TD of 4,911 m). 23.2 Status of Geodynamics‘ Geothermal Activities in 2010 Jolokia 1 was drilled in 2008 as part of a program to extend the size of measured geothermal resources in the Innamincka granite by showing that reservoirs similar to the one at Habanero could be successfully stimulated. The well was drilled with mud weights kept slightly below the reservoir pressure determined at Habanero, with the aim of detecting permeable fractures during drilling and then sealing them with cement so that drilling could continue. Only one permeable fracture was detected at a depth of 3,822 m and the well was drilled to a depth of 4,911 m. An objective of Jolokia 1 was to show that reservoirs could be created at deeper levels than the one at Habanero and also that multiple reservoirs could be created in the same well. Logging during 2008 had indicated possible fracture zones at 4,400 m and 4,700 m, and these were targeted for the formation of two reservoirs. However, qualified high temperature open-hole packers required to undertake this operation were not available in 2008. It was thought that such qualification was possible within a short time frame (6-12 months) so it was decided that another well would be drilled before Jolokia 1 was stimulated. The rig was moved to Savina 1 a further 10 km west. The well failure at Habanero 3 on 24 April 2009 occurred after suspension of Savina 1and while the preparation for the Jolokia stimulation was in progress. The failure resulted in a re-design of the well with two completion strings in the upper part of the well and a liner set to 4,350 m as originally envisaged, a very complicated completion. The well was re-entered on 4 July 2010. Initially caliper and image logs were run before the setting of the lower liner. Temperature logs were also run during the logging and liner deployment operations. Successive logs gave slightly higher temperatures indicating the well was not quite in thermal equilibrium from liner deployment activity. The log giving the highest temperature went to a depth of 4,590 m and gave a measured temperature of 263.5 °C. This temperature projects to 275°C at TD and 278°C at 5 km depth. The stimulation lasted from 23 October to 4 November 2010, and a total of 530 m3 of concentrated sodium chloride brine and 20.5 m3 of concentrated sodium bromide brine were injected. During the injection of the sodium chloride brine the injection pressure at the liner shoe was estimated at 112 MPa. At this pressure, seismicity was occurring on steeply dipping fractures as indicated by focal mechanism analysis, but injectivity remained low. During injection of sodium bromide the pressure at the liner shoe increased to 122 MPa and the injection rate increased to 7 l/sec indicating that one or more of the stimulated fractures was opening in a tensile mode. The minimum horizontal stress at 4,350 m was determined to be 117 MPa, considerably higher than the vertical stress of 98 MPa, thus confirming the overthrust stress environment determined at Habanero. During the stimulation of Jolokia, a total of 140 seismic events were located, and since then the number has risen to over 200 (latest catalogue dated 14 March 2011). The highest magnitude event (ML 1.6) occurred on 27 February 2011, 115 days after the stimulation was completed. The evidence of high injection pressures being required and events continuing long after the stimulation was complete indicates that the reservoir is tightly confined with pressure leak-off very slow. This 269PDF Image | Geothermal Research and Tech IEA
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