Management of the Balcova–Narlidere geothermal reservoir, Turkey

Management of the Balcova–Narlidere geothermal reservoir, Turkey The 2000–2005 management and field monitoring procedures at the Balcova–Narlidere geothermal field, Turkey are described. During that period, fluid production increased from 140 to 300 kg/s and the living space being heated grew from 0.64 to 1.6 million m 2 . The shallow (depth <160 m) injection done between 1996 and 2002 cooled the fluids being produced; the hydraulic connection between shallow production and injection wells was confirmed by tracer tests. Two deep injection wells were drilled to mitigate the problem and to increase injection capacity. Because net fluid extraction was reduced, reservoir pressure drawdown was controlled. Wells drilled after 2000 indicated that the eastern portion of the field had greater potential and yielded higher temperature fluids. After testing and establishing well flow performance, pump capacities were matched to production well capacities. Mineral scaling in wells and surface installations was brought under control reducing the annual cost of inhibitors by about US$100,000. Since all production and injection wells are located near the Agamemnon fault zone and because the capacity of the district heating system is being continuously increased, there is the risk of thermal breakthrough in the production wells. http://www.deepdyve.com/assets/images/DeepDyve-Logo-lg.png Geothermics Elsevier

Management of the Balcova–Narlidere geothermal reservoir, Turkey

Geothermics, Volume 37 (4) – Aug 1, 2008

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Publisher
Elsevier
Copyright
Copyright © 2007 Elsevier Ltd
ISSN
0375-6505
eISSN
1879-3576
D.O.I.
10.1016/j.geothermics.2007.12.003
Publisher site
See Article on Publisher Site

Abstract

The 2000–2005 management and field monitoring procedures at the Balcova–Narlidere geothermal field, Turkey are described. During that period, fluid production increased from 140 to 300 kg/s and the living space being heated grew from 0.64 to 1.6 million m 2 . The shallow (depth <160 m) injection done between 1996 and 2002 cooled the fluids being produced; the hydraulic connection between shallow production and injection wells was confirmed by tracer tests. Two deep injection wells were drilled to mitigate the problem and to increase injection capacity. Because net fluid extraction was reduced, reservoir pressure drawdown was controlled. Wells drilled after 2000 indicated that the eastern portion of the field had greater potential and yielded higher temperature fluids. After testing and establishing well flow performance, pump capacities were matched to production well capacities. Mineral scaling in wells and surface installations was brought under control reducing the annual cost of inhibitors by about US$100,000. Since all production and injection wells are located near the Agamemnon fault zone and because the capacity of the district heating system is being continuously increased, there is the risk of thermal breakthrough in the production wells.

Journal

GeothermicsElsevier

Published: Aug 1, 2008

References

  • Optimization of downhole pump setting depths in liquid-dominated geothermal systems: a case study on the Balcova–Narlidere field, Turkey
    Aksoy, N.
  • Natural polarization studies at Balcova geothermal field
    Ercan, A.; Drahor, M.; Atasoy, E.
  • Lumped parameter models for low-temperature geothermal fields and their application
    Sarak, H.; Onur, M.; Satman, A.
  • Geothermal reinjection experience
    Stefansson, V.

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