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00118 MODELING OF SCALE DEPOSITION IN GAS WELLS WITH VERY SALINE PRODUCED WATER

Picture for 00118 MODELING OF SCALE DEPOSITION IN GAS WELLS
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Product Number: 51300-00118-SG
ISBN: 00118 2000 CP
Author: Patrick J. Shuler, Eric J. Daniels, Liz Burton, Huey-Jyh Chen
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One of the challenges in the operation of gas wells with co-produced water is downhole and surface facility scale deposition. Scale deposition problems such as reduced tubing size are more likely when the produced water is very saline, and the pressure/temperatures changes are large. In addition to the common scales such as calcium carbonate, more exotic scales such as lead and zinc sulfide and calcium fluoride may occur. Halite formation is a special concern for low water volume wells where water absorption by the gas due to pressure/temperature changes cause salt to drop out. This paper presents model predictions of changes in scaling conditions over the life cycle of typical gas wells completed in the Norphlet trend in Mobile Bay. These gas wells produce salt-saturated formation brines containing significant heavy metals from reservoirs with very high bottom hole temperature/pressures (in excess of 400 °F [205 °C] and 15,000 psi [ 1.03 E05 kPa]). The study results are consistent with the field observations of scale problems in these gas wells. Model results help identify zones along these very long wellbores that are most susceptible to scaling problems, and when during the life of the well scaling problems are most likely to occur. Thus the model is useful for determining when and where injection of fresh water or chemicals in the well could be an effective scale control measure.
One of the challenges in the operation of gas wells with co-produced water is downhole and surface facility scale deposition. Scale deposition problems such as reduced tubing size are more likely when the produced water is very saline, and the pressure/temperatures changes are large. In addition to the common scales such as calcium carbonate, more exotic scales such as lead and zinc sulfide and calcium fluoride may occur. Halite formation is a special concern for low water volume wells where water absorption by the gas due to pressure/temperature changes cause salt to drop out. This paper presents model predictions of changes in scaling conditions over the life cycle of typical gas wells completed in the Norphlet trend in Mobile Bay. These gas wells produce salt-saturated formation brines containing significant heavy metals from reservoirs with very high bottom hole temperature/pressures (in excess of 400 °F [205 °C] and 15,000 psi [ 1.03 E05 kPa]). The study results are consistent with the field observations of scale problems in these gas wells. Model results help identify zones along these very long wellbores that are most susceptible to scaling problems, and when during the life of the well scaling problems are most likely to occur. Thus the model is useful for determining when and where injection of fresh water or chemicals in the well could be an effective scale control measure.
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