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wells when they are at the end stage of production. In this case, the reservoir pressure drops to such a low level that it cannot lift the weight of the oil/water column to the surface. By injecting a gas (such as nitrogen) into the wellbore at a specific point, the density of the fluid column can be
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acting on the flowing fluids. As the gas velocity in the production tubing drops with time, the velocity of the liquids carried by the gas declines even faster. Flow patterns of liquids on the walls of the conduit cause liquid to accumulate in the bottom of the well, which can either slow or stop gas
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to lift the liquids. Improved electrical pumps coming onto the market may enhance the effectiveness of the technology. More recently, downhole compressors are being used to increase velocity of gas flow, which in turn accelerates liquid unloading.
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in the gas. Consequently, a low volume of liquid is present in the tubing or production conduit, resulting in a pressure drop caused by
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reduced to the point that the reservoir pressure is once again able to lift fluids to the surface.
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Possible solutions to this problem include the installation of a velocity string, a
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by James Lea, Henry
Nickens and Mike Wells, Gulf Professional Publishing 2003
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barrier that the water creates. A common practice is to use a device called a
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to continuously or intermittently pump the water to the surface to remove the
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flows to the surface in a producing gas well, the gas carries
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of the gas is high enough. A high gas velocity results in a
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used to remove water or condensates build-up from producing
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66:effects on surface wellhead seals), or a
46:flow pattern in which liquids are finely
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83:The same concept is also applicable to
62:string injecting foamers (often with
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122:paper on gas well deliquification
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144:"Liquid Loading Mitigation"
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17:Gas well deliquification
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30:When
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