Category Archives for Wellhead Surface Equipment

Surface Equipment – Wellhead Flash Gas Recovery

For each barrel of natural gasoline condensate collected in storage, roughly 1,300,000 BTU’s worth of gas is flashed-off from the low pressure three phase separator. This assumes that the high pressure separator is operating at 1000 psig and the low … Continue reading

10. October 2009 by Jack
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Surface Equipment – Orifice Meter

Permitting a wellhead meter to read high robs your employer. The royalty and severance tax payments made by the lease operator are based on the meter readings. Pulsations in the meter run (such as those induced by wellhead reciprocating compressors) … Continue reading

10. October 2009 by Jack
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Surface Equipment – Brine Tank

If the interface level controller on the low pressure, three phase separator malfunctions, a well’s entire production of natural gasoline may wind up in an open top brine holding tank. Of course, losses in hydrocarbons will be accelerated due to … Continue reading

10. October 2009 by Jack
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Surface Equipment – Condensate Tank

Maintaining the low pressure separator at too high a pressure can cause the natural gasoline condensate holding tank to over-pressure. As a rough approximation, about half a mole of gas is vented from a condensate tank for each barrel of … Continue reading

10. October 2009 by Jack
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Surface Equipment – Low Pressure Three Phase Separator

The high pressure liquid flows into the low pressure separator. Typically the low pressure vessel operates at 30 to 60 psig. Below 20 psig, there will not be enough pressure to push the accumulated liquids into adjacent tanks. Above 60 … Continue reading

10. October 2009 by Jack
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Surface Equipment – High Pressure Separator

To prevent metering difficulties, and to reduce corrosion and pressure drop in downstream piping, liquids are removed from wellhead gas. Water plus natural gasoline condensate are drawn off as a mixed phase. Gas flows out of the separator, through the … Continue reading

10. October 2009 by Jack
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Surface Equipment – Heater Operation

Why are there two chokes shown in figure 3—2. Certainly, gas flow could be controlled with a single choke. One reason is that the erosion of the choke is reduced by limiting the pressure drop through a single restriction. Note … Continue reading

10. October 2009 by Jack
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Surface Equipment – Cassing Pressure

Ideally, there should not be any gas accumulation inside the casing of a single completion well. If gas does infiltrate the annular space between the casing and the tubing, excessive pressure will build-up inside the casing. If the casing pressure … Continue reading

10. October 2009 by Jack
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Surface Equipment – Wellhead Tree

My initial impression of the collection of valves sitting atop a gas well was that the assemblage of hardware was unnecessarily complex. This turns out to be a false first impression. Both the casing and the tubing strings terminate at … Continue reading

10. October 2009 by Jack
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