For years, hydrocarbon dewpoint (HCDP) has been used as the industry’s measure of “dry gas.” The problem is that dewpoint measurements assume the gas and liquid phases in a pipeline are in equilibrium, the same calm conditions found in a lab flask.
Real pipelines do not behave like that. Gas typically moves at 20–100 ft/sec, while liquid films or droplets creep along the pipe wall at less than 1 ft/sec. They never reach equilibrium.
The result? An analyser or equation of state can report a dewpoint of –40 °C, while liquids are simultaneously flowing into compressors and downstream equipment. This creates an unsafe blind spot: operators believe they are moving dry gas, while liquid carryover causes millions in pigging and disposal costs, and suppliers lose millions in condensates to the gas line.
Visual systems like LineVu are now showing the industry what is really happening inside the pipe and why it is time to move beyond dewpoint to answer the question, “is my gas wet or dry?”
LineVu reveals contamination in high-pressure natural gas systems that until now has gone undetected. Despite commercial and legal contracts requiring that no liquids or solids enter a gas network, liquid contamination is a common cause of damage to power stations and other plant worldwide.
By monitoring the efficiency of gas/liquid separation systems, the patented LineVu system provides safety and financial benefits that were previously unattainable.
Paul Stockwell, managing director, Process Vision