Natural gas is usually in contact with water in the producing reservoir and comes to the wellhead saturated with all the water vapor it can hold. It may either be dehydrated at the wellhead or brought into the plant wet
Removing most of the water vapor from the gas is required by most gas sales contracts. because it prevents hydrates from forming when the- gas is cooled in the transmission and distribution systems and prevents water vapor from condensing and creating a corrosion problem. Dehydration also increases line capacity marginally. This course is designed to provide necessary information and practice for such activities.
State four major reasons for removing water from gas distribution systems.
State the specification of water content in gas for the transport of gas in pipelines.
Using the correct graph and given the gas conditions of pressure and temperature, calculate the water content of the gas.
List the requirements for hydrate formation and describe how hydrates are produced and the dangers of hydrate formation.
State hydrate removal/prevention methods.
Describe and list routine checks and tasks on the equipment.
Explain the adsorption process.
Who Should Attend?
Process operations professionals.
Field & DCS operators.
Petroleum & chemical engineers.
Oil & Gas Treatment technicians.
The Course Content
Day One: Fundamentals & Principles
Introduction to gas dehydration (what, why )
The water content of natural gas and Dewpoint concept
Gas Hydrates (formation, removal, prevention )
Dehydration Methods ( liquid and solid desiccant, comparison )
Day Two: TEG: Process description & Main Equipment
Absorption & Striping principle
Absorption column ( Contactor ) and regenerator
Pressure reduction valve & Flash tank
lean/ rich Heat exchanger & Filters
Reboiler & Reflux drum
Day Three: TEG: Operation & Control
Dehydration Unit start-up
Dehydration Unit Shut Down
Normal operations conditions
Main equipment operation ( TEG pump, H.Ex )
The main control loops
Day Four: TEG: Operation & Equipment Troubleshooting