Separation Processes in Gas Production
INTC 2323 - 11
Vern Wilson
Chapter 3
The full well stream has gas, oil, and stuff
The contaminants are water and solids
Velocity and gravity related
Separator
Why Separate?
Gas from the reservoir is composed hundreds of
different compounds of hydrogen and carbon all with
different densities, vapor pressures and other physical
characteristics.
Field processing requires separation of the various
compounds into salable compounds.
Separation Processes
Four basic processes to make pipeline gas:
Separation
– Separate free oil, gas and water
Conditioning
– Separate H2S or CO2 from
gas
Or from oil
Conditioning
– remove water vapor from the
gas - dehydration
Processing
– remove condensable liquid
hydrocarbons - stabilizing
Theory of Separation
Dissipate the well energy
Rapid decrease in velocity
Reduce turbulence
Control foaming
Provide outlets for gas and liquid
Provide level controls
Provide pressure relief
Provide gauges – T, P, Level
Two Types of Separators
Vertical
Horizontal
VERTICAL SEPARATOR
Used on low to intermediate gas-oil ratio wells
Also, when relatively large slugs anticipated
Takes up less space
Vertical Separator
Typical Barnett Shale Battery
HORIZONTAL SEPARATOR
Commonly less expensive than vertical
Greater gas-liquid interface area
Horizontal Separator
Double Barrel Separator
Separator Controls
Stage Separation
Oil is worth more than gas – therefore make more oil
Purpose is to reduce the pressure on the production a
little at a time to produce more oil
Multiple Sep
LOW TEMP SEPARATION
Intentional hydrate forming
Inlet gas cooled by expansion
This causes the water and liquid hydrocarbons to
condense
Produces:
Dry gas – the low temp provides condensation
Condensate -
Free water
Requires about 1,000 psi
Glycol Injection System
Inject about 6 to 10 gallons of Glycol per million cubic
feet of gas being produced
Glycol losses occur by:
Staying in solution with condensate
Carryover into the gas stream
Losses in the regenerator
Condensate Stabilization
Stabilizing means removing light hydrocarbons from
the liquid
If you dump high pressure liquid to a storage tank the
light ends will evaporate and carry some of the heavy
ends with them
You can assume that you will recover about ½ a barrel
per million scf of condensate for every 10°F drop in
separator temperature
The Stabilizer will allow another ¼ B/MM/10°F drop
Stabilizer
Equilibrium
Bubble Point
Dew Point
Single Phase
Two Phase
Equilibrium
Convergence
Turbo Expander Plant
This presentation delves into the importance of separating gases, oils, and solids in the well stream for effective field processing. It covers the theory of separation, different processes involved, types of separators, and their specific uses, such as vertical and horizontal separators. Images and descriptions enhance the understanding of why separation is crucial in gas production.
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Presentation Transcript
INTC 2323 - 11 Vern Wilson Chapter 3
The full well stream has gas, oil, and stuff The contaminants are water and solids Velocity and gravity related
Why Separate? Gas from the reservoir is composed hundreds of different compounds of hydrogen and carbon all with different densities, vapor pressures and other physical characteristics. Field processing requires separation of the various compounds into salable compounds.
Separation Processes Four basic processes to make pipeline gas: Separation Separate free oil, gas and water Conditioning Separate H2S or CO2 from gas Or from oil Conditioning remove water vapor from the gas - dehydration Processing remove condensable liquid hydrocarbons - stabilizing
Theory of Separation Dissipate the well energy Rapid decrease in velocity Reduce turbulence Control foaming Provide outlets for gas and liquid Provide level controls Provide pressure relief Provide gauges T, P, Level
Two Types of Separators Vertical Horizontal
VERTICAL SEPARATOR Used on low to intermediate gas-oil ratio wells Also, when relatively large slugs anticipated Takes up less space
HORIZONTAL SEPARATOR Commonly less expensive than vertical Greater gas-liquid interface area
Stage Separation Oil is worth more than gas therefore make more oil Purpose is to reduce the pressure on the production a little at a time to produce more oil
LOW TEMP SEPARATION Intentional hydrate forming Inlet gas cooled by expansion This causes the water and liquid hydrocarbons to condense Produces: Dry gas the low temp provides condensation Condensate - Free water Requires about 1,000 psi
Glycol Injection System Inject about 6 to 10 gallons of Glycol per million cubic feet of gas being produced Glycol losses occur by: Staying in solution with condensate Carryover into the gas stream Losses in the regenerator
Condensate Stabilization Stabilizing means removing light hydrocarbons from the liquid If you dump high pressure liquid to a storage tank the light ends will evaporate and carry some of the heavy ends with them You can assume that you will recover about a barrel per million scf of condensate for every 10 F drop in separator temperature The Stabilizer will allow another B/MM/10 F drop
Equilibrium Bubble Point Dew Point Single Phase Two Phase Equilibrium Convergence
