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8/4/13 Chemical & Process Technology: Problems Caused by Two Phase Gas-Liquid Flow
webwormcpt.blogspot.com/2010/02/problems-caused-by-two-phase-gas-liquid.html 1/4
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Problems Caused by Two Phase Gas-Liquid Flow
Saturday, February 27, 2010
Two phase gas liquid flow is commonly occur in any oil & gas production and processingsystem. Several flow patterns can occur in two phase gas liquid flow. There are Bubbleflow (with minimum vapor bubble), Plug flow, Stratified flow, Wavy flow, Slug flow, Annularflow and Mist/Dispersed flow (with minimum liquid droplet). See following images.
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8/4/13 Chemical & Process Technology: Problems Caused by Two Phase Gas-Liquid Flow
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Obvious Location Present of two phase gas liquid may be obvious and be easily identified duringdevelopment phase. Typical example are Full-Well-Stream (FWS) production whichpossibly producing hydrocarbon in gas and liquid form. Formation water, condensedwater, mercury, and injected chemical (e.g. corrosion inhibitor, hydrate inhibitor, etc) inliquid form, wax in slurry form and sand in solid form may also present in the FWS, whichtypically result complicated multiphase form. Partial stabilized condensate travel longdistance experience high pressure drop lead to vaporization. Vapor travel long distanceexperience ambient and J-T (isenthalpic process) cooling lead to condensation. Hotsaturated vapor is cooled by air cooler or heat exchanger results condensation, vapor orliquid passing through turbine experience isentropic process, etc. These streams areobvious and can be easily identified in process simulation. Generally example are :
Full Well Stream (FWS)Partial stabilized condensate with long pipelineSaturated vapor with long pipelineLiquid stream from separator passing a level control valveDownstream of Air cooler / Heat exchangerTurbine outletHot fluid mix with cool fluid continuously
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Non-obvious Location There are certain stream may be not so obvious and may not beeasily identified in process simulation. Hot saturated vapor flow inlong pipe experience heat loss to ambient and frictional loss,condensation begin and two phase flow (i.e. mist flow, annularflow). Cold saturated or partial subcooled liquid experiencefrictional loss due to fittings, piping, etc and ambient heatingresults vaporization and two phase flow (i.e. bubble flow, wavy flow,slugging flow). Hot stream mix with cold stream may resultsequilibrium change and lead to two phase. Typical area is flarecollection system. Hydrocarbon in process vessel at pressure once
it is drained to drain collection header may flash and lead to vaporization. Generallyexample are :
Saturated vapor within plant (condensation)Cooled or subcooled liquid within plant (vaporization)Flare collectionHydrocarbon drain collection
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8/4/13 Chemical & Process Technology: Problems Caused by Two Phase Gas-Liquid Flow
webwormcpt.blogspot.com/2010/02/problems-caused-by-two-phase-gas-liquid.html 3/4
Problems Two phase gas liquid flow can cause several destructive problems. There are :
Impingement erosionSplashing erosionCavitation erosionFlashing erosionFlow induced vibrationSurge / hammerNoiseDecrease process performancePhase separation
Impingement, Splashing, Cavitation & Flashing ErosionTwo phase gas liquid flow can lead to impingement, cavitation & flashing erosion. Twophase gas liquid flowing fluid where heavy phase is accelerated with light phase andinduced high momentum and shearing stress on surface. Slugging flow in vapor-liquidsystem with large slug hammering on surface induce high momentum with mediumvelocity and high mass flux. Mist flow with droplet accelerate at vapor velocity induce highmomentum with high velocity and low mass flux. Both induce high shear stress on thesurface and increase material removal rate.
Flow Induced VibrationHigh velocity compressible fluid in pipe is moving in turbulence pattern. Turbulence flowwill induced vibration on pipe. Once the flow induced vibration frequency meeting thenatural frequency of pipe support, resonance occur can lead to severe movement of pipesupport. Present of two phase gas liquid flow can generate different level of frequency andincrease possibility of resonances.
Surge & HammerTwo phase gas liquid slugging and high velocity gas moving liquid at similar speed,severe vibration can occur when liquid slug is knocking/splashing on the pipe wall,especially at bend and elbow. Hot steam mix with cold condensate at the collectionheader results sudden steam vapor collapse. The collapse vapor results sudden lowerpressure will lead sudden replacement of surrounding condensate. Sudden movement ofcondensate can results significant movement of condensate as well as piping and pipesupport. Under designed pipe support may fail due to severe vibration.
Quick opening of valve for incompressible, multiphase and gas/vapor will results suddenchange in momentum (0 to +mv) and subsequently instantaneous peak force acting onthe piping. This phenomena is commonly occurs in control valve (CV), Blowdown valve(BDV) and pressure relief device i.e. press ure relief valve (PRV) and rupture disc (RD).The instantaneous peak force acting on the piping may potentially lead to piping failure.
NoiseAbove phenomenon such as Impingement, Splashing, Cavitation & Flashing Erosion,Flow Induced Vibration and Surge & Hammer may also generate noise which potentiallyexceeded the allowable noise limit.
Affect process performanceIn oil and gas production, condensate-produced water bulk separation occur in slugcatcher / inlet receiver follow by a Condensate separator. Some process design mayinclude a filter coalescing separator to promote water droplet coalescing (usingcoalescing element) and separation before it is sent to Condensate stabilization.Condensate at saturation point from Condensate separator feeding to Filter Coalescingseparator will experience frictional drop and potential lead to vaporization. Vapor willaccumulate in the filter coalescing separator and seriously affect Coalescing activity inFilter Coalescing Separator.
Plate heat exchanger (PHE) is used in Solvent e.g. Amine, MEG, TEG, etc regeneration torecover heat from lean solvent stream and promote energy saving. Hydrocarbon and / orvapor bubble under carry from Solvent Absorber to PHE potentially accumulate in the PHEand seriously affect the heat transfer in PHE.
Phase Separation - Mal-DistributionAir cooler used for fluid cooling is widely used in Oil & Gas and Petrochemical plant. Hotfluid is fed to a Inlet header box, distribute fluid into tubes (normally finned) where coolingtake place and cooled fluid is collected in the Outlet header box. If hot two phase gasliquid fluid feeding to the inlet header box, liquid with higher momentum tends to flowpreferential path (straight) compare to vapor with lower momentum. The lead to seriousvapor-liquid mal-distribution. Fluid (vapor dominant) feed to tube closer to inlet possiblyover cooled whilst fluid (liquid dominant) feed to tube further from inlet possibly undercooled. For large duty air cooling system, fluid may further distribute into multiple headerboxes and multiple unit air cooler, this will further create mal-distribution of fluid.
Knowing the problems caused by two phase gas liquid flow, identification of potential twophase gas liquid becoming an important activity during design phase. Process engineershall take extra care during design phase and provide necessary prevention measures tominimize / avoid occurrence of two phase flow.
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8/4/13 Chemical & Process Technology: Problems Caused by Two Phase Gas-Liquid Flow
webwormcpt.blogspot.com/2010/02/problems-caused-by-two-phase-gas-liquid.html 4/4
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