IPTC Presentación oral
Transcript of IPTC Presentación oral
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Bangkok, February 2012
HYDRAULIC EVALUATIONHYDRAULIC EVALUATIONOF TRANSPORT GASOF TRANSPORT GAS
PIPELINE ON OFFSHOREPIPELINE ON OFFSHOREPRODUCTIONPRODUCTION
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i.i. IntroductionIntroduction
ii.ii. Premises and criteriaPremises and criteria
iii.iii. Thermodynamic behavior of the streamsThermodynamic behavior of the streamsiv.iv. Export pipeline route / bathymetryExport pipeline route / bathymetry
v.v. ResultsResultsHydrate formation evaluationHydrate formation evaluation
Steady state modelingSteady state modeling
Transient state modelingTransient state modelingvi.vi. ConclusionsConclusions
ContentsContents
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Project Description:
Development of two fields located offshore
Location: Atlantic Coast of Venezuela Production: 650 MMscfd of natural gas
Purpose: to satisfy national and global demand
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PARIA PENINSULA
SUCRE STATE
System
Gathering
Field B
Field ASystem export
pipeline
Onshore facilities
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PARIA PENINSULA
SUCRE STATE
System
Gathering
Field B
Field ASystem export
pipeline
Onshore facilities
IntroductionIntroduction
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P in the export pipelineP in the export pipeline 400 psi400 psi
VVSGSG between 10 and 25 ft/sbetween 10 and 25 ft/s
Erosion ratio < 1Erosion ratio < 1
Onshore delivery Pressure: 1100 psigOnshore delivery Pressure: 1100 psig
Maximum operating pressure: 1500 psigMaximum operating pressure: 1500 psig
Onshore liquid slug catcher capacity: 4700 bblOnshore liquid slug catcher capacity: 4700 bbl
Analysis is focused on determining appropriateAnalysis is focused on determining appropriatepipeline sizespipeline sizes
Premises and criteriaPremises and criteria
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Temperature (F)
Pressure
(psia)
Critical point
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Temperature (F)
Pressure(psia)
Critical point
Phases envelopePhases envelope
Field AField APhases envelopePhases envelope
Field BField B
Thermodynamic behavior of theThermodynamic behavior of the
streamsstreams
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Distance (m)
Elevation
(m
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Bathymetry Sea level
Export pipeline route /Export pipeline route /
bathymetrybathymetry
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Hydrate FormationHydrate FormationEvaluationEvaluation
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Distance (m)
Te
m
perature(F)
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Elevation
(m)
Temperature Bathymetry
Temperature profileTemperature profile
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Temperature (F)
Pres
sure(psia)
Hydrate curve. Filed A
Hydrate curve. Fiedl B
Hydrate curve. Field (A+B)
Phase envelope. Field (A+B)
Hydrate formation curveHydrate formation curve
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Temperature (F)
Pressure(psia)
Unhibited
MEOH/water 1:20
MEG/water 1:20
TEG/water 1:20
MEOH/water 1:10
MEG/water 1:10TEG/water 1:10
MEOH/water 1:5
MEG/water 1:5
TEG/water 1:5
MEOH/water 1:4
MEG/water 1:4
TEG/water 1:4
MEOH/water 1:3
MEG/water 1:3
MEOH/water 1:2
MEG/water 1:2
Seabed temperature
Hydrate inhibitors effectHydrate inhibitors effect
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Steady State ModelingSteady State ModelingResultsResults
Xiao et al pressure dropXiao et al pressure drop
mechanistic modelmechanistic modelEaton hold up modelEaton hold up model
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Liquid inventoryLiquid inventory
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Gas flow rate (MMscfd)
To
talliquid
content(bbl)
26" 28" 30" 32" 34" Inside diameter Onshore slug catcher capacity
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Gas flowrate (MMscfd)
P
ressure
atinlet(psig)
26" 28" 30" 32" 34" Inside diameter Maximun operating pressure
Inlet pressureInlet pressure
Inlet pressure and liquidInlet pressure and liquid
inventoryinventory
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Superficial gas velocitySuperficial gas velocity
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Gas flowrate (MMscfd)
Sup
erficialGasvelocity(ft/s)
26" 28" 30" 32" 34" Inside diameter
Erosion ratioErosion ratio
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Gas flowrate (MMscfd)
Erosion
ratio
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26" 28" 30" 32" 34" Inside diameter
Superficial gas velocity andSuperficial gas velocity and
erosion ratioerosion ratio
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Transient StateTransient StateModeling ResultsModeling Results
OLGA modelOLGA model
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Time (s)
Totalliquidc
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ntentinb
ranch(
bbl)
50% 100% Field production
Liquid holdupLiquid holdup
P d filP d t t fil
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Temperature profileTemperature profile
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Distance (m)
Pressure
(psig)
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Pipeline
elevation(
m
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50 100 200 300 400 500 650 700 800 900 1000 Gas flowrate (MMscfd) Bathymetry
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Distance (m)
Tem
perature
(F
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P
ipeline
elevation(
m
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50 100 200 300 400 500 650 700 800 900 1000 Gas flowrate (MMscfd) Bathymetry
Pressure profilePressure profile
Pressure and temperature profilePressure and temperature profile
for an export pipeline of ID28for an export pipeline of ID28
C i f t d dC i f t d d
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Comparison of steady andComparison of steady and
transient models resultstransient models results
59208592085755557555Liquid rate (bbl/d)Liquid rate (bbl/d)
79798080Inlet temperature (Inlet temperature (F)F)
0.200.20 -- 0.380.380.280.28 -- 0.410.41Erosion ratioErosion ratio2626
3434
Maximum liquid holdup (%)Maximum liquid holdup (%)
5522Minimum liquid holdup (%)Minimum liquid holdup (%)
40800408002040520405Total liquid holdup (bbl)Total liquid holdup (bbl)1212 -- 16161212 -- 1919Ranges of VRanges of VSGSG (ft/s)(ft/s)
400400403403Pressure drop (psi)Pressure drop (psi)
1500150015021502Inlet pressure (psig)Inlet pressure (psig)
28282828Internal diameter (in)Internal diameter (in)
Transient StateSteady StateVariables
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Thermal evaluation shows risk of hydrate formationThermal evaluation shows risk of hydrate formation
TEG at 1:10 injection ratio has been selected on aTEG at 1:10 injection ratio has been selected on apreliminary basis as hydrate inhibitorpreliminary basis as hydrate inhibitor
2828 IDID pipeline showed a hydraulic acceptablepipeline showed a hydraulic acceptable
behaviorbehavior It is not expected erosion to be an issue as erosionIt is not expected erosion to be an issue as erosion
ratio < 1ratio < 1
Flow assurance studies should be considered sinceFlow assurance studies should be considered sincethe beginning of a project and analysis must bethe beginning of a project and analysis must be
carried out during entire life of the fieldscarried out during entire life of the fields
CONCLUSIONSCONCLUSIONS
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Thank youThank you
Any questions?Any questions?