IPTC Presentación oral

8/2/2019 IPTC Presentacin oral

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Bangkok, February 2012

HYDRAULIC EVALUATIONHYDRAULIC EVALUATIONOF TRANSPORT GASOF TRANSPORT GAS

PIPELINE ON OFFSHOREPIPELINE ON OFFSHOREPRODUCTIONPRODUCTION


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22IPTCIPTC -- 15287. Hydraulic evaluation of offshore gas pipeline, Jorge Tru15287. Hydraulic evaluation of offshore gas pipeline, Jorge Trujillojillo

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

10 40455055620515202530354045

35

40

45

50

55

11

PARIA PENINSULA

SUCRE STATE

System

Gathering

Field B

Field ASystem export

pipeline

Onshore facilities

10 40455055620515202530354045

35

40

45

50

55

11

PARIA PENINSULA

SUCRE STATE

System

Gathering

Field B

Field ASystem export

pipeline

Onshore facilities

IntroductionIntroduction


4/1944IPTCIPTC -- 15287. Hydraulic evaluation of offshore gas pipeline, Jorge Tru15287. Hydraulic evaluation of offshore gas pipeline, Jorge Trujillojillo

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


5/1955IPTCIPTC -- 15287. Hydraulic evaluation of offshore gas pipeline, Jorge Tru15287. Hydraulic evaluation of offshore gas pipeline, Jorge Trujillojillo

0

100

200

300

400

500

600

700

800

900

1000

-300 -250 -200 -150 -100 -50 0

Temperature (F)

Pressure

(psia)

Critical point

0

500

1000

1500

2000

2500

3000

-300 -250 -200 -150 -100 -50 0 50 100 150 200 250 300

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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-140

-120

-100

-80

-60

-40

-20

0

20

40

60

80

0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000 100 000 110 000 120 000 130 000

Distance (m)

Elevation

(m

)

Bathymetry Sea level

Export pipeline route /Export pipeline route /

bathymetrybathymetry


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IPTCIPTC -- 15287. Hydraulic evaluation of15287. Hydraulic evaluation of

offshore gas pipeline, Jorge Trujillooffshore gas pipeline, Jorge Trujillo 77

Hydrate FormationHydrate FormationEvaluationEvaluation


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60

62

64

66

68

70

72

74

76

78

80

0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000 100 000 110 000 120 000 130 000

Distance (m)

Te

m

perature(F)

-140

-120

-100

-80

-60

-40

-20

0

20

40

60

Elevation

(m)

Temperature Bathymetry

Temperature profileTemperature profile


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0

500

1000

1500

2000

2500

3000

3500

4000

4500

-250 -200 -150 -100 -50 0 50 100 150 200

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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0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

5500

6000

-100 -90 -80 -70 -60 -50 -40 -30 -20 -10 0 10 20 30 40 50 60 70 80

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

0

20 000

40 000

60 000

80 000

100 000

120 000

140 000

160 000

0 100 200 300 400 500 600 700 800 900 1000

Gas flow rate (MMscfd)

To

talliquid

content(bbl)

26" 28" 30" 32" 34" Inside diameter Onshore slug catcher capacity

1000

1100

1200

1300

1400

1500

1600

1700

1800

1900

2000

0 100 200 300 400 500 600 700 800 900 1000

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

0

5

10

15

20

25

30

0 100 200 300 400 500 600 700 800 900 1000


Sup

erficialGasvelocity(ft/s)

26" 28" 30" 32" 34" Inside diameter

Erosion ratioErosion ratio

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1.0

0 100 200 300 400 500 600 700 800 900 1000


Erosion

ratio

(-)

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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0

10 000

20 000

30 000

40 000

50 000

0 20 000 40 000 60 000 80 000 100 000 120 000 140 000

Time (s)

Totalliquidc

o

ntentinb

ranch(

bbl)

50% 100% Field production

Liquid holdupLiquid holdup

P d filP d t t fil


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Temperature profileTemperature profile

1000

1100

1200

1300

1400

1500

1600

1700

1800

1900

0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000

Distance (m)

Pressure

(psig)

-140

-120

-100

-80

-60

-40

-20

0

20

40

60

80

Pipeline

elevation(

m

)

50 100 200 300 400 500 650 700 800 900 1000 Gas flowrate (MMscfd) Bathymetry

50

52

54

56

58

60

62

64

66

68

70

72

74

76

78

80

82

84

86

88

90

0 10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000

Distance (m)

Tem

perature

(F

)

-140

-120

-100

-80

-60

-40

-20

0

20

40

60

80

P

ipeline

elevation(

m

)

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

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