2007-6031-2J-0007 Rev H Re-AFD Pipeline Hydraulic Analysis_Approved

8/11/2019 2007-6031-2J-0007 Rev H Re-AFD Pipeline Hydraulic Analysis_Approved

1/166


2/166

Cuu Long Join t Operating CompanySu Tu Trang LTPTP - Wellhead Platform and Pipeline

Engineering, Transportation and Installation

DOCUMENT TITLE: PIPELINE HYDRAULIC ANALYSISDOCUMENT NO.: 2007-6031-2J-0007

Rev. H

REVISION RECORD SHEET

No. Rev. No. Content of Revis ion D

1 A Issued for Comments

2 B Re-Issued for Comments

Previous document number was 2007-6031-2J-7107.Revised to incorporate CLJOC comments.

3 C Re-Issued for Comments

Revised to incorporate CLJOC comments.

4 D Issued for Approval


3/166




Rev. H

TABLE OF CONTENTS

1.

INTRODUCTION ...............................................................................................................

2. SUMMARY AND CONCLUSIONS ...................................................................................

2.1 Summary ..........................................................................................................................2.2 Conclusions ......................................................................................................................

3. PIPELINE SYSTEM DESCRIPTION .................................................................................

3.1 Platform Data ....................................................................................................................

3.2

Pipeline, Expansion Loops, Expansion Loop Tie-Ins and Riser Details ..........................3.2.1 Pipeline and External Coating Data .................................................................................


4/166




Rev. H

NOTATION

5LPP 5 Layer Polypropylene

BBL Barrel

BOPD Barrels of Oil Per Day

BWPD Barrels of Water Per Day

CA Corrosion Allowance

CD Chart Datum

COJ Centre of Jacket

CPP Central Production Platform


5/166




Rev. H

UG Gas Velocity

UL Liquid Velocity

WATC Total Water Content in Branch (m3)

WGS World Geodetic System

WHCP Well Head Control Panel


6/166




Rev. H

1. INTRODUCTION

This report has been prepared for Cuu Long Joint Operating Company (CLJ

Detailed Engineering design project for the development of the Su Tu Trang located offshore the Socialist Republic of Vietnam.

As part of the development of the Block 15-1, CLJOC intends to install a Long

Test Program (LTPTP) wellhead platform, pipeline and other associated facil

Trang field as well as send production from the Su Tu Trang LTPTP to the CP

The overall development concept consists of the following components:


7/166




Rev. H

Figure 1 Overall Field Layout of Block 15-1 Field Development


8/166




Rev. H

2. SUMMARY AND CONCLUSIONS

2.1 Summary

The hydraulic analysis simulation was performed for the following pipeline:

- 12 pipeline from LTPTP to CPP

The objectives of the steady state hydraulic analysis are as follows:

- Determine the boundary between non-insulated (FBE) and insulate


9/166




Rev. H

Based on the insulation boundary, the following 26 cases were calculated.

Case A1 - to generate the temperature and pressure profiles for mechan

Case A2 - to verify the pipeline flow capacity of 50 MMscfd.

- based on maximum flow rate, inlet temperature of 101C, m

temperature, half- buried.

Case A3 - to generate the temperature and pressure profiles considerin

pipeline (5LPP with concrete coating).


10/166

Cuu Long Join t Operating CSu Tu Trang LTPTP - Wellhead Plat

Engineering, Transportation an


Table 2.1-2 Summary of Analys is Cases

Units

Maximum Flow Cases Low Flow Cas

PrepCase

A1 A2 A3 B1 B

Inlet Temperature C 150 150 101 150 83.4 83

Inlet Temperature F 302 302 213.8 302 182.1 182

Outlet Temperature C 29.2 79.5 51.1 88.4 19.6 19

Inlet Pressurecalculated in analysis

BarG 33.1 37.5 33.6 38.7 11.3 11

Total Gas Flowrate MMscfd 50 10

Cases

InputParameters


11/166

Cuu Long Joint Operating CSu Tu Trang LTPTP - Wellhead Platf

Engineering, Transportation an


Table 2.1-2 Summary of Analys is Cases (Continued)

Units

Var

Flow from 1 Well

C9 C10 C11 C12 C13 C14

Inlet Temperature C 147.3 140.9 121.1 79.5 102.2 83.4

Inlet Temperature F 297.1 285.6 250 175.1 216 182.1

Outlet Temperature C 76.0 59.9 32.8 26.0 35.4 28.2

Inlet Pressurecalculated in analysis

BarG 37.4 22.5 13.1 11.5 29.4 18.6

Total Gas Flowrate MMscfd 50 30 15 5 50 30 C d t C t t bbl / MM f

Cases

InputParameters


12/166


13/166




Rev

3. PIPELINE SYSTEM DESCRIPTION

3.1 Platform Data

The coordinates of the platforms are given below.

Table 3.1-1 Platform Coordinates

S/No Location RemarksReference

Point

Coordinates

Easting (m) Northi

1 LTPTP Proposed COJ 867,000 1,130


14/166




Rev

3.2.1 Pipeline and External Coating Data

The external coating data are presented in Table 3.2-2.

Table 3.2-2 Pipeline and External Coating Data

External Coating Data

Su Tu Trang EPS to Su Tu Vang CPPPrepCase

Cases A1 to A2,B1,B2 andC1 to C21

Ri t LTPTPCorrosion Coating

M t i l FBE


15/166




Rev

The following figure presents a schematic of the 12 riser and pipeline system

and CPP.

Figure 3.1: General Riser and Pipeline Model Configuratio


16/166




Rev

The pipe wall and the external coating material thermal properties used are giv

Table 3.2-3 Material Thermal Propert ies

Material Density (kg/m3)

Thermal Conductivity(W/m-K)

Hea

Steel Pipe 7850 50

5LPP 760 0.185

FBE 1450 0.3

Concrete 3040 1.74

Riser Splash Zone Coating 1907 0.2


17/166

Cuu Long Join t Operating Su Tu Trang LTPTP - Wellhead Pla

Engineering, Transportation a


Table 3.3-1 Operating Condit ions (Pressure, Temperature) and Flow Rates

Units

Maximum Flow Cases Low Flow Cas

PrepCase

A1 A2 A3 B1 B

Inlet Temperature C 150 150 101 150 83.4 83

Inlet Temperature F 302 302 213.8 302 182.1 182

Outlet Temperature CTo

Inlet Pressure BarG

Total Gas Flowrate MMscfd 50 10

Cases

InputParameters


18/166

Cuu Long Join t Operating CSu Tu Trang LTPTP - Wellhead Platfo

Engineering, Transportation and


Table 3.3-1 Operating Condit ions (Pressure, Temperature) and Flow Rates

Units

Var

Flow from 1 Well

C9 C10 C11 C12 C13 C14

Inlet Temperature C 147.3 140.9 121.1 79.5 102.2 83.4

Inlet Temperature F 297.1 285.6 250 175.1 216 182.1

Outlet Temperature CTo be d

Inlet Pressure BarG

Total Gas Flowrate MMscfd 50 30 15 5 50 30

Condensate Content bbl / MMscf

Cases

InputParameters


19/166




Rev. H

3.4 Environmental Conditions

The following figure shows the application of the air and seawater velocities

considered in the hydraulic analysis.

Figure 3.4.1: Application of Velocit ies and Temperatures at L

AT

Air


20/166




Rev.

The environmental conditions were taken from the Structural Basis of Design a

of Design.

The ambient air temperature and seawater properties used in the analysis aTable 3.4-1.

Table 3.4-1 Surrounding Temperature

Ambient Air Temperature

Units Minimum Mean Ma

Temperature C 19 27


21/166




Rev.

Note:

1. The current and wind velocities are based on the Metocean Criteria

(2003-4000-6B-0002, Rev. A).

The following soil parameters were used with the FEMtherm module to mod

half-buried into the seabed soil for Preparatory Case Study, Cases A1 to A3, B

Case B2 has been modelled as non-buried.

Soil Type : Sand

Seabed Soil Density (sand) : 2500 kg/m3


22/166




Rev.

Component Mole % Molecular WeightIdeal Liq

G

Heptanes 0.93

Methycyclohexane 0.43

Toluene 0.31

Octanes 0.96

Ethylbenzene 0.04

M-, P-Xylene 0.25

O-Xylene 0.06

Nonanes 0 69


23/166




Rev.

The fluid composition was modified by adding condensate components and

condensate and water flow rates as in Table 3.2-1 at separator conditions (

MPa and temperature of 115.6 C). The modified compositions are presented

Table 3.5-2 presents the modified fluid compositions to be used in the differen

- Fluid 1 represents the fluid composition with condensate flow rate o

and water flow rate of 100 bbl / MMscf.

- Fluid 2 represents the fluid composition with condensate flow rate o

and water flow rate of 0 bbl / MMscf.


24/166




Rev.

ComponentFluid 1 Fluid 2

Mol % Mol %

o-Xylene 0.046 0.076

Ps-Cumene 0.047 0.079

C7 0.654 1.09

C8 0.696 1.159

C9 0.517 0.86

C10 0.462 0.767

C11 0.39 0.647


25/166




Rev.

3.6 Fluid Densi ties

The fluid densities for pressures 10 to 90 barg at temperatures 100 C

presented in the table below.

Table 3.6-1 Fluid Densi ties

Fluid Density (kg/m3)

Pressure(barg)

10 20 30 50

Temperature

(C)

100 16.9 34.5 52.7 89.8

150 9 3 23 4 38 3 68 8


26/166




Rev.

Table 3.6-2 Data Summary for Su Tu Trang Fluid Samples

Hydrocarbon Samples Well ST-1X ST-3X

DST 3 1

Field Sample No. 3-27 1-38

Sand F F

Fluid Type Condensate CondensateV

Da

PAT Sample No. 39250-91-1 39250-91-2

Fluid Property Method Results Results

Density (g/cc @ 20

o

C) DMA5000 0.783 0.7799


27/166




Rev.

4. BASIS OF STUDY

The study was carried out using OLGA software (OLGA v 5.3.2.2). Appendix

details about OLGA and the general level of accuracy that can be expectesimulations. In addition to the basic OLGA software, the following optional O

used.

FEMtherm module this enables the pipeline to be modelled and

buried into the seabed, taking into account the density, thermal con

capacity of the seabed soil.


28/166




Rev.

Seabed profile along the planned pipeline route from LTPTP to CPP is sh

below.

Figure 4-1: Seabed Prof ile of Pipeline Route from LTPTP to CPP


29/166




Rev.

5. ANALYSIS RESULTS

5.1 Boundary of Insulation

The maximum operating temperature in the segment without 5LPP coating w

Preparatory Case Study as shown by the graphical plots in Appendix A. Fro

profile for Preparatory Case Study, the point at which the fluid temperature is

determined. This occurs at the point 456m from the start of the pipeline mod

KP 0.247 along the actual pipeline route with reference to Pipeline Routing

2007-6031-2I-0002. Only FBE (corrosion coating) and concrete coating sha

KP 0 to KP 0 247 of the pipeline route 5LPP shall be applied to downstreamKP 0 247 It h ll b t d th t P t C St d h ff


30/166




Rev.

PipelineFlow rates(MMscfd)

CasePIN

(barg)Pressure Drop

(barg)

LTPTP to

15 C7 12.7 3.4

5 C8 11.5 2.2

50 C9 37.4 28.1

30 C10 22.5 13.2

15 C11 13.1 3.8

5 C12 11.5 2.2

50 C13 29.4 20.1

30 C14 18 6 9 3


31/166




Rev.

with FBE coating used in Preparatory Case Study. This temperature trend w

the pressure profile along the pipeline.

The flow in the pipeline is stratified along the seabed and semi-annular uPreparatory Case Study and Cases A1 to A3.

The Capacity Verification Case A2 has been performed to check the inlet pr

than 36.4 barg. The PINobtained for this case is 33.6 barg. Hence, the inlet p

case is adequate.

The inlet pressures for Cases A1 to A3 are acceptable as they are less


32/166




Rev.

For extremely low flow cases C4, C8 and C12, the simulation did not achieve

explains the fluctuating behaviour of the liquid content in the pipeline.

For these 5 MMscfd gas flow rate cases, the TOUT temperatures for the

bbl/MMscf and 100 bbl/MMscf water content in the fluid composition, are 26

26.0C respectively.

All the temperature profiles for the cases (Cases C1 to C21) follow the

described in Case A1.


33/166




Rev.

For cases with flow rates above 15 MMscfd, the flow in the pipeline is ma

annular at the risers.

Brief increases of gas and liquid velocities occur due to the removal of slugs in

do not cause any problems during low flow conditions.

A comparison between the water content in the fluid and its effect on the TO

flow rates was made to study the possibility of waxing due to low flow conditio

Cases C13 to C21 were considered as they are simulated as receiving flow

have lower inlet temperatures


34/166




Rev.

From Appendix B of "Process Basis of Design" (Ref. 4), the WAT (W

Temperature) is relatively high, ranging from 34 deg C to 50 deg C. On th

calculated arriving temperature at Su Tu Vang (STV) CPP is lower than 34

cases with low flow rates. It should be, therefore, noted that there would be a

low flow rate in order to avoid wax appearance during operation.


35/166

Cuu Long Joint Operating CoSu Tu Trang LTPTP - Wellhead Platfo



Table 5.2-2 Summary of Steady State Simulation Results

Pipeline CaseQGST

(MMscfd)

QOST(bopd)

QWST(bwpd)

PIN(barg)

POUT(barg)

TIN(C)

TOUT(C)

Prep. Case 50 7500 5000 33.1 9.31 150 29.2

A1 50 7500 5000 37.5 9.31 150 79.5

A2 50 7500 5000 33.6 9.31 101 51.1

A3 50 7500 5000 38.7 9.31 150 88.4

B1 10 1500 0 11.3 9.31 83.4 19.6

B2 10 1500 0 11.3 9.31 83.4 19.5

C1 50 7500 0 30.5 9.31 136 42.9

C2 30 4500 0 19 1 9 31 123 5 31 3


36/166

Cuu Long Joint Operating CoSu Tu Trang LTPTP - Wellhead Platfo



Pipeline CaseQGST

(MMscfd)QOST

(bopd)QWST

(bwpd)PIN

(barg)POUT

(barg)TIN(C)

TOUT(C)

LTPTP toCPP

C17 30 4500 1500 19.7 9.31 97.5 35.9

C18 15 2250 750 12.5 9.31 69.3 26.7

C19 50 7500 5000 35.3 9.31 123.9 61.0

C20 30 4500 3000 21.1 9.31 107.9 43.2

C21 15 2250 1500 12.9 9.31 79.5 28.1

Note:

1 Flow Regime: 1 Stratified 2 Annular 3 Slug 4 Bubble


37/166




Rev. H

6. REFERENCES

Ref. Doc. No. Title

1 2007-6031-2H-0001 Pipeline Basis of Design

2 STT-TQ-T-0002 Technical Query Hydraulic Analysis Proced

3 2007-6031-2K-0001 Proposed STT EPS to STV CPP PipelSurvey (TL Report), Rev. 1.

4 2007-4700-9H-0003 Process Basis of Design (Rev. M)


38/166




Rev. H


39/166

STEADY STATE SIMULATION PLOTS

Figure 1: Steady State Preparatory Case Study, TIN= 150oC, POUT= 9.31 barg, F

(Temperature Profile)


40/166


(Pressure Profile)


41/166


(Liquid Volume Fraction Profi le - HOL)


42/166


(Flow Regime Indicator Profile)


43/166


(Gas Velocity)


44/166

Figure 6: Steady State Preparatory Case Study TIN= 150oC, POUT= 9.31 barg, Fu

(Liquid Velocity)


45/166


(Total Liqu id Content in Branch - LIQC)


46/166


(Total Oil Content in Branch - OILC)


47/166


(Total Water Content in Branch - WATC)


48/166

Figure 10: Steady State Case A1, TIN= 150oC, POUT= 9.31 barg, FBE and 5LPP Co



49/166


(Pressure Profile)


50/166


(Liquid Volume Fraction Profile - HOL)


51/166




52/166


(Gas Velocity)


53/166


(Liquid Velocity)


54/166


(Total Liqu id Content in Branch LIQC)


55/166




56/166




57/166




58/166


(Pressure Profile)


59/166


(Liquid Volume Fraction Profile - HOL)


60/166




61/166


62/166


(Liquid Velocity)


63/166




64/166




65/166



28 S S C 3 1 0oC 9 31 C


66/166

Figure 28: Steady State Case A3, TIN= 150oC, POUT= 9.31 barg, Fully 5LPP Coate



67/166

Fi 30 St d St t C A3 T 150oC P 9 31 b F ll 5LPP C t


68/166


(Liquid Volume Fraction Profile HOL)

Figure 31: Steady State Case A3 T = 150oC P = 9 31 barg Fully 5LPP Coate


69/166





70/166

Figure 32: Steady State Case A3, TIN= 150 C, POUT= 9.31 barg, Fully 5LPP Coate

(Gas Velocity)



71/166


(Liquid Velocity)

Figure 34: Steady State Case A3 TIN = 150oC POUT = 9 31 barg Fully 5LPP Coate


72/166




73/166

Figure 36: Steady State Case A3 TIN = 150oC POUT = 9 31 barg Fully 5LPP Coate


74/166

Figure 36: Steady State Case A3, TIN 150 C, POUT 9.31 barg, Fully 5LPP Coate



75/166

Figure 38: Steady State Case B1, TIN= 83.4oC, POUT= 9.31 barg, FBE and 5LPP C


76/166

g y , IN , OUT g,

(Pressure Profile)



77/166

g y , IN , OUT g,




78/166

g y g




79/166

(Gas Velocity)



80/166

(Liquid Velocity)



81/166




82/166




83/166




84/166



(P P fil )


85/166

(Pressure Profile)


(Li id V l F ti P fi l HOL)


86/166



(Fl R i I di t P fil )


87/166



(Gas Velocity)


88/166

(Gas Velocity)


89/166


90/166


(Total Oil Content in Branch OILC)


91/166

(Total Oil Content in Branch OILC)




92/166

(Total Water Content in Branch WATC)

Figure 55: Steady State Case C1, TIN= 136oC, POUT= 9.31 barg, FBE and 5LPP C



93/166



(Pressure Profile)


94/166

(Pressure Profile)




95/166

( q )

Figure 58: Steady State Case C2, TIN= 123.5oC, POUT= 9.31 barg, FBE and 5LPP



96/166

( p )


(Pressure Profile)


97/166

( )




98/166

Figure 61: Steady State Case C3, TIN= 97.8oC, POUT= 9.31 barg, FBE and 5LPP C



99/166



100/166




101/166




102/166


(Pressure Profile)


103/166




104/166


105/166


(Pressure Profile)


106/166




107/166




108/166


109/166




110/166




111/166

Figure 74: Steady State Case C7, , TIN= 111.7oC, POUT= 9.31 barg, FBE and 5LPP

(Pressure Profile)


112/166




113/166




114/166


115/166




116/166




117/166


(Pressure Profile)


118/166




119/166




120/166


(Pressure Profile)


121/166




122/166




123/166


(Pressure Profile)


124/166




125/166




126/166


(Pressure Profile)


127/166




128/166




129/166


(Pressure Profile)


130/166


131/166




132/166


(Pressure Profile)


133/166




134/166


135/166


(Pressure Profile)


136/166


137/166

Figure 100: Steady State Case C16, TIN= 115.6oC, POUT= 9.31 barg, FBE and 5LP



138/166


(Pressure Profile)


139/166


140/166




141/166


(Pressure Profile)


142/166


(Total Liquid Content in Branch LIQC)


143/166




144/166


(Pressure Profile)


145/166




146/166




147/166


(Pressure Profile)


148/166




149/166


150/166


(Pressure Profile)


151/166




152/166




153/166

Figure 116: Steady State Case C21, TIN= 79.5

oC, POUT= 9.31 barg, FBE and 5LPP

(Pressure Profile)


154/166

Figure 117: Steady State Case C21, TIN= 79.5

oC, POUT= 9.31 barg, FBE and 5LPP



155/166



DOCUMENT TITLE: PIPELINE HYDRAULIC ANALYSISDOCUMENT NO : 2007 6031 2J 0007

Rev. H


156/166

DOCUMENT NO.: 2007-6031-2J-0007

Cuu Long Joint Operating CompanySu Tu Trang LTPTP - Wellhead Platform and Pipeline


DOCUMENT TITLE: PIPELINE HYDRAULIC ANALYSISDOCUMENT NO : 2007-6031-2J-0007

Rev. H


157/166

DOCUMENT NO.: 2007-6031-2J-0007

B.1 Geometrical System Definit ion

The OLGA model accepts a network of diverging and converging branch

consists of a sequence of pipes and each pipe is divided into sections

correspond to the spatial mesh discretisation in the numerical model.

Each branch starts and ends at a node. There are three different types of node

Terminal (free end) nodes, where boundary conditions must be specifie

Split nodes, where branches split

Merge nodes, where branches are coupled together



DOCUMENT TITLE: PIPELINE HYDRAULIC ANALYSISDOCUMENT NO : 2007-6031-2J-0007

Rev. H


158/166

DOCUMENT NO.: 2007 6031 2J 0007

This difference will not affect the steady state results provided that the inlet flo

same composition as in the PVT table. In transient simulations, as the fluids

different compositions, the changes of the physical properties and the chan

mass fractions with the changes of temperature and pressure will differ from t

PVT table. These differences are usually small.

As an alternative to PVT tables, it is possible to perform a simulation us

tracking, where the compositional data is provided in a feed file and the code c

properties internally. This means that the total composition may vary both i

and that no special consideration is needed for a pipeline network. This proce

accurate in simulations where the fluid compositional will change considerab




Rev. H


159/166

DOCUMENT NO.: 2007 6031 2J 0007

Temperature

OLGA performs only one energy balance for the fluid and only one flu

computed in the middle of each pipe section. This temperature is an average

oil and water phases. Therefore, for reliable temperature calculations in OL

for thermal computations must be as accurate as possible. Such data are the

the fluid, pipe wall modelling and soil modelling in case of a buried pipeline.

Pressure

The accuracy of the pressure drop calculations in OLGA depends on the acc

data and on the quality of the physical models implemented in the code. Im

are pipeline profile, inner wall surface roughness and fluid properties such as




Rev. H


160/166

DOCUMENT NO.: 2007 6031 2J 0007

Dynamic flow behaviour

The code has been tested against dynamic flow experiments, both typical sta

and terrain slugging experiments. The code has also been compared to variou

data from some field tests and the accuracy in predicted slugging frequenci

varies from very good predictions at typically terrain slugging conditions (

liquid slug volume predictions are within +/-10%), to inaccuracies of +/-100%

slugging conditions (slug volumes and frequencies are small for hydrodynam

the large spread). It should also be considered that the quality of the field

difficult to estimate. Data such as flow rates, pipeline profile and equilibrium

of the fluid can be crucial for the quality of the simulations in addition to the c

values for slug frequencies and slug sizes.




Rev. H


161/166




Rev. H


162/166

APPENDIX C - ANALYSIS RESULTS FOR 3LPP AND 5LPP COATING APPLIED C

C1 : SUMMARY

This section presents the results of the hydraulic analysis for Preparatory Case (3L

with 3LPP coating and 5LPP coating based on the following coating arrangement.

LTPTP Riser = 2.2 mm 3LPP

LTPTP Expansion Loop Tie-in = 2.2 mm 3LPP with 43 mm concrete coating

Pipeline (temperature greater than 140 C) = 2.2 mm 3LPP with 54 mm concre

insulated)




Rev. H


163/166

Table C-1 Summary of Analysis Cases

UnitsMaximum Flow Cases

Prep Case

Inlet Temperature C 150 1

Outlet Temperature F 302 3

Outlet Temperature C 31.2 8

Inlet Pressure calculated in analysis BarG 33.5 3

Total Gas Flowrate MMscfd 50

C d t C t t bbl / MM f 150

Cases

InputParameters




Rev. H


164/166

Table C-2 Pipeline and External Coating Data

External Coating Data

Su Tu Trang EPS to Su Tu Vang CPP Prep Case

Riser at LTPTP

Corrosion Coating

- Material 3LPP

- Thickness (mm) 2.2

Expansion Loop

Corrosion Coating

- Material 3LPP

- Thickness (mm) 2.2

Hot End


165/166


166/166

Documents

2007-6031-2J-0007 Rev H Re-AFD Pipeline Hydraulic Analysis_Approved