Process and Utility Design Basis (Offshore Platform)

FRONT-END ENGINEERING DESIGN (FEED) SERVICE FOR BK-TNG WELLHEAD PLATFORM

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PROCESS AND UTILITY DESIGN BASIS Page 2 of 50

TABLE OF CONTENTS

1.0

GENERAL

4

1.1 1.2 1.3

BACKGROUND PURPOSE OF DOCUMENT DEFINITIONS AND ABBREVIATIONS

4 4 4

2.0

OVERVIEW OF THIEN UNG WELLHEAD WELL HEAD PLATFORM PLA TFORM DEVELOPMENT

6

3.0

OVERVIEW OF PLA TFORM FACIL ITIES

7

3.1 3.2

PRODUCTION FACILITY UTILITY FACILITY

7 7

4.0

BRIEF PROCESS DESCRIPTION

9

5.0

DESIGN CODES

11

6.0

GENERAL DESIGN CONSIDERATIONS

13

6.1 6.2 6.3 6.4 6.5 6.6 6.7

PRODUCT AND EFFLUENT DISCHARGE SPECIFICATIONS DESIGN LIFE PLATFORM ORIENTATION ORIENTATI ON DESIGN MARGINS TURNDOWN STANDARD CONDITIONS UNITS OF MEASUREMENT

13 13 13 13 13 14 14

7.0

PRODUCTION AND WELL DATA

15

7.1 7.2 7.3 7.4 7.5

WELLHEAD CONFIGURATION CONFIGURATI ON SHUT-IN TUBING HEAD PRESSURE AND TEMPERATURE FLOWING WELLHEAD PRESSURE AND TEMPERATURE FULL WELL STREAM COMPOSITIONS AND CHARACTERISTIC PRODUCTION AND DESIGN FLOWRATE

15 15 15 16 20

8.0

PROCESS SIMULATIONS SIMULA TIONS

21

9.0

ENVIRONMENTAL DATA

22

9.1 9.2 9.3 9.4 9.5 9.6

AIR TEMPERATURE SEAWATER TEMPERATURE SOLAR RADIATION RELATIVE HUMIDITY WIND DATA RAINFALL DATA

22 22 23 23 23 23

10.0

PROCESS FACIL ITIES DESIGN BA SIS

25

10.1 10.2 10.3 10.4 10.5 10.6 10.7 10.8 10.9

WELL FLOWLINES AND HEADERS WELL TESTING PRODUCTION SEPARATION DH GAS COMPRESSION SYSTEM GAS DEHYDRATION SYSTEM GAS METERING LAUNCHER CONDENSATE TREATMENT AND EXPORT PRODUCED WATER TREATMENT SYSTEM

25 25 25 27 28 29 29 30 31


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11.0

UTILITIES DESIGN BA SIS

33

11.1 11.2 11.3 11.4 11.5 11.6 11.7 11.8 11.9 11.10 11.11 11.12 11.13 11.14

CLOSED DRAIN AND OPEN DRAIN SYSTEMS FUEL GAS SYSTEM INSTRUMENT/UTILITY INSTRUMENT/UTILITY AIR SYSTEM NITROGEN SYSTEM HP & LP FLARE SYSTEM POTABLE WATER & WASH WATER SYSTEM SEAWATER SYSTEM DIESEL FUEL SYSTEM CHEMICAL INJECTION SYSTEM POWER GENERATION AVIATION FUEL SYSTEM SEWAGE SYSTEM FUTURE DESIGN PROVISIONS FIRE FIGHTING SYSTEM

33 34 35 36 37 39 40 41 42 44 45 45 46 46

12.0

REFERENCES

47

Ap pendi pen dix xA

Uni ts of Measur ement

FRONT-END EN INEERING ESIGN (FEE ) SERVICE FOR BK-TNG WELLH AD PLATFORM P OCESS AN

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UTILITY DESIGN BASIS Page 4 of 50

1.0

GENERAL

1.1

Backgroun Thien Ung ield is located in the middle part of Block 04- in the Na Con Son Basin, offshore the Socialist Republic of ietnam, ap roximately 15 km of D i Hung fiel , and approximate ly 270 km southeast of Vung T u. The Bl ck 04-3 c vers an a ea of approximate ly 2600 km . The Thien Ung field i including it 2 structural parts. Thien Ung structure discovery was made in 20 4 with the 04-3-TU-1X ell. Two su sequent ap raisal wells (04.3- U-2X and 04.3-TU-3X), drilled and tested respe tively, delineated the field. Location of hien Ung fi ld is shown in Figure 1. 1 below.

Figure 1.1: Thien Ung Reservoir Location

1.2

Purpose of document This docum nt provides the design asis for the process and utility facilitiies to be ins alled on Thien Un g Platform opside.

1.3

Definitions and Abbre iations

1.3.1

Definitions PROJECT

FEED service for BK-TNG Wellhead P latform

COMPANY

The party whi ch initiates the project nd ultimatelly pays for i s design a d construction and o ns the fa ilities. Her the COM ANY is Vietsovpetro ( Referred to as VSP)

CONTRAC OR

The party w ich carries out all or art of the design, engineering, p ocurement, construction and commi sioning of t e project


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VENDOR 1.3.2

The party on which the order or contract for supply of the equipment equipment / package or services is placed

Abbreviations AGRU

Acid Gas Removal Removal Unit

BDV

Blowdown Valve

BPD

Barrel per Day

BK-TNG

Thien Ung Wellhead Platform

COG

Center of Gravity

CGR

Condensate-to-Gas Condensate-to-Gas Ratio

ESD

Emergency Shutdown

FEED

Front End Engineering Engineering Design

FWS

Full Well Stream

F&G

Fire and Gas

GTG

Gas Turbine Generator

HMB

Heat and Mass Balance

MMSCMD

Millions Standard Cubic Meter Per Day

MMSCFD

Millions Standard Cubic Feet Per Day

MPFM

Multiphase Flow Meter

MSF

Module Support Frame

MSL

Mean Sea Level

NPSH

Net Positive Suction Head

PCS

Process Control System

PCV

Pressure Control Valve

PFD

Process Flow Diagram

POB

Person On Board

PPD

Pour Point Depressant

ppm

Parts Per Million

PSD

Process Shutdown

PSV

Pressure Safety Valve

PVE

Petrovietnam Engineering Consultancy Joint Stock Corporation

SCSSV

Surface Controlled Sub-Surface Safety Valve

SITHP

Shut-In Tubing Head Pressure

SITHT

Shut-In Tubing Head Temperature

SDV

Shutdown Valve

SSV

Surface Safety Valve

SURF

Subsea Umbilical Risers and Flowlines

TEG

Triethylene Glycol

TPGM

Technip Geoproduction (M) Sdn Bhd

USD

Unit Shutdown

VSP

VIETSOVPETRO

WHCP

Wellhead Control Panel

WV

Wing Valve


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2.0

OVERVIEW OF THIEN UNG WELLHEA D PLATFORM PLA TFORM DEVELOPMENT Thien Ung Wellhead Platform (BK-TNG) is designed to handle total gas production from Thien Ung field and associated gas from Dai Hung-02 platform transported via subsea pipeline. Phase 1 development involves installation of process and utility facilities sufficient for total gas production from Thien Thien Ung wells and and associated gas from Dai Dai Hung-02. During this phase of production, Thien Ung high pressure full well stream from each production well has enough flowing pressure to meet the required pressure at the export gas pipeline without compression. Phase 1 production continues for approximately eleven years [ref. 4] before the well pressure depletes further and the well production is unable to flow into the export pipeline under its own flowing pressure. The production facilities are designed to handle 2.048 MMSCMD with 10% margin of gas production from Thien Ung filed and 1.0 MMSCMD of associated gas from Dai Hung-02. Utility facilities installed on BK-TNG are designed to support the current production facilities th only. Phase 2 is considered from year 12 to end of production life and is not included in FEED. During phase 2, production gas of BK-TNG will be compressed prior to flow into the export gas pipeline.


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3.0

OVERVIEW OF PLATFORM PLA TFORM FACILITIES FACIL ITIES The facilities to be installed on BK-TNG during phase 1 are given in the following sections.

3.1 3.1

Production facility The BK-TNG production facility includes:

3.2 3.2

•

12 well slots with 12 single-completion single-completion wells

•

Flow-lines and Production Producti on Header

•

Test Header and Well Testing Facility

•

Production Separator

•

Gas Dehydration System (using TEG system)

•

Gas Custody Metering System

•

Slug Catcher and gas compression system for associated associated gas from Dai Hung-02 Hung-02

•

Custody Metering System for DH-02 gas

•

Wet Gas Heater

•

Condensate-Water Condensate-Water Heater

•

Condensate Condensate Dewatering Separator

•

Condensate Treatment System

•

Condensate Custody Metering System

•

Produced Water Treatment System

•

Production launcher for 26-inch two-phase export pipeline connected to Nam Con Son 2 pipeline designed for intelligent pig and pigging spheres

Utility Facilit Facilit y The BK-TNG utility facility includes: •

Fuel Gas System

•

HP/LP Flare System

•

Open/Closed Open/Closed Drain System

•

Chemical Injection System (corrosion inhibitor, reverse demulsifier, Methanol Wax Inhibitor and provision for scale inhibitor, demulsifier, and pour point depressant injections)

•

Diesel Fuel System

•

Power Generation System

•

Seawater System

•

Firewater System

•

Potable Water and Wash Water System

•

Electro Chlorination System

•

Instrument and Utility Air System

•

Nitrogen System


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•

Aviation Fuel System

•

Sewage System

•

Distribution headers for instrument instrument air, utility air, nitrogen, potable water, wash wash water water and firewater.

•

Accommodation: Accommodation: Living quarter for 29 persons at peak time


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4.0

BRIEF PROCESS DESCRIPTION The Thien Ung full well stream (FWS) from each production well starting from day one of production life is letdown through choke valve and flows to Production Header via production flowline. During well test, FWS from the test well is sent to the Test Header and to the Test Separator where the stream is measured and checked for well performance. The tested well fluid leaving the Test Separator is then combined and flows back to the Production Header. From Production Header, the well fluid is fed to a two phase Production Separator where vapor is separated from liquid. liquid. Saturated vapor vapor leaving the Production Production Separator is then heated and combined with associated gas from Dai Hung-02 prior to be dehydrated in a TEG based Gas Gas Dehydration Dehydration system. Liquid from the Production Separator Separator is fed to Condensate Dewatering Dewatering Separator after necessary heating. For initial few years of operation (when wellhead pressures are high), the achieved temperature of the gas from the Production Separator after being reduced to Gas Dehydration operating operating pressure pressure is low enough enough to be in in hydrate region. region. Therefore, an an electric Wet Gas Heater Heater is provided to heat heat up the gas to avoid avoid hydrate formation. formation. Inlet temperature to Gas Dehydration Unit after combining with Dai Hung gas is maintained at least 5°C above hydrate temperature or minimum 15°C, whichever is higher. The Wet Gas Heater also maintains the Thein Ung gas temperature atleast 5°C above hydrate temperature after PCV downstream of the heater before it mixes with DH gas. Associated gas from Dai Dai Hung-02 pipeline pipeline arrives at a range of 15-28°C 15-28°C and 6.5 – 9.0 barg barg [ref.7] and is fed to a two-phase Slug Catcher. Separated gas gas from the Slug Catcher Catcher is metered and compressed to 30 barg, cooled to 50°C and then combined with the heated gas from the Production Separator prior to be dehydrated in the TEG system, which operates at near near 28 bar g. Separated liquid liquid from the Slug Slug Catcher is flown to the the LP Condensate Header Header to Closed Drain Vessel. The Production Separator is operating approximately at slightly lower than well head pressures from the seventh year to the eleventh production year [according to Thien Ung production profile, profile, ref. 4]. While during the first six production production years, when the well fluids have high flowing pressure [according to Thien Ung production profile, ref. 4], the Production Separator is operating at approximately 65 bar g to optimize equipment and line sizing throughout throughout eleven eleven production years for constrained constrained platform layout/space. The Condensate Dewatering Separator is maintained at a pressure of about 28 barg to enable routing of generated flash gas to dehydration & export without the need for compressing.The TEG based Gas dehydration system is operated at around 28 bar g to ensure adequate pressure is available to export gas into the pipeline. Required export pressure at BK-TNG platform is 25 bar g The combined saturated gas from Production Separator, DH gas compressor and Condensate Dewatering Separator is routed to TEG Contactor Inlet Scrubber to remove entrained liquid prior to be fed to the TEG Contactor where the saturated gas is dried by contacting with lean triethylene triethylene glycol (TEG). Dry gas from the TEG Contactor exchanges exchanges heat with the hot lean TEG in Lean TEG/Dehydrated Gas Heat Exchanger to cool the lean TEG that feeds to TEG Contactor. The dehydrated gas passes through a Gas Custody Metering System prior to export. Rich TEG leaving at bottom of TEG Contactor is regenerated in Glycol Regeneration System where water in rich TEG is stripped in TEG reboiler and Stripping Column. The lean TEG is recycled back to TEG Contactor. The separated condensate from Production Separator is heated by a Condensate/Water Heater to ensure that temperature of the condensate at outlet of LCV downstream of the Production Separator Separator is 30°C i.e. i.e. 6°C above WAT to avoid wax formation. formation. Separated


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Condensate is filtered to remove solids and then fed to Coalescer where fine separation of condensate and water takes place. Dewatered condensate is routed to a Condensate Custody Metering System System then spiked with the dehydrated dehydrated gas gas to export. Exported gas is transported via the 26-inch two-phase Nam Con Son 2 Pipeline to White Tiger field facilities. Produced water separated from the three-phase Condensate Dewatering Separator is routed to the Produced Water Treatment System for removal of oil and grease in water to less than 30 ppm to meet local environmental regulation prior to be discharged to sea. Liberated gas from the three-phase separator is combined with the saturated gas from Production Separator and DH gas compressor for dehydration. Besides the process systems, appropriate utility systems such as Fuel Gas system, Flare System, Drain System, Instrument/Utility Air System, Seawater System, Power Generation System, Diesel System, Potable Water/Wash Water System, etc. are provided to support the platform operation. operation.


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5.0

DESIGN CODES The process design of the platform and facilities are to comply with the following international codes and standards:1.

API RP 14C

Recommended Recommended Practice for Analysis, Design, Installation, and Testing of Basic Surface Safety Systems for Offshore Production Platforms Seventh Edition, 01 March 2001

2.

API RP 14E

Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems – Fifth Edition, 1991

3.

API Std. 520 Part I

Sizing, Selection, and Installation of Pressurerelieving Devices in Refineries Part I - Sizing and Selection – Eight Edition, 01 December 2008

4.

API RP 520 Part II

Sizing, Selection, and Installation of PressureRelieving Devices in Refineries Part II – Installation - Fifth Edition, 01 August 2003

5.

API Std. 521

Pressure-relieving and Depressuring Systems Fifth Edition; with Errata: 6/2007 and Addendum: Addendum: 5/2008

6.

API Std. 526

Flanged Steel Pressure Relief Valves - Sixth Edition, 01 April 2009

7.

API Std. 2000

Specification for Venting Atmospheric and LowPressure Storage Tanks – Non-refrigerated and Refrigerated - Sixth Edition, 01 November 2009

8.

API Spec 12J

Specification for Oil and Gas Separators – 8th Edition, April 2009

9.

TEMA

Standards of The Tubular Exchanger manufactures Association, Ninth Edition, 2007

10.

NACE MR0175 / ISO 15156

Petroleum and Natural Gas Industries — Materials for Use in H2S-containing Environments in Oil and Gas Production: Part 1: General Principles Principles for Selection Selection of Cracking-resistant Material – First Edition, 2001, with Technical Corrigendum Corrigendum 1: 2005 (E) & Technical Circular 1: 2007 (E) Part 2: Cracking-resistant Carbon Carbon and Low Low Alloy Steels, and the Use of Cast Irons Irons – First Edition, 2003, 2003, with Technical Corrigendum Corrigendum 1: 2005 (E) & Technical Circular 1: 2007 (E) Part 3: Cracking-resistant CRAs (CorrosionResistant Alloys) Alloys) and Other Other Alloys – First Edition, 2003, with Technical Corrigendum Corrigendum 1: 2005 (E) &


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Technical Corrigendum Corrigendum 2: 2005 (E) & Technical Circular 1: 2007 (E) & Technical Circular 2: 2008 (E) 11

TCVN 6171:2005

Fixed Platforms Regulation – The Technical Supervision and Classification

12

TCVN 6767-3: 2000

Fixed Offshore Platforms – Part 3: Machinery and Process Systems


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6.0

GENERAL DESIGN CONSIDERATIONS

6.1 6.1

Product and Effluent Discharge Specific Specific ations Table 6.1: Design Specifications Summary Parameter

Unit

Value

Ref.

lb H2O/MMSCF

7

Ref.2

barg

25 minimum

Ref.2

Water Content of Dehydrated Gas

lb H2O/MMSCF

5 [HOLD]

Note 1

Free Water content in Condensate

ppmv

60 [HOLD]

Note 2

ppmv

30

Ref.1

Gas and Condensate Product Water content spec. for Gas Export Pipeline Export gas line pressure

Produced Water Oil content in Produced Water effluent

Notes: 1. Spec at the outlet of Gas Dehydration to achieve an export gas water spec of 7lbs/MMSCF after mixing with the condensate 2. Spec at the outlet of coalescer filter to achieve an export gas water spec of 7lbs/MMSCF. Connecting pipeline to hanger flange located on the riser is designed to transfer product gas to the two-phase 26-inch Nam Con Son 2 export pipeline. The expected pipeline departure pressure for BK-TNG is required at 25 bar g. 6.2

Design Lif e The facilities are designed for a service life of 25 years. [Ref. 1]

6.3

Platfor m Orientation The orientation of the platform is as below. [Ref. 1] True North

45°

6.4

Platform North

Design Margi Margi ns 10% margin is considered for Production from Thien Ung. No design margin is considered for Production from Dai Hung. No additional additional design margin is considered for equipment design

6.5

Turndown


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No specific turndown turndown requirement requirement for the platform is envisaged. envisaged. All equipment equipment and systems shall be designed to handle the varying throughputs as per production profile.

6.6

Standard Condit ions The standard conditions used:

6.7

Pressure Pressur e :

1.01325 (1 atm)

Temperature:

15 °C

bara

Units of Measur Measur ement The SI unit of measurement is used. The units and their abbreviations are listed in Appendix A.


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7.0

PRODUCTION PRODUCTION AND WELL DATA

7.1

Wellhead Config uratio n The Thien Ung field contains 12 slots with 12 single completion wells [Ref.1]. Each well is equipped with remote actuated SCSSV, SSV and WV. No back-up SCSSV pressure equalization equalization facilities is required to be installed on BK-TNG topsides. The well flowlines, production/test headers are rated to API 10000 psi. Production flowlines up to the last block valve to production and test header are rated to withstand the SITHP; whereas the production header, test header and are associated piping are de-rated to ANSI 600 psi rating. Equipment downstream downstream of Production Production Separator Separator are de-rated to ANSI 300 psi rating. Appropriate overpressure protection shall be designed for headers to avoid overpressure by flowing wells.

7.2

Shut-in Tubing Head Head Pressur e and Temperatur Temperatur e Shut-In Tubing Head Pressure (SITHP) is 406 bar absolute Shut-In Tubing Head Temperature (SITHT) is 100°C

7.3

Flowi ng Wellhead Pressure and Temperatur Temperatur e The Thien Ung flowing production profile, wellhead pressure and temperature are as follows: [Ref.4]. Table 7.1: 7.1: Thien Ung Ung Field Flow ing Wellhead Condit ions Year

2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Number of Wells

Daily Gas Production

3 8 12 12 12 12 12 12 12 11 11 11 9 9 9 6 3 2 2 2

MSCMD 393.6 747 1871 2048 2048 2048 2002 1829 1452 1018 860 685 498 440 368 307 119 67 60 54

Daily Condensate Production SCMD 108.0 124.0 185.8 149.0 104.8 75.0 55.9 45.9 40.1 32.7 28.5 23.9 20.3 18.3 16.1 14.3 7.4 1.4 1.2 1.1

Daily Water Production

Wellhead Pressure

Wellhead Temperature

SCMD 0.0 1.9 0.8 4.8 15.2 36.7 73.9 124.7 162.7 160.8 189.0 193.7 181.7 202.9 210.5 214.1 88.2 38.4 40.3 41.8

atm 254 228 204 167 130 97 63 47 45 41 35 29 24 18 15 12 10 14 12 11

°C 60 64 63 63 63 63 63 59 54 50 48 47 46 47 47 48 48 37 38 38


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Thien Ung production rates shown in table above are considered at well head conditions, i.e. upstream of chokes, for simulation modeling The Dai Hung-02 gas production rates are as follows [ref.4]. Table 7.2: 7.2: Dai Hung-02 Gas Gas Produc tio n Rate Daily Daily Gas Gas Produc tion Year MMSCMD 2015 1 1.0 2016 2 0.96 2017 3 0.89 2018 4 0.90 2019 5 0.80 2020 6 0.56 2021 7 0.29 2022 8 0.27 2023 9 0.26 2024 10 0.0

7.4

Full Well Well Stream Composi tio ns and Characterist ic The full well stream compositions represent Thien Ung well fluids through field life [ref.1]

Table 7.3: Thien Ung full Well Stream Composition (Dry Basis) Low er Case

Higher Case

Av erag e (BA SE CASE)

Mole %

Mole %

Mole %

H2S

0.000

0.000

0.000

CO2 (Note 1)

5.297

9.000

5.671

N2

0.379

0.365

0.378

CH4

74.805

71.879

74.511

C2H6

7.734

7.432

7.704

C3H8

4.526

4.349

4.508

iC4H10

1.117

1.074

1.113

nC4H10

1.322

1.270

1.317

iC5H12

0.515

0.495

0.513

nC5H12

0.364

0.350

0.363

Pseudo C6

0.794

0.763

0.791

Pseudo C7

0.850

0.817

0.847

Pseudo C8

0.610

0.587

0.608

Pseudo C9

0.316

0.304

0.315

Pseudo C10

0.242

0.232

0.241

Pseudo C11

0.138

0.132

0.137

Composition


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Pseudo C12

0.120

0.116

0.12

Pseudo C13

0.098

0.095

0.098

Pseudo C14

0.081

0.078

0.081

Pseudo C15

0.066

0.064

0.066

Pseudo C16

0.042

0.041

0.042

Pseudo C17

0.021

0.020

0.021

Pseudo C18

0.018

0.017

0.018

Pseudo C19

0.018

0.017

0.018

Pseudo C20+

0.523

0.503

0.521

H2O

0.000

0.000

0.000

Total

100.00

100.00

100.00

25.687

28.9

26.5

320

330

328.3

Average molar mass (g/mole) Average molar mass C20+ (g/mole)

Note 1: For the platform design, design, compositions compositions from Average BASE CASE are are used. For lower and higher cases, the compositions of other components are normalized equally to achieve 100% total. For material selection and corrosion rate calculations, average BASE CASE compositions are used to achieve realistic corrosion rates and reasonable material selection. However, Higher Case composition is also to be used as sensitive case to check corrosion rate and material selection. A check case of material selection assuming that ten years of production life correspond to Higher case composition and balance 15 years of production life with Base Case composition shall be carried out as a sensitivity check The properties of pseudo components for Thien Ung wells are shown in the following table: Table 7.4: 7.4: Pseudo Pseudo Comp onent Prop erties fo r Thien Ung FWS Component

NBP (°C) (°C)

Molecular Weight

Density @ 60 ºF (kg/m3)

Pseudo C6

66.93

84

685.0

Pseudo C7

94.83

96

722.2

Pseudo C8

118

107

745.0

Pseudo C9

144.93

121

764.0

Pseudo C10

168.32

134

778.0

Pseudo C11

190.27

147

789.0

Pseudo C12

212.76

161

800.0

Pseudo C13

234.31

175

811.0

Pseudo C14

256.26

190

822.0


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Pseudo C15

278.18

206

832.0

Pseudo C16

298.25

222

839.0

Pseudo C17

316.42

237

847.0

Pseudo C18

331.89

251

852.0

Pseudo C19

344.69

263

857.0

Pseudo C20+

406.69

335.1

872.6

Compositions Compositions of Dai Hung-02 associated gas arriving at DH-TU pipeline are shown in table below [ref.8]: Table 7.5: Gas compositions from DH-02 Composition

Year 1 (2015)

Year 3, 4 (2017, 2018)

Year 8, 11 (2022, 2025)

Mole % H2S

0.0004

0.0004

0.0004

CO2

3.0854

3.0828

3.0765

N2

0.4103

0.4099

0.4091

CH4

77.4616

77.3974

77.2375

C2H6

8.4475

8.4405

8.4231

C3H8

5.4073

5.4029

5.3918

iC4H10

1.2612

1.2602

1.2576

nC4H10

1.4138

1.4128

1.4098

Neo-C5

0.0000

0.0000

0.0000

iC5H12

0.5097

0.5094

0.5083

nC5H12

0.3270

0.3268

0.3262

n-C6H12

0.2928

0.2927

0.2921

n-C7H14

0.3827

0.3830

0.3822

n-C8H16

0.2055

0.2061

0.2056

n-C9H20

0.0277

0.0280

0.0279

n-C10H22

0.0050

0.0052

0.0051

n-C11H24

0.0005

0.0005

0.0005

Pseudo C12+

0.0001

0.0001

0.0001

H2O

0.7613

0.8413

1.0461

Total

100.00

100.00

100.00

The properties of Thien Ung reservoir fluids are given in the following table: Table Table 7.6: 7.6: Analys is Resul ts of Degassed Degassed Oil Samples of Thien Ung Oil Field in Standard Conditions [Ref.1]


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Well

04-3-TU-1X

04-3-TU-3X

DST (Drill (Drill Stem Test)

DST#3

DST#5

DST#3

DST#4

DST#5

Density (g/m3)

0.8065

0.7755

0.8172

0.8035

0.7961

Viscosity @ 50 °C (cP)

1.85

1.32

1.55

1.0576

1.0650

Viscosity @ 70 °C (cP)

NA

NA

1.2334

NA

NA

Pour Point (°C)

<-20

<-20

18.00

2.00

-8.00

Ash (%mass)

0.003

0.014

NA

NA

NA

Sulphur (%mass)

0.022

0.012

NA

NA

NA

Wax content (%mass)

2.60

4.50

12.97

4.20

1.63

Wax Disappearance Disappearance Temperature Temperature (°C)

NA

NA

57

55

55

trace

0.15

0.38

0

0

Asphalt (%mass)

Pour point for Thien Ung wells is ranging from <-20 °C to 18 °C Wax appearance temperature is assumed 24°C Other impurities in the well fluid are as follow: i) Sulphur Compounds [Ref.1] There is no significant H2S detected in any of the well tests. However, for design purpose of material selection, maximum H 2S content assumes to be 20 ppmv. ii ) Wax Content [Ref.1 ] Thien Ung condensate has a high wax content of 1.6 - 13% mass. Refer also to Table 2.5 above. iii) Mercury [Ref.1] No significant mercury content was detected in any of the well test to date. iv) Emulsion [Ref.1] The Thien Ung fluid evaluations have been indicating low emulsion formation risk in separation or in combination with other condensate. Provision to inject de-emulsifier should be made as a precaution but usage is expected to be minimal or nil. v) Scaling [Ref.1] Water analysis and scale predictions have been showing the brine to be under-saturated in calcium carbonate at higher pressure, becoming oversaturated at near atmospheric pressure. Scale formation is believed unlikely to occur, with the lower pressure systems at greatest risk.


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No scale is, therefore, expected at downhole and no interventions are to be expected to be required for scale. Provision should be made for scale inhibitor injection points upstream of the separator to protect the downstream LP process equipment, equipment, if required. r equired. vi ) Foaming [Ref.1] Foaming [Ref.1] Thien Ung condensate has been evaluated as having low foam forming tendency, and it is expected that antifoam injection is not required. vii) Sand Sand Product ion [Ref.1] ion [Ref.1] Studies have indicated a risk for low levels of solids production from wells during later years of field life. The sand control philosophy is to manage sand down-hole through the use of gravel packs or screens. There is a small risk that sand may accumulate in the production separators during later years of field life. These vessels should therefore be equipped with appropriate internal sand flushing and nozzles to enable sand handling and flushing from the vessels during later years of field life. Peak predicted sand loading is less than 130 litres/MMscm (16 - 17 lb/MMscf) which is normally sand free. Acoustic non-intrusive solid detectors are required near the wellheads.

7.5

Produc tio n and Design Flowrate The production flowrate for Thien Ung wells and Dai Hung associated gas rate are shown in the following table. Table 7.7: Production and Design Flowrate Summary Produc tio n Cases

Produc tion /Desig /Desig n Flowrate

Reference Reference

Max Thien Ung total wells Gas production rate

2.048 MMSCMD + 10% margin

Ref.4

Max Thien Ung individual well Gas production rate

382.7 MSCMD + 10% margin (for 10 wells)

Ref.5

Max Dai Hung total Gas rate

1.0 MMSCMD

Ref.4

185.8 SCMD + 10% margin

Ref.4

44 SCMD +10% margin (for 10 wells)

Ref.5

Maximum Condensate rate Max Thien Ung individual well Condensate rate Maximum total Produced Water rate Max Thien Ung individual well Produced Water rate

481 MSCMD + 10% margin (for 2 wells

58 SCMD + 10% margin (for 2 wells) 189.0 SCMD + 10% margin

Ref.4

39 SCMD + 10% margin (for 10 wells)

Ref.5

85 SCMD + 10% margin (for 2 wells)


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8.0

PROCESS SIMULA TIONS Simulation model is done using Aspen HYSYS Version 7.3. The HYSYS Peng Robinson (PR) equation of state (EOS) with Lee Kesler enthalpy method is used as the property package for the simulation model. Heat and Material Balance is then generated from the model. The process simulations are to cover the following cases in order to represent the Thien Ung Field and Dai Hung Field development. development. The following process simulation simulation cases are performed for the preparation of heat and material balance. Table Table 8.1: 8.1: Proc ess Simul ation Cases Case

Description

1

Case 1: Year 1 – 1 – Maximum Dai Hung Gas Rate. Rate. Thien Ung Production Rate of o 0.3936 MMSCMD Gas and 108 SCMD Condensate, FTHP/T =253barg/60 C. Dai Hung Gas of 1.0 MMSCMD

2

Case 2: Year 3 – 3 – Maximum Thien Ung Condensate Rate , Thien Ung Production Rate of 1.871 MMSCMD Gas and 185.78 SCMD Condensate, FTHP/T = o 203barg/63 C. Dai Hung Gas of 0.89 MMSCMD

3

Case 3: Year 4 – 4 – Maximum Gas Volumetric Rate to TEG system, system, Thien Ung Production Rate of 2.048 MMSCMD Gas and 149.0 SCMD Condensate, o FTHP/T = 166barg/63 C. Dai Hung Gas of 0.9 MMSCMD

4

Case 4: Year 8 – 8 – Maximum Gas Volumetric Rate to Inlet System, System, Thien Ung Production Rate of 1.829 MMSCMD Gas and 45.9 SCMD Condensate, FTHP/T o = 46barg/59 C. Dai Hung Gas of 0.27 MMSCMD

5

Case 5: Year 11 – 11 – Maximum Thien Ung Water Rate, Rate , Thien Ung Production Rate of 0.860 MMSCMD Gas and 28.5 SCMD Condensate, Condensate, 189.0 SCMD Water, o FTHP/T = 34barg/48 C


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9.0

ENVIRONME ENVIRONMENTAL NTAL DATA The Thien Ung Development Complex is located some 270 km SE of Vung Tau. This area is considered to be harsh environment with strong tides and is exposed to summer monsoon storms and winter depressions. depressions.

9.1

Air Temperatur Temperatur e Table Table 9.1: Air Temperatur Temperatur e Parameter

Month

Year

1

2

3

4

5

6

7

8

9

10

11

12

Mean (°C)

24.8

25 25.1

26 26.4

28 28.1

28.8

28.2

27.8

27.8

27.7

27.6

26 26.7

25 25.6

27.1

Max (°C)

33.6

33.7

39.0

37.0

37.5

38.0

34.0

33.6

37.0

36.2

36.0

35.0

37.0

Min (°C)

22.0

22.0

22.0

23.0

22.0

21.4

22.0

21.0

22.0

21.8

21.1

21.7

21.0

For Air Cooler design: Design air temperature (min) Design air temperature (max)

= =

21.0 °C 39.0 °C

= =

21.0 °C 35.0 °C

For Generator rating: Design air temperature (min) Design air temperature (max)

9.2

Seawater Seawater Temperatu re

The maximum seawater temperature is the maximum monthly average water temperature during warmest month at the depth of abstraction, which may be extrapolated from surface temperature measurement Table 9.2: Seawater Temperature Parameter

Month 1

2

3

4

5

6

7

Year 8

9

10

11

12

Surface Mean Mean (°C) (°C)

24.6 24.6

24.5

26.1 26.1

28.5

28.3 28.3

29.5

28.7

28.5

28.7

28.4

27.5

26.1

27 27.5

Max (°C)

25.3

26 26.5

28.2

29 29.8

30 30.6

31.9

31.1

30.9

30.5

29.8

29 29.2

27 27.8

3 1. 1.9

Min (°C)

23.9

23.2

23.1

25.3

25.1

27.2

25.7

24.5

25.9

25.8

23.9

24.9

23 23.5

Mid Layer Mean Mean (°C) (°C)

24.7 24.7

24.5 24.5

25.8 25.8

27.3

25.9

24.9

24.8

25.2

24.9

27.3

27.3

26.0

25 25.7

Max (°C)

25.6

26 26.1

27.8

29 29.2

29 29.8

30.9

29.7

29.9

30.1

30.1

28 28.4

29 29.1

3 0. 0.1

Min (°C)

23.9

23.3

23.2

22.7

21.8

21.1

21.4

18.4

20.2

21.1

20.7

24.6

18 18.4


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9.3

Solar Radiation Table 9.3: 9.3: Solar Radiation [ HOLD] HOLD] Parameter Parameter

9.4

Basis

Solar Radiation (kW/m2)

Maximum

6.85 kW.hr/m2/day based on 8 hr per day of radiation

0.86

Minimum

3.2 kW.hr/m2/day based on 8 hr per day of radiation

0.4

Average

4.42 kW.hr/m2/day kW.hr/m2/day based on 8 hr per day of radiation

0.55

Relativ Relativ e Humidi ty

Table 9.4: Con Son, All-year and Calendar Month Relative Humidity Distribution Statistics Ann.

Jan

Feb

Mar

Apr

May

Jun

July

Augt

Sep

Oct

Nov

Dec

99 Percent (%)

96.0

95.2

96.0

96.0 96. 0

96.0

96.0

98.0 98. 0

96.0

96.0

98.0

98.0

96.0

95.0

75 Percent (%)

85.0

84.0

84.0

86.0 86. 0

85.0

85.0

87.0 87. 0

85.0

84.0

87.0

91.0

85.0

84.0

Mean (%)

80.0

78.8

78.5

79.8

78.7

79.3

80.9

80.3

80.2

81.4

83.6

80.4

78.6

25 Percent (%)

74.0

74.0 74. 0

73.0

74.0

73.0 73. 0

73.0

75.0

75.0 75. 0

76.0

76.0

77.0 77. 0

75.0

74.0 74. 0

1 Percent (%)

64.0

62.8

62.0

64.8

63.0

62.0 62. 0

65.0

65.0

66.0 6 6.0

65.4

67.0

64. 0

62.0

Std. Dev. (%)

7.7

7.2

7.2

7.6

8.0

8.0

8.0

7.3

6.7

7.8

8.4

7.5

7.1

No. years data

8.7

8.8

8.7

8.9

8.6

8.9

8.8

8.9

9.6

9.8

8.0

7.9

7.8

For flare radiation calculation, the following relative humidity to be used. Design relative humidity (min) = Design relative humidity (max) =

9.5

62.0% 98.0%

Wind Data The following wind data is at the reference level of 10.0 m above MSL designated EL 0.00. The prevailing wind direction: - From Northeast : October to April - From Southwest : May to September The design wind speed for flare radiation is 18.8 m/s based on the prevailing wind direction. The wind speed is used without considering wind chilling effect.

9.6

Rainfal l Data The instantaneous instantaneous intensity of r ainfall is 50 mm/hr.


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Table Table 9.5: 9.5: Rainfall Parameter

Quantity of days with rainfall

Month

Year

1

2

3

4

5

6

7

8

9

10

11

12 12

2.5

2.0

2.0

6.5

16

19

18.5

20

22.5 22 .5

21

14.5 14 .5

6.5

15.1


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10.0

PROCESS FACIL ITIES DESIGN BA SIS The key basis for the Process Systems design is listed below.

10.1 10.1

Well Flowl ines and Headers Headers The well flowlines, production/test headers are subjected to SITHP of 406 bar absolute. With this SITHP, the system is rated to API 10000 psi. The production flowlines up to the last block valve to production and test header are rated to API 10000 psi to withstand the SITHP; whereas the production header, test header and associated piping piping are de-rated to ANSI 600 psi rating. rating. Down-stream equipments equipments are derated to ANSI 300 psi rating. Appropriate overpressure protection shall be designed for headers to avoid overpressure by flowing wells. All wells are designed to t o be equipped equipped with self-equalized self-equalized surface controlled sub-surface safety valve (SCSSV). No SCSSV pressure equalized equalized facility is required to be installed installed on the topside of BK-TNG.

10.2 10.2

Well Testing Well testing at BK-TNG platform platform shall shall be carried out by Test Test Separator. Separator. The Test Separator for Thien Ung field is sized to handle the max individual well gas rate with associated condensate and water. Test Separator Separator

-

Configuration Configurat ion : 1 x 100%

-

Type : 2 phase horizontal separator

-

Operating pressure : ⇒ 65 barg during first 6 years th

th

⇒ 30 barg minimum from year 7 to year 11 th

⇒ Operating pressure during year 12 to end of production life shall be determined in

phase 2

-

The Test Separator is designed to test only one well at a time

-

Capacity : Flow Flow rate is based based on on the two largest largest wells: Gas: 0.53 MMSCMD Condensate: 63.8 SCMD Water: 93.5 SCMD

10.3 10.3

Produc tion Separation Separation Production Separa Separator tor Production Separator is designed to perform separation of 12 production wells FWS into vapor and liquid streams.

-


-

Type : 2-phase Vertical Separator


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-

Operating pressure : ⇒ 65 barg during first 6 years th

⇒ 2 – 3 bar less than wellhead pressures from year 7 to year 11

th

th

⇒ Operating pressure during year 12 to end of production life shall be determined in

phase 2

-

Capacity: As per simulation simulation case 4 for vapor vapor section section and case 2 for liquid section Max vapor flow: 2.01 MMSCMD 3

Max liquid flow: 27.35 m /h Note: Separator shall be provided with internals for removal of sand and other solids by washing with wash water. water. Provision of additional additional space for washing and and sand separation separation and sand handling equipment is to be considered.

-

Separator shall be designed with a maximum vapor k factor of 0.15 m/sec considering vane pack A minimum 3 minutes residence time on liquid shall be provided from normal liquid level Maximum liquid carry-over in the gas gas stream not exceed exceed 0.1 0.1 USgal/MMSCF USgal/MMSCF

Wet Gas Heater Gas separated separated from Production Separator Separator is heated heated in Wet Gas Heater. Heater. The heater is envisaged to heat the Thien Ung gas adequately to ensure a) Operating temperature temperature remains remains above hydrate hydrate temperature temperature in the complete complete system b) Inlet temperature temperature to Gas Dehydration Dehydration unit unit after combining combining with Dai Hung Hung gas is maintained at least 5°C above hydrate temperature or minimum 15°C, whichever is higher

-


-

Type : Electric

-

Process fluid temperature at outlet of heater : adequate adequate to keep operating temperature 5°C above hydrate temperature throughout the system and to maintain Gas Dehydration Unit inlet temperature of combined gas at least 5°C above hydrate temperature or minimum 15 °C, whichever is higher

-

Capacity : 350 kW

-

Heater pressure drop : approximate 0.5 bar

Note: Heating requirement is only expected during the first three years of operation when the wellhead pressures upstream choke are high resulting in low gas temperature downstream of choke. Condensate-Water Heater Separated liquid from Production Separator is heated in Condensate-Water Condensate-W ater Heater. The heater is required to ensure a) b)

Condensate temperature is maintained above WAT Effective separation of oil & water in the vessel

-


-

Type : electric


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-

Process fluid temperature at outlet of heater : adequate to ensure temperature of combined condensate of Thien Ung and Dai Hung-02 is above 30°C

-

Capacity : 65 kW

-

Heater pressure drop : approximate 0.5 bar

Slug Catcher Slug Catcher is provided for condensate knock-out and to handle slug from Dai Hung-02 associated gas pipeline. The separator, shall be designed to knock out associated condensate from gas, and is designed handle a larger slug volume from the subsea pipeline during pigging or startup/shutdown startup/shutdown scenarios.

-

Configuration: Configurati on: 1 x 100%

-

Type: 2-phase Separator

-

Operating pressure : 6.5 to 9 bar g [ref.7]

-

Gas capacity: capacity: equivalent equivalent to maximum Dai Hung-02 Hung-02 gas rate of 1.0 1.0 MMSCMD MMSCMD @ 15°C and 9 barg with associated condensate flowrate due to condensation in transport pipeline.

-

Capacity: The Slug Catcher is designed for 3

Slug volume: 10.6 m [ref.7] Vapor flow rate: 1 MMSCMD 3

Liquid flow rate: 5 m /h (maximum drain rate. Normal incoming flowrate is 3 ~1.5 m /hr)

-

Maximum liquid carry-over in the gas gas stream not exceed exceed 0.1 USgal/MMSCF

-

The vessel shall be designed designed with a maximum vapor k factor of 0.15 m/sec considering vane pack A minimum 3 minutes residence time on liquid shall be provided from normal liquid level

-

10.4 10.4

DH Gas Gas Compress ion System Associated from DH-2 arrives arrives at 6.5 to 9 bar g; therefore, therefore, it is required to be compressed compressed to meet operating pressure on BK-TNG platform for export via NCS2 pipeline. Vapor leaving the Slug Catcher is metered and compressed in a Compression System which includes a DH Gas Compressor Suction Scrubber, a DH Gas Turbine Driver [hold], [hold], a DH Gas Compressor [hold] and associated equipment and a DH Gas Compressor After Cooler. Vapor leaving the DH Gas Compressor After Cooler is combined with the heated gas leaving the Wet Gas Heater and then dehydrated in the TEG system.

-

Gas capacity: 1.0 MMSCMD

-

Arrival pressure: from 5.5 barg to 8 barg

-

Arrival temperature: 15°C to 28°C

DH Gas Gas Compressor Suction Scrubber A gas compressor suction scrubber is provided to knock-out entrained liquid in the vapor before it is compressed in the compressor.

-


-

Type : vertical vertical two-phase two-phase knock-out knock-out drum with vane vane type type mist mist eliminator eliminator

-

Maximum liquid carry-over in the gas gas stream not exceed exceed 0.1 USgal/MMSCF


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. DH Gas Gas Compr essor Package The DH Gas Compressor Package consists of gas turbine driven centrifugal compressor [hold] and associated equipment. Compressor is on suction pressure speed control with discharge pressure over-ride.

-


-

Type : centrifugal

-

Compression specification: gas is to be compressed from 5.5 5.5 barg to 31 barg

DH Gas Compressor After Cooler DH compressed gas leaving the compressor at about 170°C is cooled by air cooler before combining with heated gas from Wet Gas Heater for dehydration in the TEG system.

10.5 10.5

-

Configuration Configuration : 1 x 100% 100% with minimum two fans fans

-

Type : forced drafted air cooler

-

Temperature Temperature specification: specification: gas gas is to cooled cooled from about 170°C to 50°C 50°C (max)

Gas Dehydration System Wet gas from Production Separator and DH gas compressor is sent to the Gas Dehydration System to dehydrate the gas to meet the export gas quality in term of water content.

-

Capacity : per simulation simulation case 3 for vapor vapor section and case case 1 for liquid section Vapor flow rate: 3.08 MMSCMD 3

Liquid flow rate: 1.1 m /h (to Inlet Scrubber)

-

Operating pressure : approximately approximately 28 barg

−

Operating temperature : as per simulation, operating temperature is kept kept at least 5°C 5°C above hydrate temperature or minimum 15°C, whichever is higher

TEG Contactor Inlet Scrubber TEG Contactor Inlet Scrubber is provided to remove any dropped out condensate in the gas before it contacts with TEG in the Contactor to avoid foaming in the Contactor.

-


-

Type : 2-phase 2-phase vertical separator with vane vane pack/ coalesce internals

-

Specification: Inlet Scrubber Scrubber shall be designed designed for for removal of liquid liquid particles of 5 microns and above The vessel shall be designed designed with a maximum vapor k factor of 0.15 m/sec considering vane pack

-

A minimum 3 minutes residence time on liquid shall be provided from normal liquid level

TEG Contacto r

-


-

Type of dehydration : absorption with TEG


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-

Specification : The wet wet gas is dehydrated such that the water content content for the gas after being spiked with condensate in the export pipeline is 7lb/MMSCF

-

Type of packing packing : vertical vertical column with structured packing

Operating temperature temperature : 28°C .( year 4 with capacity of 3.07 MMscmd) MMscmd) 50°C ( year * with capacity of 2.3 MMscmd) Lean TEG/Dehydrated Gas Heat Exchanger

-


-

Type : shell and tube heat exchanger

-

Lean glycol is cooled to 5°C above the gas temperature temperature entering entering the TEG Contactor Contactor

-

Exchanger shell side and tube side pressure drop : 0.5 bar

TEG Regeneration Package Specification: The TEG Regeneration Package shall be designed suitable to achieve a lean TEG concentration of 99.7% wt and to generate lean TEG to meet the export dry gas quality, capacity and operating conditions conditions as stated in the Gas Dehydration System.

10.6

Gas Meterin g DH Gas Gas Custod y Metering

-

A gas custody Metering is provided to measure measure Dai Hung-02 associated gas received received on BK-TNG platform

-

Configuration : N+1 metering runs

-

Type : Ultrasonic flowmeter

-

Gas metering accuracy : fiscal standard ≤ 1%

-

Capacity : 1.0 1.0 MMSCMD MMSCMD @ 15°- 28 C and and 6.5 – 9 barg

Export Gas Gas Custody Metering Metering The combined dry gas is metered prior to export

10.7

-


-

Type : Ultrasonic flowmeter

-

Gas metering accuracy : fiscal standard ≤ 1%

-

Capacity : design gas gas export requirement requirement of 3.0 MMSCMD 10 to 1 turndown turndown for each each meter run

Launcher Production Launcher

-

Production launcher for the 26-inch two-phase export pipeline

-

Designed to accommodate accommodate one one intelligent intelligent pig or five (5) (5) spheres, whichever is longer longer

Note: The launcher launcher is is designed to facilitate future future high pressure operation. operation. operation does not foresee any high pressure over 300 psi rating.

Current


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10.8 10.8

Condensate Treatment Treatment and Expor t Separated liquid from Production Separator is heated by a Condensate-Water Heater to avoid wax formation. Heated Condensate-Water stream is combined with pumped condensate from Closed Drain Vessel and then fed to the Condensate Treatment System. The system is designed to recover flash gas and reduce water content in the separated condensate. Condensate-Dewatering Condensate-Dewatering Separator Separator The Condensate Dewatering Separator is designed to perform a three phase separation to separate water, condensate and flash gas from liquids of Thien Ung and Dai Hung-02. The gas is combined with the wet gas from the Production Separator to be treated in the Gas Dehydration System; Water is sent to Produced Water Treatment System; Condensate is further dehydrated prior to commingle with the dry gas for export.

-


-

Type : 3-phase horizontal vessel

-

Operating pressure : 28-30 bar g

-

Capacity: The Condensate Condensate Dewatering Separator is designed for Vapor flow rate: 1 MMSCFD 3

Condensate flow rate: 30 30 m m /h 3

Water flow rate: 8.7 m /h

- Specification -

Maximum water content of the separated liquid hydrocarbon not to exceed 2000 ppmv

-

Maximum hydrocarbon hydrocarb on content of the separated water not to exceed 2000 ppmv

-

Target micro size separation for heavy heavy and light phases phases is < 100 μm

Note: Separator shall be provided with internals for removal of sand and other solids by washing with wash water. water. Provision of additional additional space for sand separation separation and sand sand handling equipment has been considered.

-

The vessel shall be designed designed with a maximum vapor k factor of 0.15 m/sec considering vane pack A minimum 5 minutes residence time on liquid shall be provided from normal liquid levels Vessel shall be be provided with suitable internals internals to achieve low low water in oil specifications specifications at outlet

Condensate Condensate Booster Pumps

-


-

Type : vertical inline centrifugal pumps

-

Capacity : 30 m /h

-

Pump is used to boost the condensate pressure to supplement pressure drop in condensate treatment system to prevent flashing in the Condensate Custody Metering System

3

Condensate Filters The filters are to protect the downstream Condensate Coalescer Coalescer

-



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-

Type : cartridge filters

-

Filtration specification: 99% removal of solid particles 2 microns and above.

-

Filter capacity : 30 30 m m /h

3

Condensate Coalescer

-


-

Type : liquid/liquid coalescer

-

Coalescer specification : removal of free water water in condensate condensate from 2000 2000 ppmv down to 60 ppmv

-

Coalescer capacity : 30 30 m m /h

3

Note: a set of coalescer element shall be provided as non-installed spare element Condensate Custody Metering Skid Condensate after being dehydrated is passing through a Condensate Custody Metering Skid to measure export condensate

-

Only one Condensate Condensate Custody Custody Metering Skid is required to cater cater for for total condensate flow from BK-TNG

-


-

Metering type : coriolis type / turbine type

-

Condensate Condensate metering accuracy : fiscal standard ≤ 0.5%

-

Metering capacity : 30 30 m m /h

3

Note: the system is designed so that no flashing and vaporizing phenomenon occurs in the metering system 10.9 10.9

Produc ed Water Treatment Treatment System Produced Water Treatment System is designed to reduce hydrocarbon content in the produced water from the three-phase Separator Separator to meet local environmental regulation. Hydrocyclones function as the primary facility to separate hydrocarbon in the produced water. From the Hydrocyclones, produced water is routed to the IGF Package for final skimming of hydrocarbon and degassing of dissolved gases present in the produced water. The rejected oil stream from Hydrocyclones is routed to the LP Flare Drum for oil recovery. The treated produced water is discharged to sea via the hazardous open drain caisson. Hydrocyclones

-


-

Specification : Removal of majority majority of dispersed dispersed oil prior to be further further treated in IGF unit

-

Produced water capacity : 8.7 m /h

3

Induced Gas Gas Floatation (IGF) (IGF) Package Package

-


-

Specification : Removal Removal of dispersed dispersed oil down to 30 30 ppmv ppmv

-

Produced water capacity : 8.7 m /h

-

Flotation achieved with mixing/sparging mixing/sparging with fuel gas

3


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Hydrocyclones and IGF are to be combined into one package. Produced Water Treatment combination of Hydrocyclone + IGF is suggested. However, vendor is at liberty to suggest alternate system such as CFU as long as meeting performance specs and space/weight limitation.


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11.0

UTILITIES DESIGN BA SIS The key design basis for the Utilities Systems is listed below.

11.1 11.1

Closed Drain and Open Drain Systems Two Drain Systems include: Closed Drain System and Open Drain System. Closed and Open Drain Systems are segregated so that no possibility exists for system pressure to cause backflow into the Open Drain System. Continuous low pressure process drains are routed directly to the Closed Drain System in order to contain any gas that might be blown through when draining of these facilities. Maintenance drains from the pressurized process systems are also collected in the drain header and routed to the Closed Drain System. The Closed Drain System consists of f ollowing items: • • • •

Closed Drain Vessel Closed Drain Vessel Pumps Closed Drain Heater Closed Drain headers

The separated gas from the Closed Drain Vessel is routed to the LP flare header. Liquid collected from the Closed Drain System is pumped back to the 3-phase CondensateDewatering Separator. Separator. The closed drain drain header is segregated into different pressure pressure rating closed drain header depending on the pressure rating of upstream facilities. An electrical heater is provided in the Closed Drain Vessel to heat up the sub-zero fluid/wax formed in the drum due to low temperature from Joule-Thompson effect after letting down through the pressure reducing devices (pressure relief valves, blowdown valves, etc.).

The Open Drain System consists of t he following items: • • •

Open Drain Caisson Open Drain Pump Hazardous and non-hazardous open drain headers

Open Drain System is designed to collect hazardous and non-hazardous open drain sources on BK-TNG. Hydrocarbon collected collected in the Open Drain System is pumped back to the 3-phase Condensate Condensate Dewatering Separator. Separator. In case the collected hydrocarbon hydrocarbon in the caisson is relatively dirty or being contaminated, the hydrocarbon liquid is evacuated to drain pots and is sent to onshore for safe disposal. Liberated gas from the Open Drain Caisson is vented to atmosphere at safe location. Open drain system is designed in such a way that hazardous and non-hazardous systems are always segregated. Closed Drain Vessel

-


-

Type : horizontal two-phase knock-out drum

-

Liquid capacity: to provide adequate residence time to continuous hydrocarbon sources and to accommodate BK-TNG single largest liquid inventory from maintenance drains ( of HP Flare KOD from LALL) between NLL to LAH of the vessel,.


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Closed Drain Vessel Pumps

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-

Type : progressive cavity/screw pump

-

Capacity : minimum minimum pump out rate of 10.7 10.7 m /hr and provide a reasonable pumping time to evacuate the closed drain vessel from LAHH to LAL within 2 hours

3

Closed Drain Vessel Vessel Heater Heater

-


-

Type : Electric heater

-

The heater duty is designed to heat the liquid in the vessel from minimum ambient o o o temperature of 21 C to 30 C (wax appearance temperature is about 24 C) within 5 hours, assuming the initial liquid level is at high level alarm (LAH) and the liquid is condensate.

Open Drain Caisson

-


-

Liquid capacity capacity : Maximum Maximum liquid flow from open open drain, drain, which may contributed contributed by rainwater or firewater collected on BK-TNG and allow self-venting for vapor trapped in the drained liquid

-

Specification: Caisson is designed to a) Separate all oil droplets of 500 micron and above present due to deck washing. Assuming maximum maximum rainfall or or fire water b) Hold maximum maximum inventory that can be be drained into the the system during upsets upsets (i.e. from diesel, ATF, or Closed drain system)

Open Drain Caisson Pump

-

Configuration Configuration : 2 x 100% (one (one installed installed and one one uninstalled uninstalled spare)

-

Type : semi-submerged semi-submer ged pump

-

Capacity : ≥ submerged pump flowrate of 5 m /hr and within a reasonable pumping time

3

11.2

Fuel Gas Syst em Fuel Gas System is designed for high-pressure gaseous fuel for gas turbines of main power generators and DH gas compression system. The system also supplies lowpressure fuel gas as pilot gas/ignition gas for the HP/LP flare tips and as primary purge gas for the HP/LP flare header. The low-pressure fuel gas is also supplied to the TEG Regeneration Regeneration System for use as stripping gas and blanket gas for TEG Flash Drum and as blanket gas/floatation gas for Induced Gas Floatation Vessel. Fuel Gas System is designed to cater for the overall fuel requirement on BK-TNG for the operation of existing phase. The system consists of pre-heater, pressure letdown valve (PCV), scrubber, filter and superheater. superheater. The normal fuel gas supply is dehydrated gas from TEG Contactor with back-up fuel gas supply tapped from the Production Separator gas outlet. Fuel gas is treated to achieve the fuel specification for gas turbines of main power generators and DH gas compressor. Design Design Considerations Considerations


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-

Capacity: system shall shall be designed for all continuous users , 3.3 MMSCFD. MMSCFD.

-

Pressure at battery battery limit: 25 bar bar g for HP users; 7 bar g for LP users

Fuel Gas Preheater

-


-

Type : electric heater

-

Heater duty : 31kW 31kW that is to provide heating heating duty such that temperature at downstream of pressure letdown valve is higher than the hydrate formation temperature by at least 5 °C

Fuel Gas Gas Scru bber

-


-

Type : 2 phase vertical scrubber

-

Scrubber sizing is governed governed by the worse case of : i)

Gas/liquid separation based on maximum fuel gas flow expected or

ii)

Buffer volume for GTG change over – in 30 seconds

Fuel Gas Gas Filt ers

-


-

Type : cartridge filter

-

Filtration specification : 99% removal of solid particles 5 microns microns and above

Fuel Gas Superheater

11.3 11.3

-


-

Type : electric heater

-

Heater duty : 60 kW that that is to provide provide 28°C superheat to meet the gas turbine fuel requirement

Instrument/Utilit Instrument/Utilit y Air System The Instrument/Utility Air System is provided for instrument and utility air demand. The supply is distributed to the users at BK-TNG. Part of instrument air is used to produce Nitrogen. The system consists of Air Compressor Packages, Air Dryer Packages and Instrument Air Receiver. The Air Compressor Package consists of electric motor driven oil-injected air compressors and associated equipment. Instrument Air Dryer Package consists of 2 trains of 1x100% Pre Filter, 1x100% Dual Desiccant Tower and 1x100% After Filter. 2 x 100% Air Compressors, operated on a lead-lag1-lag2 lead-lag1-lag2 basis. Instrument air users include all pneumatic controllers, valve actuators, and purging of control panel. Utility air is used mainly for air hoists, winches, air motors, sand blasting, air tools, etc. 3 The Instrument and Utility Air system is envisaged to be designed for 1250 Sm /hr of compressed air requirement


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Ai r Co mpres mp res so r Pac kag es

-


-

Type : rotary screw oil injected

The compressors shall be mounted on Skid 3

-

Capacity: 1250 Sm /h @ 10.0 barg

Ai r Dr yer Pack ages

-

Configuration Configurati on : 2x 100%

-

Type : Pressure swing adsorption (heatless) type dual desiccant towers

-

Instrument air water dew point specification : 0 C @ 7 barg

-

Capacity: 1250 Sm /h

-

Specification per ISA requirement: requirement:

o

3

i)

Maximum of 3 μm particle size in the instrument air system

Instrument Ai r Receiver Receiver

11.4 11.4

-


-

Type : knock-out drum

-

The buffer buffer volume for Instrument Instrument Air Receiver Receiver is sufficient sufficient to provide provide 15 minutes of normal continuous continuous air consumption with instrument air pressure drops from 7.5 barg to 4.5 barg

Nitro gen System Low-pressure nitrogen is used as separation gas for DH Compressors, back-up purge gas for the flare system, blanketing gas for vessel and tank and as maintenance purge for equipment. The facilities that require nitrogen blanketing include Methanol Storage Tank. Instrument air is used to generate 97% Nitrogen. The Nitrogen system consists of a generator, a booster compressor, and a receiver. Nitro gen Generator Generator Package

-


-

Capacity : 120 Sm /h which is maximum of the following and therefore adequate for

3

a. continuous users i.e. Separation gas for for DH compressor seal b. Start up requirements requirements i.e. i.e. HP/LP back up flare purge purge and nitrogen blanketing blanketing c. Maintenance Maintenance requirement requirement i.e. Purging of one one largest largest vessel vessel to make it hydrocarbon free within 4 to 6 hours d. Peak requirements requirements i.e. separation separation gas gas requirement requirement during cold static conditions Nitrogen Boost er Compressor Package Package

-

Configuration Configurati on : 1x 100%

-

Type :

-

Capacity: 50 Sm /h which is adequate to fill 4 50-liter-nitrogen cylinders from 8 barg to 200 barg within 1 hour

3

Nitrogen Receiver


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11.5

-


-

Type : vertical drum

-

The buffer buffer volume volume for Nitrogen Receiver is sufficient to provide 5 minutes minutes holdup holdup time of maximum continuous nitrogen requirement from 8 barg to 4 barg for operational convenience to accommodate demand surges

HP & LP Flare Syst em HP and LP Flare System are provided for safe disposal of hydrocarbons released from pressure reliefs, blowdown, continuous and intermittent operational flaring. The Flare System is designed to achieve as low as possible radiation and dispersion on the locations of interest. The design shall consider potential for low temperature and hydrate during all flaring scenarios. The flare design shall consider appropriate limits for the effects of thermal radiation and noise on platform personnel. The HP and LP Flare System consist of the following equipment: •

HP Flare KO Drum

•

HP Flare KO Drum Heater

•

HP Flare Tip

•

LP Flare Tip

•

Flare Ignition Package

•

Flare Boom

The LP flare takes continuous hydrocarbon emissions and emergency release from the LP equipment sources. The hydrocarbon hydrocarbon release is routed to the Closed Drain Vessel via the LP flare header. LP Flare gases separated from the drum are sent to LP Flare Tip for disposal by combustion. Liquid collected in the Closed Drain Vessel is recovered by pumping back to the Condensate Dewatering Separator. Gases and liquid released from the HP equipment sources is routed to the HP Flare KO Drum via HP flare header. HP flare separated from the drum is sent to the HP Flare Tip for disposal by combustion. Liquid separated in the HP Flare KO Drum is routed to Closed Drain system. Electrical heaters are provided in both HP Flare KO Drum and Closed Drain Vessel to heat up the collected liquid to avoid wax formation due to low operating and ambient temperatures. Besides acting as the holdup drum for HP flare gases and liquid, the HP Flare KO Drum also functions as process liquid drains drum. HP process condensate are routed to HP Flare KO Drum through a continuous HP process condensate header. Similarly process drain from Low Pressure sources like Induced gas Floatation Unit of the Produced Water System, DH Slug Catcher are routed to the Closed Drain Vessel. The HP and LP flare headers are purged by fuel gas to prevent air ingress into the headers. The fuel gas purge is backed up by nitrogen purge.


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HP Flare Flare KO Drum

-


-

Type : horizontal two-phase knock-out drum with double inlets and and submerged submerged heater heater

-

Gas capacity and droplet size: Removal of liquid droplet with size 600 µm and above considering liquid in the vessel at its maximum level.

-

HP flare flare system system is designed for flaring/relief flaring/relief of complete complete platform production. No credit credit is being taken for reduced production when the platform will be at its relieving pressure.

-

Liquid capacity capacity : the HP Flare KO Drum is designed designed for for a hold-up hold-up of 15 minutes from LAH setting to the maximum liquid level for the maximum liquid relieving flow to the HP Flare KO Drum during emergency

HP Flare KO Drum Heater

-


-

Type : electric electric heater heater (submerged (submerged in HP Flare KO Drum) Drum)

-

Duty : suitable to heat up max liquid inventory from minimum ambient temperature to 30°C within 5 hours

HP Flare Tip

-


-

Type : sonic sonic flare tip and smokeless (at design design flow)

-

Capacity : 3.4 MMSCMD @ 2 bar ΔP

Flare Ignition Package

-

Configuration Configuration : 2 x 100%, each each package package of different different kind of ignition ignition system system

-

Type : flame front generator and one one high energy spark spark type with with propane propane bottles as back-up and start-up purpose

Note: HP Flare KO Drum is located at elevated location to allow gravity flows of KO liquid to Closed Drain system LP Flare Tip

-


-

Type : pipe pipe flare and smokeless (at design flow)

-

Capacity : 0.015 MSCMD @ 0.05 bar ΔP, that is based on maximum emergency gas load from LP equipment

Flare Boom Length Determination The length and decline angle of flare boom is determined in such a way that the radiation level at any point of platform where personnel may exist is limited to : i.

4.73 kW/m2, including solar radiation, based on the intermittent peak flowrate through HP Flare Tip and/or LP Flare Tip. The radiation is calculated based on the solar radiation and relative humidity as shown in Section 10.5 and 10.6 respectively.

ii.

1.58 kW/m2, excluding solar radiation, based on continuous flowrate through HP Flare and/or LP Flare Tip. The radiation is calculated based on the solar radiation and relative humidity as shown in Section 10.5 and 10.6 respectively.


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11.6 11.6

Potable Water & Wash Water Water System Potable water is provided for personal use in the living quarters and also for safety showers and emergency eyewash at BK-TNG. The normal potable water supply is produced from seawater with back-up potable water supply from boat. Potable Water System consists of the followings: • Potable Water Filter • Potable Water Maker Package • Potable Water Storage Tank • Potable Water Pumps • Potable Water UV Sterilizer Wash water is supplied to the Wash Water Station and Sewage Treatment. It is tapped from the Seawater System. Potable Water Maker Package

-

Configuration Configuration : 2 x 100% potable water makers makers in one package

-

Type : Reverse Osmosis

-

Water quality : WHO drinking water quality

-

Capacity: 0.36 m /h, that is consumption rate of 0.25 m /POB/day for 29 POB with 20% margin.

3

3

Potable Water Stor age Tank Tank

-

Configuration Configuration : 1 x 100% (one tank with 2 compartments) compartments)

-

Type : atmospheric tank

-

Capacity: 35 m total. In order to reduce the weight and size of the tank, the Potable water storage tank is sized to store 4 days based on normal 29 POB and 5 operation of safety shower and eye wash stations

5

Potable Water Water Pumps

-


-

Type : centrifugal centrif ugal pump

-

Capacity: 15 m /h based on the required potable water for 15 showers to be used concurrently with 7L/shower/minutes 7L/shower/minutes plus water for one eyewash/safety shower

-

The pumps pumps is designed designed to provide potable potable water water pressure of at least least 4 barg barg at living quarter and other user battery limits

-

The duty pump is designed to run continuously to keep the pressure in the potable water header. Any excess potable water to be spilled back to Potable Water Storage Tank through a flow control valve, which keeps the pump operating at its rated capacity.

3

Potable Water Water Inlet Filt er The filter is to filter the potable water supplied from onshore.

-


-


-

Filtration specification : 99% removal of solid particles 40 microns microns and and above above


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PROCESS AND UTILITY DESIGN BASIS Page 40 of 50 3

-

The capacity of the filter is taken to 80 80 m /hr, which is the assumed delivery flowrate from the delivery pump at supply boat

Potable Water UV Steril Steril izer

-


-

Type : UV sterilizer

-

Capacity: 15 m /h

3

11.7

Seawat Seawater er Syst em Seawater is supplied to the following users: • • • • •

Feed water for Potable Water Maker Feed water for Hypochlorite Package Pressurization for firewater ring main Living quarter for toilet flushing (as backup) Backflow to standby standby Seawater Seawater Lift Pump and Firewater Firewater Pump Pump for protection from marine growth.

Seawater is pumped by the Seawater Lift Pumps located in the Seawater Lift Caissons. Seawater is filtered by Seawater Filters to remove any solid particles prior distribution to the users.

-

Capacity: capacity capacity includes includes maximum maximum consumption consumption rate from all continuous continuous seawater users and frequently intermittent users plus 20% margin for additional requirement from vendor packages and future user demand.

Seawater Lift Pumps

-


-

Type : vertical lift pump

-

Capacity : 55 m /h, which includes maximum consumption rate from all continuous seawater users and additional demand for operation of one fire water hose reel of 28 3 m /h

-

Location: 2-3 2-3 meters below below the minimum possible possible water water level in caisson considering considering variations due to tides and waves

3

Seawater Lift Caisson

-


-

Bottom termination termination of caisson : at least least 10-15 meters below below the pump elevation

Seawater Seawater Filt ers

-


-

Type : basket type or equivalent

-


Hypochlorite Package

-

Configuration Configuration : 1 x 100% (with inside package equipments equipments provided with at least least 2 x 50% configuration)


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PROCESS AND UTILITY DESIGN BASIS Page 41 of 50 3

-

Capacity : 3.5 m /h that is to adequately provide shock dosing of one standby pump plus normal dosing for one continuous pump, approximately 3.6 kg/h Cl 2 equivalent

-

Dosing rate :

2 ppm wt (normal) 4 ppm wt (max/shock)

11.8

Diesel Fuel Syst em Diesel Fuel System is provided on BK-TNG to supply liquid fuel to the following users: • • • •

Emergency Generator Diesel-driven Firewater Pumps Crane diesel engines Survival crafts

Diesel is supplied to the platform from onshore by boat. From the supply boat, raw diesel is pumped to an an atmospheric tank tank located in Crane Pedestal. Diesel is filtered by a Raw Diesel Coarse Filter where all coarse solids are removed prior to be transferred to and atmospheric storage tank. Diesel Transfer Pump transfers diesel from the storage tank located in the crane pedestal to the users. Diesel Filter Coalescers are provided at downstream of the transfer pumps to filter diesel to meet the fuel requirement for users. Diesel storage is based on five (5) days base load for full life support for maximum POB during prolonged process shutdown. This means diesel is used to power the Emergency Diesel Generator to provide power supply to personnel on the living quarters and control room for life support and possible users on platform during maintenance maintenance activity. Raw Raw Diesel Coarse Filt er The coarse filter is to filter the diesel supplied by boat.

-


-


-


-

Capacity : 80m /h (assumed maximum flowrate from boat transfer)

3

Raw Raw Diesel Storage Tank

-

Configuration Configuration : 1 x 100% (one tank with 2 compartments) compartments)

-


-

Capacity: 39.8m , that is 5 days holdup base load for full life support for maximum POB during prolonged process shutdown to support the power required for maintenance activities on platform and startup requirement. The storage capacity is within LAL to LAH of the tank.

3

Diesel Transfer Pumps

-


-

Type : centrifugal centrif ugal pump

-

Capacity : minimum flow rate of 5 m /hr

-

The pump pump is designed designed to develop sufficient discharge discharge pressure pressure to deliver deliver diesel at 1.5 barg to deck crane filling nozzle inlet.

3


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-

The diesel pumps are envisaged to have intermittent operation for filling up the day tank of respective users and for cleaning of raw diesel into clean diesel compartment.

Diesel Fuel Coalescer

11.9 11.9

-

Configuration Configuration : 1 x 100% 100% (with 100% spare element)

-

Type : filter coalescer

-

Filtration specification specification : 99% 99% removal of of solid particles particles 10 microns and above above and removal of free water content down to 200 ppmv to suit the requirement for Emergency diesel generators and Fire water pumps

Chemical Injectio n System Chemical Injection System is designed to cater for the chemical requirement of the overall facilities. Chemical Injection Injection System installed on BK-TNG includes includes the following: following: •

Wax Inhibitor

•

Corrosion Inhibitor

•

Methanol Injection

•

Reverse Demulsifier

Each Injection System consists of storage tank and pump package with 2 x 100% pump configuration, configuration, except for methanol as it is only required for start-up. In case there are multiple injection points, the injection rates can be controlled individually to each injection point by using Injection Rate Control Device (IRCD). Chemical is injected via the injection atomizing quill or atomizer to provide good dispersion. 11.9.1 11.9.1 Wax Inhibi tor -

Wax inhibitor is inject inject to condensate export header to avoid wax formation occur in export pipeline as per Flow Assurance Study report. In addition, injection points are provided provided on each flowline upstream of choke as during initial year well flow stream temperature appears close to WAT.

Wax Inhibitor Storage Tank

-


-


-

Storage capacity : 5.5 m /h, that is7 days of maximum continuous usage

3

Wax Wax Inhibitor Injection Pump

-

Configuration Configurat ion : 2 x 100% pumps in the package

-

Type : metering pump

-

Capacity : 31 liter/h, liter/ h, based on requirement of 1000 ppm wax inhibitor in hydrocarbon condensate in export pipeline.

11.9.2 11.9.2 Corros ion Inhibi tor Corrosion inhibitor is injected in the gas export header when due to process upsets undehydrated undehydrated wet gas is exported into the pipeline. pipeline. This is to mitigate possible corrosion inside the export pipeline caused by water drop-out from the process stream.


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-

Injection points: export gas header

Corrosion Inhibi tor Storage Tank Tank

-


-


-

Storage capacity : 15 days of maximum continuous usage and minimum 2m to ensure no overfilling from tote tank transfer

3

Corrosion Inhibitor Injection Pump

-


-


-

Capacity : 1 liter/h, based on dosage rate of 30 ppm by volume on liquid flowrate

11.9.3 11.9.3 Methanol Injectio n Methanol storage tank is blanketed with nitrogen to minimize methanol in contact with oxygen in the air, which degrades methanol. Methanol is injected upstream of the choke valve to mitigate hydrate formation during well start-up. Continuous injection of Methanol is not envisaged. Only intermittent injection during Cold start up is required

-

Injection points: upstream choke of each flowline

Methanol Storage Drum

-


-

Type : pressure pressure vessel storage tank with nitrogen blanketing

-

Storage capacity : 5.5m , adequate for 1 well start-up

3

Methanol Injection Pump

-

Configuration Configuration : 1 x 100% ( due due to intermittent requirement) requirement)

-

Type : reciprocating pump

-

Capacity : 5.5 m /h, that is to provide sufficient injection rate to prevent hydrate formation when starting up one well at 40% design flowrate

3

11.9.4 11.9.4 Reverse Demusi fi er

-

Injection points : In produced water downstream of Condensate-Dewatering Condensate-Dewatering Separator Dosing rate : 0.2 liter/h, based on on 20 ppmv on Produced water water flowrate

Reverse Reverse Demulsi fier Stor age Tank Tank

-


-


-

Storage capacity : 15 days of maximum continuous usage and minimum 2 m to ensure no overfilling from tote tank

3

Reverse Demulsifier Injection Pump

-


-



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-

Capacity : 0.2 liter/h, based on dosage dosage rate of 20 ppmv ppmv on on Produced Produced water water rate

11.9.5 Chemical Chemical Filling All chemicals shall be filled in the platform storage tanks by Tote tanks that shall be supplied by boat. Tote tank storage of approximately 15 days of supply in the platform shall be maintained Filling of Storage tanks from Tote tanks shall be by gravity 11.9.6 Future Requirement Necessary injection points shall be kept for injection of the following chemicals a. Pour point Depressant b. Demulsifier c. Scale Inhibitor d. Biocides Current design does not consider the requirement to inject the above chemicals, however, if required can be considered in future with temporary setups 11.10 11.10

Power Generatio n There are two independent independent and self-contained electric power supplies: • main electric power supply system • emergency electric power supply system The electric power generated on BK-TNG supplies to all services/loads necessary for maintaining the platform in normal operation without recourse to the emergency source of power. The main power is generated from Gas Turbine Generator Packages (GTG) provided in 2 x 100% configuration. configuration. Fuel gas is the primary fuel for the gas turbine turbine generators. Emergency Diesel Generator Package (EDG) with diesel engine is provided to supply the required emergency power for the essential users when main power generators shutdown or during black start-up. The GTG capacity shall include 20% spare power Gas Turbine Generators (GTG) Package

-


-

Type : gas drivers

-

The gas gas turbine for generators generators is de-rated de-rated at maximum ambient temperature of 35 C

o

Note: Main Power Generator System capacity includes 20% spare power and is designed such that all turbine generators (including stand-by generator) can operate simultaneously parallel together.

-

Capacity : 3224 kW min required output power

Emergency Diesel Generator Generator Package

-


-

Type : diesel engine driver


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11.11 11.11

Capacity : 1126 kW min required output power

Avi ation Fuel System Helicopter re-fuel facility is provided by the Aviation Fuel System at the BK-TNG. The system consists of Aviation Fuel Pods, Aviation Fuel Pumping Skid and Dispensing Skid. The Aviation Fuel System on Thien Ung Platform is designed in accordance to requirement as stated in CAP 437. 3

There are three (3) portable aviation fuel pods with a capacity of 2.0m each. One (1) pod is hooked up to Aviation Fuel Pumping Skid while another one as standby. The third one is on transit to onshore for refilling. The Aviation Fuel Pumping Skid includes the required aviation fuel treatment facilities. Av iat ion io n Fu el Pods Po ds

-

Configuration Configuration : three (3) units

-


-

Capacity : 2.0 m each. The capacity of each fuel pod is sufficient to provide at least one filling for helicopter model MI-172

3

Av iat ion io n Fuel Fu el Pu mpin mp in g Sk id

-

Configuration Configurat ion : 2 x 100% pumps

-

Capacity : 13.5 m /hr

3

Av iat ion io n Fuel Fu el Di sp ens ing in g Sk id

-


-

Capacity : 13.5 m /hr

3

11.12 11.12

Sewage Syst em Sewage from Living Quarters is piped to the Sewage Treatment Package. The biological type Sewage Treatment Package is designed to treat black and grey water from the living quarter prior discharge to the Sewage Water Disposal Caisson. Sewage Treatment Package

-


-

Type : Biological Biological type complete with pump, pump, blower blower and and all standard accessories

-

Discharge quality quality specification : as per requirement requirement in Vietnam Vietnam Petroleum and Protection Environment Law

-

Capacity : 29 POB

-

The Sewage Treatment Package is designed to handle seawater as the black water produced contains seawater (seawater is used for toilet flushing)

Sewage Sewage Water Water Disp osal Caisso n

-


-

Capacity : 8 m /day based on 29 POB

3


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11.13 11.13

Future Design Provis ions

11.13.1 Sand Disposal Sand removal and disposal may be required late in field life. Sand recovery is currently assumed to be shipped to shore for treatment and safe disposal. Provision of tie-in shall be kept to install sand cleaning facilities in the future. 11.13.2 11.13.2 Riser Space shall be kept for a future 16”riser in future. However, no space shall be considered for any Launching / Receiving facility in the platform for this future riser 11.14 11.14

Fire Fighti ng System Refer to Safety Design Basis Doc no 1014-BKTNG-SA-RPT-0014 1014-BKTNG-SA-RPT-0014


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12.0

REFERENCES 1.

ITB for Provision of of FEED Services Services for Thien Ung Ung Fixed Platform Attachment 1 of Chapter II Technical Technical Requirements Requirements and Scope Scope of Supply Supply Scope of Work

2.

KOM MOM Oct-29-2013 Oct-29-201 3 and Oct-30-2013

3.

Compositions Compositions and production profile of of Dai Hung-02 gas

4.

1014-PR-TI-0001 1014-PR-TI-0001 – Process Design Parameters

5.

1014-PM-TQ-0002 1014-PM-TQ-0002 – Request of of Company Company Confirmation for FEED Basis Basis Assumptions Assumptions

6.

1014-PM-MOM-0004

7.

Email confirmation of “Process “Process need list for DH compressor” compressor”

8.

Email confirmation of “DH gas arrival composition_VSP” composition_VSP”

HOLDS:

1.

Type of DH Gas Compressor is on hold


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APPENDIX A UNITS OF MEASUREMENT


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QUANTITY Amount of Substance Substance Area Calorific Value (Gases Vol. Basis) Calorific Value (Mass Basis) Calorific Value (Mole Basis) Calorific Value (Solid & Liquid Vol. Basis) Concentration Concentration (Mass / Volume) Concentration Concentration (Mole / Volume) Concentration Concentration (Volume / Mole) Cooling Duty Density (Gas / Liquid / Solid)

Energy

Flowrate (Mass Basis)

Flowrate (Mole Basis) Gas Flowrate (at standard condition) Flowrate (Volume Basis)

Heat Flux Heat Release Rate Heat Transfer Coefficient Heat Transfer Coefficient Heat Transfer Coefficient (Volumetric) Length

Mass Power

Pressure

UNIT

AB BREVIATION

Mole square meter kilojoules per normal cubic meter kilojoules per kilogram kilojoules per mole kilojoules per cubic meter

mol m² 3 kJ/Nm kJ/kg kJ/mol 3 kJ/m

kilograms per cubic meter moles per cubic meter cubic meters per mole Kilowatts kilograms per cubic meter grams per cubic centimeter grams per liter Joule kilojoule kilowatt hour kilograms per second kilograms per hour grams per second moles per second Millions standard cubic meter per day cubic meters per second cubic meter per hour decimeters cubed per second liters per second Watts per square meter Watts per cubic meter Watts per square meter per degree Kelvin Watts per square meter per degree Kelvin Watts per cubic meter per degree Kelvin Micron millimeter centimeter meter kilometer kilogram metric tonne Watt kilowatt megawatt

kg/m 3 mol/m 3 m /mol kW 3 kg/m g/cc g/l J kJ kWh kg/s kg/hr g/s mol/s MMSCMD 3 m /s 3 m /hr 3 Dm /s l/s 2 W/m 3 W/m 2 W/m K

Bar millibar

bar mbar

3

2

W/m K 3

W/m K μm

mm cm m km kg ton W kW MW


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QUANTITY Specific Entropy Specific Heat Capacity (Mass) Specific Heat Capacity (Mole) Specific Volume Surface Tension Temperature Thermal Conductivity Time

Velocity Viscosity (Dynamic) Viscosity (Kinematic) Volume

UNIT Newtons per square metre kilojoules per kilogram per degree Kelvin kilojoules per kilogram per degree Kelvin kilojoules per kgmole per degree Kelvin cubic meters per kilogram cubic meter per mole Dynes per centimeter degree Celsius degree Kelvin Watts per meter per Kelvin Second minute hour meters per second Centipoise Centistokes cubic meter decimeter cubed liter

AB BREVIATION 2

N/m kJ/kg K kJ/kg K kJ/kgmol K 3

m /kg 3 m /mol Dyne/cm °C o K W/m K s min hr m/s cP cS 3 m 3 Dm l

Exceptions: 1.

Customary units, units, i.e. inch (in or “) and pounds pounds per square square inch (PSI), can be used for defining defining pipe diameter and the size and rating of pipe fittings, flanges, gaskets and valves.

2.

Customary and/or ASME / ANSI rating of classes 75, 125, 150, 300, 600, 900, 1500 and 2500 may be used to define valve and flange rating.

3.

Customary and/or API / ANSI rating of classes 800, 1000, 2000, 3000, 5000, 6000 and 10000 may be used to define pressure rating of flanges, fittings, valves, gaskets and ring-type joints for wellhead equipment.

4.

Customary units of of volumetric flow rate, such such as barrels per day day (BPD) and gallons gallons per minute (GPM), may be used for oil and water measurement where applicable. applicable.

5.

For gas flowrate, expressing expressing the gas gas flowrate in imperial imperial unit of “MMSCFD” “MMSCFD” in addition addition to SI unit of “MMSCMD” is acceptable. acceptable.

6.

Customary unit unit of pound per MMSCF (lb/MMSCF) may be used for defining moisture content content in gas volume

7.

Customary unit of “atm” may be used interchangeable interchangeable with “bar”

Process and Utility Design Basis (Offshore Platform)

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