Idbc-ts-przzz-c00004 Rev 2 Chemical System Study

IDBC-TS-PRZZZ-C00004

BANYU URIP PROJECT

CHEMICAL SYSTEM STUDY

02 Nov 12 Rev 2

MPI: Not Classified

Page 2 of 17

REVISION MODIFICATION LOG Revision

Section

A

All

Issued for Review

B

All

Issued for Approval

0

Page 6

Addi ng Reference Reference List

Page 7

Addi ng CFF and PPF in the list of Definitio n

Page 13

Addi ng Container and Storage Locati on in to Table 4 and Table 5.

Ap pen di x 1 1

2

All

Description

Ad di ng Con ti ng ency enc y t o t he calc c alc ul ati on . Re-Issued Re-Issued For Use

Page 5

Correct Water Clarifier specifi cation

Page 8

Revise water specifi cation based on the latest spec agreed with GTG vendor

Page 9 -10

Revise Table 1 as per MCL com ment s

Page 11

Revise Table 2 as per MCL MCL comments

Page 12 -13

Revise Table Table 3 as per MCL MCL com ment s

Ap pen di x-1

Revise Revi se Calcu Cal culat lat io n as per MCL co mmen ts

All

Revised based on Vendor’s info rmatio n and COM COMPANY PANY’s ’s comment

IDBC-TS-PRZZZ-C00004 Rev 2 CHEMICAL SYSTEM STUDY working.doc


BANYU URIP PROJECT


02 Nov 12 Rev 2

MPI: Not Classified

Page 2 of 17

REVISION MODIFICATION LOG Revision

Section

A

All

Issued for Review

B

All

Issued for Approval

0

Page 6

Addi ng Reference Reference List

Page 7

Addi ng CFF and PPF in the list of Definitio n

Page 13

Addi ng Container and Storage Locati on in to Table 4 and Table 5.

Ap pen di x 1 1

2

All

Description

Ad di ng Con ti ng ency enc y t o t he calc c alc ul ati on . Re-Issued Re-Issued For Use

Page 5

Correct Water Clarifier specifi cation

Page 8

Revise water specifi cation based on the latest spec agreed with GTG vendor

Page 9 -10

Revise Table 1 as per MCL com ment s

Page 11

Revise Table 2 as per MCL MCL comments

Page 12 -13

Revise Table Table 3 as per MCL MCL com ment s

Ap pen di x-1

Revise Revi se Calcu Cal culat lat io n as per MCL co mmen ts

All

Revised based on Vendor’s info rmatio n and COM COMPANY PANY’s ’s comment



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Page 3 of 17

Contents 1.

INTRODUCTION.........................................................................................................................4 1.1

Production Chemicals ........................................................................... ................................................................................................................. ...................................... 4

1.2

Non-Production Chemicals .................................................................................. ......................................................................................................... ....................... 4

2.

REFERENCES............................................................................................................................6

3.

SCOPE........................................................................................................................................7

4.

DEFINITION................................................................................................................................7

5.

DESIGN BA SIS AND CRITERIA ............................................................................. ............................................................................................... .................. 8 5.1

Design Basis ............................................................................. ...............................................................................................................................8 ..................................................8

5.2

Design Criteria .......................................................................... ............................................................................................................................9 ..................................................9

6.

CHEMICAL CONSUMPTION CONSUMPTION .................................................................................... ..................................................................................................... ................. 9 6.1

7.

Chemical Flammability and Toxicity..........................................................................................13 CHEMICAL STORAGE ................................................................................ ............................................................................................................ ............................ 14

App A pp end en d i c es Appendix 1 – Calculation – Chemical Consumption Appendix 2 – Simplified PFD Appendix 3 – Well and Well-pad Design Rates – Table 10-3 Facilities Design Basis Appendix 4 – Heat and Mass Balance Flow Summary by Case – Table 10-9 Facilities Design Basis Basis Appendix 5 – Well Fluid Composition – Table 8.1 ~ Table 8.2 and Table 10-4 ~ Table 10-6 Facilities Design Basis



BANYU URIP PROJECT

1.


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Page 4 of 17

INTRODUCTION INTRODUCTION B0

This report summarizes chemical injection system in the Banyu Urip Central Field Facility (CFF). Calculation result in this report is based on chemical dosage injected to a certain point based on vendor information. Chemicals vendors approved by COMPANY are contacted to provide required information for the chemical tank sizing, pump sizing and allocation of the area for the chemical tanks. Contingency of 10% to the calculation is added to cover any uncertainties information that could have different dosage between selected vendor and current information from contacted vendor. Chemical consumption shown here in this report may change subject to dosage used by the selected vendor.

1.1 1.1

Product ion Chemicals

Production chemicals are recommended for product quality and flow assurance, these chemicals including: -

Pour Point Depressant 

-

To mitigate the risk of production flowline plugging due to crude oil gelling.

Demulsifier 

To aid separation process of the oil and water

-

Antifoam (Oil Treatment Type)

-

H2S Scavenger 

To meet H2S content specification (not exceed 10 ppm), injected during process upset conditions

-

Scale Inhibitor 

-

To avoid plugging due to uncontrolled scale deposition

Methanol 

To avoid hydrate formation at choke valves during start-up and blowdown of gas injection/cap gas production flowlines

-

Paraffin / Wax Inhibitor 

1.2 1.2

Preventing or inhibiting wax formation in export pipeline

Non-Prod Non-Prod ucti on Chemicals

Non-Production Chemical for water quality and corrosion control including: -

Corrosion Inhibitor



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Oxygen Scavenger 

Injected to achieve a dissolved oxygen level of less than about 20 ppb for adequate control of corrosion rates in the carbon steel injection water flowlines and well tubing

-

Antifoam (Water Treatment Type) 

-

Injected to control foam formation in the water deaerators

Antifoam (Amine Treatment Type) 

Injected to remove acid gases from a hydrocarbon process flow such as hydrogen sulfite and carbon dioxide

-

Phosphoric Acid 

Is recommended to install provision points for batch treatment of the Lean Amine Inlet lines to the AGRU and AGE Absorber

-

Glycol pH Control 

To maintain pH of the tri-ethylene glycol (TEG) between 6.5 and 7.5 for proper performance

-

Water Clarifier 

Injected to help to settle out solids suspended in the fluid stream by means of coagulation ; i.e Iron(III) Chloride and Lime

-

Polyelectrolyte 

Is added to water to aid the chemical coagulation process by increasing the speed of particle charge neutralization and physical combination of small particles into masses sufficiently large to be filtered out.

-

Additional Chemicals for pH Neutralization and Control 

To avoid excessive corrosion of topsides pipework and other process equipment with which it may come into contact

-

Hypochlorite 

To limits the effect of organic material and protection from contact with pathogenic organism

-

Hydrochloric Acid (HCl) 

-

To clean Hypochlorite generation package system.

Sodium Hydroxide (NaOH)



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To neutralize water from sulfur pelletizer system if direct contact type of pelletizer is utilized.

-

-



For BFW treatment and Condensate Polishing Unit , bed regeneration



For Sodium hydroxide injection package of Neutralization Pit, make up of day tank



For Hypochlorite generation package , chemical cleaning



For Reverse Osmosis Unit , UF backwashing and RO chemical cleaning

Sulfuric Acid 

For BFW treatment and Condensate Polishing Unit , bed regeneration



For Reverse Osmosis Unit , UF backwashing and RO chemical cleaning



For Sulfuric acid injection package of Neutralization Pit, make up of day tank

Morpholine 

To maintain pH of BFW system between 8 and 9.5 for HRSGs, SRU WHB & TO WHB and Package Boiler

-

Sodium Metabisulfite 

-

Calcium Chloride (CaCl2) 

-

To remove chlorine to prevent oxidation of membrane at the RO unit

To maintain salt level of WHO drinking water quality

Sodium Bicarbonate (NaHCO3) 

To maintain salt level of WHO drinking water quality



Most of the chemicals for the Banyu-Urip facility are injected continuously, such as corrosion Inhibitor due to the corrosive nature of the Banyu Urip produced fluids, and a desire to use carbon steel for the FWS flow-lines and much of the hydrocarbon and produced water process trains

2.

REFERENCES

[1] FACILITY DESIGN BASIS

IDBU-ED-BBPDB-000002_Rev 3

[2] HEAT AND MASS BALANCE – NON LICENSOR

IDBC-TS-PCCAL-C00011_Rev 0

[3] HEAT AND MASS BALANCE – LICENSOR

IDBC-TS-PCCAL-C00013_Rev 1

[4] PROCESS FLOW DIAGRAM – NON LICENSOR

IDBC-TS-PDPFD-XXXXX_Rev 0

[5] PROCESS FLOW DIAGRAM – LICENSOR

IDBC-TS-PDPFD-XXXXX_Rev 0



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[6] EXHIBIT A – SCOPE OF WORK

EPC1: PRODUCTION FACILITIES – B - 3207067

Page 7 of 17 PROCESSING

[7] RECOMMENDATIONS FOR CHEMICAL TREATMENT AND CORROSION MONITORING OF OIL AND GAS PRODUCTION FACILITIES

IDBU-ED-RBPDB-000009_Rev C

[8] SPECIFICATION FOR INITIAL FILL REQUIREMENTS

IDBC-ED-OSPDS-C00011_Rev B

[9] RECOMMENDATIONS FOR CHEMICAL TREATMENT AND CORROSION MONITORING OF OIL AND GAS PRODUCTION FACILITIES

3.

IDBC-ED-RBPDB-000009_Rev C

SCOPE

The scope of this study is stated at the Exhibit A – Scope of Work, chapter 3.3.1.2 item no.7,” Chemical Injection Systems: The P&IDs reflect the chemicals and their injection locations in IDBUED-RBPDB-000009, Recommendations for Chemical Treatment and Corrosion Monitoring of Oil and Gas Production Facilities, in Exhibit E. However, equipment vendors may have chemical treatment requirements that are different that what is shown on the P&IDs, especially with the boiler feed water and raw water treatment systems.” The P&IDs for chemical systems, especially for the boiler feed water and raw water treatment systems will be updated wherever applicable.

4.

DEFINITION

COMPANY

COMPANY is defined as Mobil Cepu Limited (MCL)

CONTRACTOR/PURCHASER

CONTRACTOR is defined as MCL’s appointed representative

VENDOR/SUPPLIER

VENDOR is defined as the company selected to supply the equipment and services detailed in this report. This is the entity having unit responsibility as defined in the industry codes and standards.

CFF

Central Field Facility

CPF

Central Processing Facility

CA

Antifoams

CD

Demulsifiers



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CE

Polyelectrolytes

CH

Biocides

CI

Corrosion Inhibitor, Scale Inhibitor

CM

Methanol, Morpholine

CP

Pour Point Depressant (PPD)

CS

Scavenger (H2S, O2)

CW

Water Clarifier

CX

Caustics

CZ

Acids (Sulfuric Acid, Hydrochloric Acid)

GTG

Gas Turbine Generator

PPF

Production Processing Facility

TDS

Total Dissolved Solid

TSS

Total Suspended Solid

TC/THC

Total Hydrocarbon

WHO

World Health Organization

5.

DESIGN BA SIS AND CRITERIA

5.1

Design Basis

Page 8 of 17

The current four cases of Hysys simulation are considered in determining the required chemical type and dosage injected to the fluids in the CPF area A. Case 1 – Peak Oil and Minimum Produced Water (Year 5) B. Case 2 – Peak Total Liquid and Peak Gas Injection (Year 6) C. Case 3 – Peak Total Liquid and Peak Gas Injection with High H2S and Low C6s (Year 6) D. Case 4 – Peak Produced Water and Oil-Fuel Gas Turndown (Year 19)

Well fluid composition as shown in the table 10-4 of Facilities Design Basis (Appendix 5) is also considered in determining type and dosage of chemicals to be injected.


IDBC-TS-PRZZZ-C00004 CHEMICAL SYSTEM STUDY

BANYU URIP PROJECT 5.2

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Design Criteria

General design criteria will be refer to the project guidelines of Specification for Initial Fill Requirements (IDBC-ED-OSPDS-C00011.) and also Recommendations for Chemical Treatment and Corrosion Monitoring of Oil and Gas Production Facilities (IDBU-ED-RBPDB-000009 Rev C) Water for Boiler and GTG NOx control is requiring treatment to achieve below specification:

6.



pH = 8.0–9.5 for HRSGs, SRU WHB & TO WHB, Package Boiler / pH = 6.0-8.5 for GTG



TDS (ppm) =< 0.1



TSS (ppm) = NIL



TC or THC (ppm) = NIL



Total Organic Matter = NIL



Calcium Hardness as CaCO3 (ppm) = <0.02



Magnesium Hardness as CaCO3 = < 0.02



Conductivity (Microsiemens/cm) = <0.2



Free CO2 (ppm) = NIL



Non Volatile = NIL



Iron (ppm) = <0.03



Total Copper (ppm) = <0.02



Ammonia (ppm) = -

CHEMICAL CONSUMPTION

Chemical consumption for CFF is summarized in the table below. Total consumption rate could be changed depend on the dosage recommended by selected vendor. This total consumption is including 10% margin.

Description

Chemical Dosage

Total Consumption

Level (ppm)

Rate (m /day)

3

Remarks

Min

Max

Min

Max

PPD

200

500

7.0

17.5

Continuous

Corrosion Inhibitor

10

30

0.6

1.7

Continuous

Scale Inhibitor

5

30

0.1

0.8

Continuous



BANYU URIP PROJECT Demulsifier

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50

Page 10 of 17

0.76

3.8

Continuous Not installed now, but may be needed in

Wax Inhibitor

50

250

1.14

5.71

future during low export oil rates to mitigate wax accumulation in offshore pipeline.

5

20

0.4

1.6

Continuous or as required

Containers with 4 L Antifoam

volume will be 5

20

provided on pumps

Batch for AGRU, AGE

suction at the Gas Treating system H2S Scavenger

2

100

0.4

18.4

Oxygen Scavenger

-

2

-

0.28

Batch (All three pumps running) Continuous Continuous and

Biocide/Hypochlorite

0.5

2

18.43

29.02

Intermittent concentration 8000 ppm Batch. At maximum gas

Methanol

3.61

7.03

injection to well at wellpad A and C

200 Liters of 4%-HCL for a maximum 1 hour is Hydrochloric Acid

required for acid chemical cleaning of

Batch

Hypochlorite Generation Package Batch. At Slop Oil Tank

Caustic (30%)

100

500

0.17

0.87

Poly-electrolyte

2

3

0.10

0.15

Continuous

Water Clarifier

5

15

0.37

1.11

Continuous

10

20

0.02

0.03

Morpholine

(Note1)


outlet

Continuous for pH control of BFW


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Manually dosed Ammonia

Batch (during a process

depend on the pH

upset of Quench

As Required

Tower for pH control)

result Manually dosed depend on the water

Calcium Chloride

Batch (for Potable

As Required

quality to meet WHO

Water Dosing Unit)

standard quality Manually dosed depend on the water

Sodium Bicarbonate

Batch (for Potable

As Required

quality to meet WHO

Water Dosing Unit)

standard quality Note.1. Special chemicals to achieve required pH with negligible impact to conductivity and TDS. To be confirmed later .

Table 1 – Chemical Consumption Summary

The detail calculation of the chemical consumption can be found in the attachment 1 of this report. In the package items, chemicals are also required such as to keep Feed and make-up Water for Boiler and HRSG in the specification. Quantity of the chemicals for the package item is shown in table below:

Chemical Dosage Level Description

(ppm) Min

Max

Total Consumption 3

Rate (m /day) Min

Remarks

Max Intermittent for RO unit(1~4 times a day for UF backwashing/once in 4-8 month for RO chemical cleaning) , Condensate Polishing Unit (Once in a

Caustic 30%

1,200

40,000

0.559

week for regeneration) , BFW treatment (25 minutes per regeneration) , Hypochlorite generation package (once in 6 months) and Sodium Hydroxide injection package for Neutralization Pit



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Page 12 of 17 For Package Boiler, continuous during Package Boiler in operating mode (Less than 1,000 hours cumulatively

0.03

0.06

0.025

per year). Scale inhibitor is Phosphate

Scale Inhibit or

Solution based on 1% solution. HRSG Continuously As Requir ed

(Note2)

Thermal Oxidizer and SRU WHBs

Scale Inhibit or (same chemical with sc ale

0.156

5

inhibitor for

Injected to Reverse Osmosis Unit (RO) Continuously

hydrocyclone) Intermittent for RO unit (1~4 times a day for UF backwashing/once in 4-8 months for RO chemical cleaning) , Sulfuric Acid 98%

40,000

24

0.185

Condensate Polishing Unit(Once in a week for regeneration), BFW treatment (25 minutes per regeneration) and Sulfuric Acid injection package for Neutralization Pit

Sodium Hypochlorite Sodium Metabisulfite Calcium Chloride Sodium Bicarbonate Morpholine

0.15

10

0.004

5

0.052

100

0.576

100

0.576

45

0.002

0.574

Injected to Reverse Osmosis Unit (UF) Batch Injected to Reverse Osmosis Unit (RO) Continuously Injected to Potable Water Dosing Unit Continuously Injected to Potable Water Dosing Unit Continuously Injected continuously to Boiler Feed Water treatment package

Note. 1. Concentration to be provided by chemical supplier. Note.2. Chemical injection fitting only for future phosphate injection.

Table 2 – Chemical fo r Package Item



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Water from sulfur pelletizer will be neutralized using Sodium Hydroxide.

6.1

Chemical Flammabilit y and Toxici ty

Below table are shown typical chemicals/solvent Purpose

Pour Point Depressant Produc ed Water Corrosion Inhibitor Demulsifier Surface Scale Inhibitor Morpholine

Antifoam

Typical Chemicals Styrene – Maleic Anhydride Copolimer Imidazoline Acetate Naphtalene, Aromatic Naphta

Specific Gravity (SG) 0.89 – 0.95

1,4-oxazine Glycol Base

Toxic/High Corrosive

33 – 35

Yes

(@15.6 °C)

Not Flammable

No

0.94 – 0.98

28 – 30

Yes

> 93

No

35 – 38

Yes

22.9

No

o

(@15.6 C) 0.98 – 1.02

1.2 – 1.6

Phosphonate Tetrahydro-2H-

o

Flash Point ( C)

(@20 °C) 0.85 – 0.95 0.8 – 1.1 (@21.1 °C)

Alkylamine Benzyl-(C12-C16 H2S Scavenger

Linier Alkyl)-

1 – 1.18 (@15 °C)

Dimethyl-

66 – 69 (ASTM D93)

(Note 1)

Yes

Ammonium Chloride Oxygen Scavenger Biocide

(@25 °C) 1.0 – 1.1

Glutaraldehyde Dimethylamine –

Polyelectrolyte

1.2 – 1.37

Sodium Bisulfide

Epichlorohydrin

(@20 °C) 1.14 – 1.18

Copolymer


(@25 °C)

Not Flammable

No

Not Flammable

No

Not Flammable

No


BANYU URIP PROJECT

Water Clarifier

pH Control

pH Control

pH Control

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Poly Aluminum

1.1 – 1.2

Chloride

(@25 °C)

Water, Amines

1 – 1.1 (@16 °C)

Page 14 of 17

Not Flammable 103 – 106 (PMCC)

No

No

1.48 – 1.54

Sodium

Not Flammable

No

2.044 (Water = 1)

Not Flammable

No

(@25 °C) ASTM

Hydroxyde

D-1298

Potasium Hydroxyde

Hydrochloric Acid

HCl, 30 – 37%

1.1 – 1.19

Not Flammable

Yes

Sulfuric Acid

H2SO4, 90 – 98%

1.75 – 1.85

Not Flammable

Yes

Calcium Chloride

CaCl2, powder

Not Flammable

No

Not Flammable

No

Not Flammable

Yes

12

Yes

Not Flammable

Yes

Not Flammable

No

Sodium Bicarbonate

NaHCO3, powder

2.1 – 2.3 (@68 °F) 2.0 – 2.2 (Water =

Caustic Methanol Sodium Hypochlorite Sodium Metabisulfite

1)

Note 1. Flammable for some Vendors.

Table 3 – Chemical Type and Injectio n Summary

7.

CHEMICAL STORAGE 3

Storage that are provided in the Banyu Urip facility, such as iso tank which has a capacity of 25 m 3

and tote tank with capacity of 2 m for each tank will be used to store chemicals required. The material required for the chemical storage will be based on MSDS required by selected vendor. Chemical requirement for one month consumption is shown in the table below:



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One Month Consumption Chemicals

Dosage (ppm)

3

Containers

(m /month),

Required for

Including batch

30-day Storage

Storage Location

injection PPD Flowline Produced Water Corrosion Inhibitor (CI) Scale Inhibitor (CI)

Demulsifier (CD)

200 – 500

217.4 – 543.5

9 - 22 Iso Tanks

10 – 20

12.1 – 36.3

2 Iso Tanks

5 – 30

4.3 – 25.7

1 Iso Tanks

10 – 50

10.4 – 52.0

1 - 2 Iso Tanks

Area “V/O” and chemical shelter Area “V/O” and chemical shelter Area “V/O” and chemical shelter Area “V/O” and chemical shelter Area “V/O” and

Antifoam (CA)

5 - 20

8.1 – 32.3

1 - 2 Iso Tanks

chemical shelter; Area K for AGRU and AGE

H2S Scavenger (CS)

2 – 402

As Required

Iso/Tote Tank

O2 Scavenger (CS)

5 – 10

6.0 – 12.0

3 - 6 Iso Tanks

Area “V/O” and chemical shelter Area “V/O” and chemical shelter

200 Liters of 4%-HCL for a Hydrochloric Acid

maximum 1 hour is required for acid chemical cleaning of

Iso Tank

Area “P” and chemical shelter

Hypochlorite Generation Package Polyelectrolyte

2–3

3.0 – 4.6

2 - 3 Tote Tanks

Clarifier (CW)

5 – 15

11.4 – 34.3

1 - 2 Iso Tank

Methanol (CM)

As Required

Area “P” and chemical shelter Area “P” and chemical shelter

Tote Tank/Iso

Area “P” and

Tank

chemical shelter

Note. Chemical consumption may change subject to dosage used by selected vendor. Chemical consumption here in this table is including 10% margin.

Table 4 – One Month Chemical Requir ement IDBC-TS-PRZZZ-C00004 Rev 2 CHEMICAL SYSTEM STUDY working.doc


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And for the package vendor, below table is shown one month consumption: One Month Chemicals

Dosage

Consumption

Containers Required for

Storage

(ppm)

(m /month), Including

30-day Storage

Location

3

batch injection Caustics will be Caustics 30%

500 – 40,000

supplied from Sodium

84.5

Hydroxide Tank (ABJ678511)

10,000

9,900 kg/1000 hr

5

0.5

98%

12 – 40,000

Chloride

Sodium Bicarbonate

shelter Area “P” and

2 Iso Tanks

31.77

chemical shelter Area “P” and

5

1 Tote Tank

0.5

chemical shelter

(SMBS) Calcium

shelter

and chemical 1 Tote Tank

Sodium Metabisulfite

chemical

Ar ea “ V/O”

Scale Inhibitor

Sulfuric Acids

Area “P” and

Area “P” and

1 Iso / 100

8.3

chemical 5 Tote Tanks

Area “P” and

1 Iso / 100

shelter

8.3

chemical 5 Tote Tanks

shelter Area “P” and

Ammonia

As Required

(Note 2)

Ammonia Bottle

(Note 3)

chemical shelter Area “P” and

Morpholine

10 – 20

1 Tote Tank

0.54 – 1.08

chemical shelter

Analyzer Calibration

Ar ea “ P” and As Required

(Note 4)

Bottle

Gas Note 1. Chemical consumption may change subject to dosage used by selected vendor. IDBC-TS-PRZZZ-C00004 Rev 2 CHEMICAL SYSTEM STUDY working.doc

(Note 4)

chemical shelter


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Note 2. Estimated 3 to 4 bottles during start-up and shutdown. Note 3. 4-Bottle Rack to be provided for Ammonia Bottles. Note 4. Initial Bottl e to be provided by Vendor, refill b y MCL.

Table 5 – One Mont h Chemical Requirement f or Package Vendor



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Appendix - 1 CHEMICAL CONSUMPTION


APPENDIX

CALCULATION SHEET

Pour Point Depressant (PPD) JOB No:

SO-2435

JOB NAME : CLIENT :

BANYU URIP PROJECT MCL

A. Injection Point - Wellpad

(*ch emical co ncentration :

Total Oil

Wellpad A

Wellpad B

PPD injected

Total Chemical Injected 3

m3/day

ppm

Density (kg/m 3)

m3/day

68

10,811

200

922.7

2.34

70.3

500

922.7

5.86

175.8

200

922.7

3.24

97.2

500

922.7

8.10

243.0

200

922.7

2.58

77.5

500

922.7

6.46

193.8

922.7

6.38

191.3

14,945

75

11,924

1

of

1

w %)

kbopd

94

Wellpad C

100

Page

m /month

PPD Tank Capacity

PPD Supply Pump Capacity

PPD Injection Pump Capacity (ITT)

PPD Injection Pump Capacity (Recommended)

m3

m3/hour (Normal)

l/d (Normal)

l/d (Normal)

40.0

19.0

0 - 15,000 (2x100%)

0 - 10,000 (2x100%)

40.0

19.0

0 - 15,000 (2x100%)

0 - 10,000 (2x100%)

40.0

19.0

0 - 15,000 (2x100%)

0 - 10,000 (2x100%)

Remarks

ContinuousInjection Total for Wellpad s

185

29,413

200 500

922.7

15.94

478.2

1

159

200

922.7

0.03

NA

500

922.7

0.09

NA

200

922.7

0.69

NA

500

922.7

1.72

NA

Low Producing Well

High Producing Well

20

3,180

* 1month=30days

B. Injection Point - Crude Export (Note 4) Total Oil

Crude Export

PPD injected

3


3

kbopd

m /day

ppm

Density (kg/m )

185

30,912

200 500

Margin (%)

Iso Tanks/Month

3

m /day

m /month

922.7

6.70

NA

922.7

16.75

NA

PPD Tank Capacity m

3

PPD Injection Pump Capacity (ITT)

PPD Injection Pump Capacity (Recommended)

m /hour (Normal)

l/d (Normal)

l/d (Normal)

19.0

0 - 40,000 (2x100%)

0 - 20,000 (2x100%)

PPD Supply Pump Capacity 3

40.0

Remarks

Intermittent as required

C. Total PPD Required PPD Dosage (ppm)

3

3

m /day m /month

200

7.0

210.4

500

17.5

526.0

8

10

21

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. PPD dosage is based on Styrene - Maleic Anhydride Copolymer 3. Total Chemical Required is including 10% Margin 4. Range required for each well control valve to cover cases 1 - 4 flows

CALCULATION SHEET

Flowline/ Produced Water Corrosion Inhibito r (CI) JOB No: JOB NAME : CLIENT :

Page

1

SO-2435 BANYU URIP PROJECT MCL


(*c hem ic al c on cen tr at io n :

100

Total Produced Water

Wellpad A

Wellpad B

m /day

68

10,811

94

Wellpad C

3

kbpd

75

14,945

11,924

w %)

CI injected


ppm

Density (kg/m )

3

3

m /day

m /month

10

994

0.11

3.3

30

994

0.33

9.8

10

994

0.15

4.5

30

994

0.45

13.5

10

994

0.12

3.6

30

994

0.36

10.8

10

994

0.32

9.6

CI Tank Capacity 3

CI Supply Pump Capacity 3

CI Injection Pump Capacity

m /hour (Normal)

l/d (Normal)

19.0

19.0

0 - 750 (2x100%)

19.0

19.0

0 - 750 (2x100%)

19.0

19.0

0 - 750 (2x100%)

m

Remarks

Continuous Injection Total for Wellpad s

200.1

31,813

Low Watercut Well

1.0

159

High Watercut Well

10.0

1,590

30

994

0.96

28.8

10

994

0.002

0.05

30

994

0.005

0.14

10

994

0.02

0.5

30

994

0.05

1.4

* 1month=30days

B. Injection Point - CPF CI injected

Add iti ona l Unt reat ed Wat er

kbpd

3


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

LP Production Separator Inlet A

1,728

10

994

0.02

0.5

30

994

0.05

1.6

LP Production Separator Inlet B

1,728

10

994

0.02

0.5

30

994

0.05

1.6 2.4

Crude Oil Stripper A

7,872

Crude Oil Stripper B

7,872

Injection Water Pump Suction

50,112

10

994

0.08

30

994

0.24

7.1

10

994

0.08

2.4

30

994

0.24

7.1

10

994

0.50

15.1

30

994

1.51

45.4

Margin (%)

Iso Tanks/Month

C. Total CI Required 3

3

CI Dosage (ppm)

m /day

m /month

10

0.6

18.6

30

1.7

55.9

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Total Chemical Required is including 10% Margin

10

0.7 2.2

CI Tank Capacity m

3

19.0


m /hour (Normal)


Remarks

l/d (Normal)

0 - 100 (2x100%)

Continuous Injection

0 - 500 (2x100%)


19.0

Continuous Injection (Provision)

of

1

CALCULATION SHEET

Flowline/ Produced Water Corrosion Inhibito r (CI) JOB No: JOB NAME : CLIENT :

Page

1

of

1



(*c hem ic al c on cen tr at io n :

100

Total Produced Water 3

kbpd

m /day

68

10,811

Wellpad A

Wellpad B

94

Wellpad C

75

w %)

CI injected

14,945

11,924

CI Tank Capacity


ppm

Density (kg/m )

3

3

m /day

m /month

10

994

0.11

3.3

30

994

0.33

9.8

10

994

0.15

4.5

30

994

0.45

13.5

10

994

0.12

3.6

30

994

0.36

10.8

10

994

0.32

9.6

3



m /hour (Normal)

l/d (Normal)

19.0

19.0

0 - 750 (2x100%)

19.0

19.0

0 - 750 (2x100%)

19.0

19.0

0 - 750 (2x100%)

m

Remarks

Continuous Injection Total for Wellpad s

200.1

31,813

Low Watercut Well

1.0

159

High Watercut Well

10.0

1,590

30

994

0.96

28.8

10

994

0.002

0.05

30

994

0.005

0.14

10

994

0.02

0.5

30

994

0.05

1.4

* 1month=30days

B. Injection Point - CPF CI injected

Add iti ona l Unt reat ed Wat er

kbpd

3

3

3

ppm

Density (kg/m )

m /day

m /month


1,728

10

994

0.02

0.5

30

994

0.05

1.6


1,728

10

994

0.02

0.5

30

994

0.05

1.6 2.4

Crude Oil Stripper A

10

994

0.08

30

994

0.24

7.1

10

994

0.08

2.4

30

994

0.24

7.1

10

994

0.50

15.1

30

994

1.51

45.4

Margin (%)

Iso Tanks/Month

7,872

Crude Oil Stripper B

7,872

Injection Water Pump Suction

50,112

CI Tank Capacity


m /day

m

3


m /hour (Normal)

19.0


Remarks

l/d (Normal)

0 - 100 (2x100%)


0 - 500 (2x100%)


19.0

Continuous Injection (Provision)

C. Total CI Required 3

3

CI Dosage (ppm)

m /day

m /month

10

0.6

18.6

30

1.7

55.9

0.7

10

2.2


CALCULATION SHEET

Scale Inhibitor (CI) JOB No: JOB NAME :

SO-2435 BANYU URIP PROJECT

CLIENT :

MCL

A. Injection Point - CPF

(*c hemi cal c on cent rat ion :

Total Water

Hydrocyclone Inlet Train A

Hydrocyclone Inlet Train B

3

kbwpd

m /day

103

17,760

103

17,760

100


3

3

m /day

m /month

0.1

4.1

30

0.8

24.8

3

ppm

Density (kg/m )

m /day

3

m /month

5

1,416

0.06

1.9

30

1,416

0.38

11.3

5

1,416

0.06

1.9

30

1,416

0.38

11.3

Margin (%)

Iso Tanks/Month

B. Total CI Required

5

10

0.2 1.0

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Total Chemical Required is including 10% Margin 3. Pump Capacity is recommended to reduce (to be confirmed after chemical vendor selected)

1

w %)

CI injected

* 1month=30days

CI Dosage (ppm)

Page

CI Tank Capacity m

3

40.0



m /hour (Normal)

l/d (Normal)

19.0

0 - 3,000 (Note 3) (2x100%)

Remarks

Continuous Injection.

of

1

CALCULATION SHEET

Scale Inhibitor (CI) JOB No: JOB NAME :


CLIENT :

MCL


(*c hemi cal c on cent rat ion :

100

Total Water kbwpd

m /day

103

17,760

Hydrocyclone Inlet Train A

Hydrocyclone Inlet Train B

103

CI Tank Capacity


3

ppm

Density (kg/m )

m /day

3

m /month

5

1,416

0.06

1.9

30

1,416

0.38

11.3

5

1,416

0.06

1.9

30

1,416

0.38

11.3

Margin (%)

Iso Tanks/Month

17,760

1

of

w %)

CI injected

3

Page

m

3

40.0



m /hour (Normal)

l/d (Normal)

19.0

0 - 3,000 (Note 3) (2x100%)

Remarks

Continuous Injection.

* 1month=30days

B. Total CI Required 3

3

CI Dosage (ppm)

m /day

m /month

5

0.1

4.1

30

0.8

24.8

0.2

10

1.0

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Total Chemical Required is including 10% Margin 3. Pump Capacity is recommended to reduce (to be confirmed after chemical vendor selected)

CALCULATION SHEET

Paraffin / Wax Inhibitor (CI) JOB No: JOB NAME : CLIENT :

Page

1



(*chemi cal concentr ati on : Total Oil

Crude Export

100

w %)

Wax Inhibitor injected 3

kbopd

m /day

185

29,413


Density (kg/m )

m /day

50

1,416

1.04

31.2

1,416

5.19

155.8

Margin (%)

Iso Tanks/Month

B. Total Wax Inhibitor Required 3

3

m /day

m /month

50

1.14

34.3

250

5.71

171.4

10


1.4 6.9

Remarks

3

m /month

250 * 1month=30days

Wax Inhibitor Dosage (ppm)

3

ppm

Future (if required)

of

1

1

CALCULATION SHEET

Paraffin / Wax Inhibitor (CI) JOB No: JOB NAME : CLIENT :

Page

1

of

1



(*chemi cal concentr ati on : Total Oil 3

kbopd

m /day

185

29,413

Crude Export

100

w %)

Wax Inhibitor injected


3

ppm

Density (kg/m )

m /day

Remarks

3

m /month

50

1,416

1.04

31.2

250

1,416

5.19

155.8

Margin (%)

Iso Tanks/Month

Future (if required)

* 1month=30days

B. Total Wax Inhibitor Required 3

3

Wax Inhibitor Dosage (ppm)

m /day

m /month

50

1.14

34.3

250

5.71

171.4

1.4

10

6.9


CALCULATION SHEET

Demulsifier (CD) JOB No: JOB NAME : CLIENT :

Page

1

of


(*chemical concentration


Total Oil

Dehydrator Inlet A

100

w %)

CD injected 3


3

3

kblpd

m /day

ppm

Density (kg/m )

m /day

m /month

99

17,040

10

957

0.18

NA

50

957

0.89

NA

957

0.18

NA

Dehydrator Inlet B

99

17,040

10 50

957

0.89

NA

HP Production Separator Inlet A

93

16,032

10

957

0.17

5.0

50

957

0.84

25.1

HP Production Separator Inlet B

93

16,032

10

957

0.17

5.0

50

957

0.84

25.1

Margin (%)

Iso Tanks/Month

* 1month=30days

B. Total CD Required 3

3

CD Dosage (ppm)

m /day

m /month

10

0.76

11.1

50

3.80

55.3

10


0.4 2.2

CD Tank Capacity m

3

CD Supply Pump Capacity 3

m /hour (Normal)

CD Injection Pump Capacity

Remarks

l/d (Normal)

As required to recover from dehydrator grid shorting event 40.0

19.0

0 - 3,575 (2x100%) Continuous Injection

1

CALCULATION SHEET

Demulsifier (CD) JOB No: JOB NAME : CLIENT :

Page

1

of

1


(*chemical concentration


Total Oil

100

w %)

CD injected 3


3

3

kblpd

m /day

ppm

Density (kg/m )

m /day

m /month

99

17,040

10

957

0.18

NA

50

957

0.89

NA

957

0.18

NA

Dehydrator Inlet A

Dehydrator Inlet B

99

17,040

10 50

957

0.89

NA


93

16,032

10

957

0.17

5.0

50

957

0.84

25.1


93

16,032

10

957

0.17

5.0

50

957

0.84

25.1

Margin (%)

Iso Tanks/Month

CD Tank Capacity m

3

CD Supply Pump Capacity

CD Injection Pump Capacity

3

m /hour (Normal)

Remarks

l/d (Normal)

As required to recover from dehydrator grid shorting event 40.0

19.0

0 - 3,575 (2x100%) Continuous Injection

* 1month=30days

B. Total CD Required 3

3

CD Dosage (ppm)

m /day

m /month

10

0.76

11.1

50

3.80

55.3

0.4

10

2.2


CALCULATION SHEET

Ant ifo am (CA) JOB No: JOB NAME :


CLIENT :

MCL


(*chemical concentration : Total Oil

Test Separator Inlet A

Test Separator Inlet B



m3/day

20

3,192

93

93

3,192

16,032

16,032




3

3

ppm

Density (kg/m )

m /day

m /month

5

812

0.03

1.0

20

812

0.13

3.9

5

812

0.03

1.0

20

812

0.13

3.9

5

812

0.16

4.9

20

812

0.66

19.7

5

812

0.16

4.9

20

812

0.66

19.7

5

812

0.00

0.0

20

812

0.00

0.0

5

812

0.00

0.0

20

812

0.00

0.0

CA Tank Capacity 3

m

40.0

Continuous Injection 3

Batch Injection

3

m /month

5

0.4

13.0

20

1.6

52.1

Container with 4 L capacity of antifoam will be provided on AGRU and AGE reflux pump that required batch injection of antifoam

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Antifoam for Amine System is Glycol Base (Recommended by LICENSOR (SHELL)) 3. Total Chemical Required is including 10% Margin

Margin (%)

Iso Tanks/Month 0.5

10

CA Supply Pump Capacity 3

m /hour (Normal)

CA Injection Pump Capacity

Remarks

l/d (Normal)

19.0

0 - 2,000 (2x100%)


LP Separator have cycl one inlet. Injection fittings f or future antifoam injection to be provided.

B. Total CA Required

m /day

of

Assumed Each Well is tested at duration of 6 hours with a maximum flowrate of 40 kbpd. Continous injection

* 1month=30days

CA Dosage (ppm)

1

w %)

CA injected

kblpd

20

60

Page

2.1

1

CALCULATION SHEET

Ant ifo am (CA) JOB No: JOB NAME :


CLIENT :

MCL


(*chemical concentration : Total Oil

Test Separator Inlet A

Test Separator Inlet B



m3/day

20

3,192

3,192

93

16,032

93

16,032



1

of

1

w %)

CA injected

kblpd

20

60

Page


3

CA Tank Capacity

3

ppm

Density (kg/m )

m /day

m /month

5

812

0.03

1.0

20

812

0.13

3.9

5

812

0.03

1.0

20

812

0.13

3.9

5

812

0.16

4.9

20

812

0.66

19.7

5

812

0.16

4.9

20

812

0.66

19.7

5

812

0.00

0.0

20

812

0.00

0.0

5

812

0.00

0.0

20

812

0.00

0.0

3

CA Supply Pump Capacity 3

m

m /hour (Normal)

CA Injection Pump Capacity

Remarks

l/d (Normal) Assumed Each Well is tested at duration of 6 hours with a maximum flowrate of 40 kbpd. Continous injection

40.0

19.0

0 - 2,000 (2x100%)


LP Separator have cycl one inlet. Injection fittings f or future antifoam injection to be provided.

* 1month=30days

B. Total CA Required CA Dosage (ppm)

Continuous Injection 3

Batch Injection

Margin (%)

3

m /day

m /month

5

0.4

13.0

20

1.6

52.1

Iso Tanks/Month 0.5

Container with 4 L capacity of antifoam will be provided on AGRU and AGE reflux pump that required batch injection of antifoam

10

2.1

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Antifoam for Amine System is Glycol Base (Recommended by LICENSOR (SHELL)) 3. Total Chemical Required is including 10% Margin

CALCULATION SHEET

H2S Scavenger (CS) JOB No: JOB NAME :


CLIENT :

MCL


(*ch em ic al co nc en tr ati on :

30

Total Fluid 3

Crude Oil Booster Pump Suction

194

Crude Oil Stripper Cooler A

92

15,960

Crude Oil Stripper Cooler B

92


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

30,912

2

1,033

0.20

NA

100

1,033

9.97

NA

2

1,033

0.10

NA

100

1,033

5.15

NA

2

1,033

0.10

NA

100

1,033

5.15

NA

15,960

* 1month=30days

B. Total CS Required 3

3

CS Dosage (ppm)

m /day

m /month

2

0.4

NA

100

18.4

NA

Margin (%)

Remarks

10

All three pumps running, considering worst case that chemical is injected into crude oil booster pump suction and stripper cooler A/B outlet

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Using Maximum Concentration, chemical will be injected at one point only 3. Total Chemical Required is including 10% Margin

1

of

w %) CS injected

kblpd (actual flow)

Page

CS Tank Capacity 3

CS Supply Pump Capacity 3

CS Injection Pump Capacity

m

m /hour (Normal)

l/d (Normal)

40.0

19.0

0 - 12,000 (3x50%)

Remarks

As required for off-spec oil

1

CALCULATION SHEET

H2S Scavenger (CS) JOB No: JOB NAME :


CLIENT :

MCL


(*ch em ic al co nc en tr ati on :

30

CS injected


3

kblpd (actual flow)

m /day

ppm

Density (kg/m )

m /day

m /month

194

30,912

2

1,033

0.20

NA

100

1,033

9.97

NA

Crude Oil Stripper Cooler A

92

15,960

2

1,033

0.10

NA

100

1,033

5.15

NA

2

1,033

0.10

NA

100

1,033

5.15

NA

92

15,960

CS Tank Capacity

3

Crude Oil Booster Pump Suction

Crude Oil Stripper Cooler B

1

of

1

w %)

Total Fluid 3

Page

3



m

m /hour (Normal)

l/d (Normal)

40.0

19.0

0 - 12,000 (3x50%)

Remarks

As required for off-spec oil

* 1month=30days


3

CS Dosage (ppm)

m /day

m /month

2

0.4

NA

100

18.4

NA

Margin (%)

Remarks

10

All three pumps running, considering worst case that chemical is injected into crude oil booster pump suction and stripper cooler A/B outlet

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Using Maximum Concentration, chemical will be injected at one point only 3. Total Chemical Required is including 10% Margin

CALCULATION SHEET

O2 Scavenger (CS) JOB No: JOB NAME :


CLIENT :

MCL

A. Injection Point

(*c hem ic al c on cen trat io n :

30

Total Fluid


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

Water Deaerator A

23,892

2

1,380

0.12

3.5

Water Deaerator B

23,892

2

1,380

0.12

3.5

5,280

2

1,380

0.03

0.8

Waste Water Treatment Unit

* Total Fluid is based on equipment design capacity.

* 1month=30days


3

CS Dosage (ppm)

m /day

m /month

2

0.28

8.46

Margin (%) 10


1

of

w %)

CS injected 3

kbwpd

Page

Tote Tanks/Month 4.2

CS Tank Capacity m

3

10.0


m /hour (Normal)

19.0


Remarks

l/d (Normal)

0 - 300 (3x50%)

Continuous as required * According to water deaerator vendor's information, 2kg of oxygen scavenger is required to reduce oxygen level of each water deaerator from 50ppb t o 20ppb.

1

CALCULATION SHEET

O2 Scavenger (CS) JOB No: JOB NAME :


CLIENT :

MCL

(*c hem ic al c on cen trat io n :

A. Injection Point

30

Total Fluid

CS Tank Capacity


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

Water Deaerator A

23,892

2

1,380

0.12

3.5

Water Deaerator B

23,892

2

1,380

0.12

3.5

5,280

2

1,380

0.03

0.8


1

of

1

w %)

CS injected 3

kbwpd

Page

m

CS Supply Pump Capacity

3

3

m /hour (Normal)

10.0


0 - 300 (3x50%)

19.0

Remarks

l/d (Normal) Continuous as required * According to water deaerator vendor's information, 2kg of oxygen scavenger is required to reduce oxygen level of each water deaerator from 50ppb t o 20ppb.

* Total Fluid is based on equipment design capacity.

* 1month=30days


3

CS Dosage (ppm)

m /day

m /month

2

0.28

8.46

Tote Tanks/Month

Margin (%)

4.2

10


CALCULATION SHEET

Biocide/Hypochlorite (CH) JOB No: JOB NAME : CLIENT :

Page

1

of


A. Injection Point

(*chemical concentration :

0.8

Total Water 3

m /h

w %)

CH injected

3

m /day

ppm


Density (kg/m )

L/hr

3

m /day

3

m /month

CH Tank Capacity 3

m

CH Supply Pump Capacity 3

m /hour (Normal)

CH Injection Pump Capacity

Remarks

l/d (Normal)

Sewage Treatment Unit

Intermittent Injection

Potable Water Tank Inlet

10.0

Basin Water Intake

2,200.0

Media Filter Sump

2,040.0

Water Deaerator Inlet

1,810.0


200.0

Diesel Fuel Inlet Filter

240

52,800

48,960

43,440

1,406

0.6

0.014

1,072

0.6

0.014

0.4

1

1,072

275

6.600

198.0

2

1,072

550

13.200

396.0

1

1,072

255

6.120

183.6

1

1,072

255

6.120

183.6

1

1,072

0.000

0.0

1

1,072

0.000

0.0

2

1,072

1,072

960

2.0

LP Degassing Vessel Inlet

1,072

0.5

4,800

40.0

Discharge of Recycle Pumps

0.5

1,072 2

1,072

2

1,072

1

48

33,750

Riverwater Lift Pumps

3

3

m /day

m /month

18.34

550.15

2

28.95

955.20

0.000

0.0

0.240

7.2

0.000

0.0 0.4

3.937

118.1

2

1,072

7.873

236.2

1

1,072

0.000

0.0

2

1,072

0.286

8.6

Remarks

Margin (%)

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Total Chemical Required is including 10% Margin 3

0.0 36.0

1,072

10

3. Generator sized for 24 m /day with 0.8% concentration 4. Biocide for Sewage Treatment Unit to be provided as a tablet feeder(capa : 60days feeding).

1

0.000 1.200

0.012

B. Total CH Required

0.5

10

1,072

* 1month=30days

CH Dosage (ppm)

50

0.4



Continuous Injection to be to be confirmed by confirmed by vendor vendor

24,000.0

Intermittent Injection (Provision)





Via tote tank

N/A

N/A


1

CALCULATION SHEET

Biocide/Hypochlorite (CH) JOB No: JOB NAME : CLIENT :

Page

1

of

1


A. Injection Point


0.8

Total Water 3

m /h

w %)

CH injected

3

m /day

3

ppm

CH Tank Capacity

Total Chemical Injected L/hr

Density (kg/m )

3

m /day

3

CH Supply Pump Capacity

3

m /month

3

m

m /hour (Normal)

CH Injection Pump Capacity

Remarks

l/d (Normal)

Sewage Treatment Unit


Potable Water Tank Inlet

10.0

Basin Water Intake

2,200.0

Media Filter Sump

2,040.0

Water Deaerator Inlet

1,810.0


200.0

240

52,800

48,960

43,440

0.5

1,072

0.6

0.014

0.5

1,072

0.6

0.014

0.4

1

1,072

275

6.600

198.0

2

1,072

550

13.200

396.0

1

1,072

255

6.120

183.6

1

1,072

255

6.120

183.6

1

1,072

0.000

0.0

1

1,072

0.000

0.0

2

1,072

4,800

Diesel Fuel Inlet Filter

40.0

960

Discharge of Recycle Pumps

2.0

48

1,406

33,750

1,072

1,072 2

LP Degassing Vessel Inlet

Riverwater Lift Pumps

50

1,072

10

1,072 1

0.4



Continuous Injection to be to be confirmed by confirmed by vendor vendor

0.000

0.0

1.200

36.0

0.000

0.0

0.240

7.2

0.000

0.0

24,000.0

Intermittent Injection (Provision)




2

1,072

0.012

0.4

1

1,072

3.937

118.1

2

1,072

7.873

236.2

1

1,072

0.000

0.0

2

1,072

0.286

8.6

Remarks

Margin (%)


Via tote tank

N/A

N/A


* 1month=30days

B. Total CH Required 3

3

CH Dosage (ppm)

m /day

m /month

0.5

18.34

550.15

2

28.95

955.20

10

Note: 1. Actual injected concentration may change upon chemical supplier selection 2. Total Chemical Required is including 10% Margin 3

3. Generator sized for 24 m /day with 0.8% concentration 4. Biocide for Sewage Treatment Unit to be provided as a tablet feeder(capa : 60days feeding).

CALCULATION SHEET Polyelectrolite (CE) JOB No: JOB NAME : CLIENT :

Page

1



A. Injection Point

Total Water kbwpd Raw Water Clarifier

3

30

w %)

CE injected


3

ppm

Density (kg/m )

m /day

m /month

48,000

0.5

1,140

0.0702

2.1053

Margin (%)

Tote Tanks/Month

* 1month=30days

B. Total CE Required 3

3

m /day

3

CE Dosage (ppm)

m /day

m /month

0.5

0.08

2.32

10


1.2

CE Tank Capacity m

3

5.0

CE Supply Pump CE Injection Capacity Pump Capacity 3

m /hour (Normal)

l/d (Normal)

19.0

0 - 150 (2x100%)

Remarks


of

1

CALCULATION SHEET Polyelectrolite (CE) JOB No: JOB NAME : CLIENT :

Page

1

of

1



A. Injection Point


3

30

w %)

CE injected


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

48,000

0.5

1,140

0.0702

2.1053

Margin (%)

Tote Tanks/Month

CE Tank Capacity m

3

CE Supply Pump CE Injection Capacity Pump Capacity 3

m /hour (Normal)

l/d (Normal)

19.0

0 - 150 (2x100%)

5.0

Remarks


* 1month=30days

B. Total CE Required 3

3

CE Dosage (ppm)

m /day

m /month

0.5

0.08

2.32

1.2

10


CALCULATION SHEET

Clarifier (CW) JOB No: JOB NAME :


CLIENT :

MCL


A. Injection Point


30

1

w %)

CW injected 3

Page


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

48,000

12

1,160

1.7

51.3

CW Tank Capacity 3

m

CW Supply Pump Capacity 3

m /hour (Normal)

CW Injection Pump Capacity

Remarks

l/d (Normal) Continuous Injection

Hydrocyclone Inlet A

103

16,450

5

1,032

0.080

2.5

15

1,032

0.24

7.4

5

1,032

0.080

2.5

15

1,032

0.24

7.4

Margin (%)

Remarks

Iso Tanks/Month

10

CW Injected to the Hydrocyclone is provision only

2.3

14.0

19.0

0 - 2000 (2x100%) Provision

Hydrocyclone Inlet B

103

16,450

* 1month=30days

B. Total CW Required 3

3

CW Dosage (ppm)

m /day

m /month

12

1.82

56.4


0

of

1

CALCULATION SHEET

Clarifier (CW) JOB No: JOB NAME :


CLIENT :

MCL


A. Injection Point

Total Water

Raw Water Clarifier

1

of

1

w %)

CW injected 3

kbwpd

30

Page

CW Tank Capacity


3

3

m /day

ppm

Density (kg/m )

m /day

m /month

48,000

12

1,160

1.7

51.3

16,450

5

1,032

0.080

2.5

15

1,032

0.24

7.4

5

1,032

0.080

2.5

15

1,032

0.24

7.4

Margin (%)

Remarks

Iso Tanks/Month

10

CW Injected to the Hydrocyclone is provision only

2.3

CW Supply Pump Capacity

3

CW Injection Pump Capacity

3

m

m /hour (Normal)

Remarks

l/d (Normal) Continuous Injection

Hydrocyclone Inlet A

103

14.0

0 - 2000 (2x100%)

19.0

Provision Hydrocyclone Inlet B

103

16,450

* 1month=30days

B. Total CW Required 3

3

CW Dosage (ppm)

m /day

m /month

12

1.82

56.4

0


CALCULATION SHEET

Methanol (CM) JOB No: JOB NAME :


CLIENT :

MCL

A. Gas Injection Line

( *c he mi ca l c on ce nt ra ti on : Total Gas

CM injected

MSCFD

ppm

1 00

3

m /day

m /month

Gas Injection to wellpad A

20 (Note 3)

3.606

NA

Gas Injection to wellpad C

20 (Note 3)

3.606

NA

Maximum Capacity of AGRU

39 (Note 4)

7.031

NA

* 1month=30days

B. Total CM Required CM Dosage (ppm)

3

3

m /day

m /month

3.61

NA

7.03

NA

Margin (%)

Note: 1. Actual injected concentration may change upon chemical supplier selection 6

2. MSCFD = 10 SCFD 3. Max. Start-up rate requiring Methanol 4. Design Case of AGRU

1

w %)


Page

CM Tank Capacity m

3

3

CM Supply Pump Capacity


3

m (Recommended)

m /hour (Normal)

m /hour (Normal) (Recommended)

l/d (Normal)

l/d (Normal) (Recommended)

2.0

10.0

0.2

0 - 7,500 (2x100%)

0 - 3,600 (2x100%)

3

Remarks

Batch as Required 10.0

Batch as Required Batch as Required

of

1

CALCULATION SHEET

Methanol (CM) JOB No: JOB NAME : CLIENT :

Page

1

of

1


A. Gas Injection Line

( *c he mi ca l c on ce nt ra ti on : Total Gas

CM injected

MSCFD

ppm

1 00

w %)


3

m /day

m /month

Gas Injection to wellpad A

20 (Note 3)

3.606

NA

Gas Injection to wellpad C

20 (Note 3)

3.606

NA

Maximum Capacity of AGRU

39 (Note 4)

7.031

NA

CM Tank Capacity m

3


3


3

m (Recommended)

m /hour (Normal)

m /hour (Normal) (Recommended)

l/d (Normal)

l/d (Normal) (Recommended)

2.0

10.0

0.2

0 - 7,500 (2x100%)

0 - 3,600 (2x100%)

3

Remarks

Batch as Required 10.0

Batch as Required Batch as Required

* 1month=30days

B. Total CM Required 3

CM Dosage (ppm)

3

m /day

m /month

3.61

NA

7.03

NA

Margin (%)

Note: 1. Actual injected concentration may change upon chemical supplier selection 6

2. MSCFD = 10 SCFD 3. Max. Start-up rate requiring Methanol 4. Design Case of AGRU

CALCULATION SHEET

Morpholine (CM) JOB No: JOB NAME : CLIENT :

Page

1

of


A. BFW Line


Total Water

BFW pump suction

3

CM injected

30

w %)

Total Chemical Injected

3

3

3

m /h

m /day

ppm

m /day

145.0

3,480

0.15

0.0017

0.1

45

0.5220

15.7

m /month

CM Tank Capacity 3

CM Supply Pump CM Injection Capacity Pump Capacity 3

m

m /hour (Normal)

l/d (Normal)

2.0

-

100.0

Remarks

Continuous Injection Dosage 0.15 ppm for pH 8 / 45ppm for pH 9.5

* 1month=30days

C. Wellpad A Gas Injection Blowdown Header Total Gas MSCFD e pa Header

as n e c on

ow own

CM injected


ppm

m3/day

m3/month

1

0.000

0.0

10

0.000

0.0

Remarks

Batch Injection

D. Wellpad C Gas Injection Blowdown Header Total Gas

CM injected


Remarks

C. Total CM Required CM Dosage (ppm)

3

m /day

3

m /month

0.15

0.002

0.06

45

0.574

17.23

Margin (%) 10

Tote Tanks/Month

0.0 8.6

=> Recommended monthly con sumption is 100 liter/day x 30 days x 1.2=3600 liter (2 tote tanks). It's based on p ump capacity.


Batch Injection

1

CALCULATION SHEET

Morpholine (CM) JOB No: JOB NAME : CLIENT :

Page

1

of


A. BFW Line


Total Water

BFW pump suction

30

3

w %)

CM Tank Capacity


CM injected

3

3

m /h

m /day

ppm

m /day

m /month

145.0

3,480

0.15

0.0017

0.1

45

3

0.5220

3

CM Supply Pump CM Injection Capacity Pump Capacity 3

m

m /hour (Normal)

l/d (Normal)

2.0

-

100.0

15.7

Remarks

Continuous Injection Dosage 0.15 ppm for pH 8 / 45ppm for pH 9.5

* 1month=30days

C. Wellpad A Gas Injection Blowdown Header Total Gas e pa Header

as n e c on


CM injected

MSCFD

Remarks

ppm

m3/day

m3/month

1

0.000

0.0

10

0.000

0.0

ow own

Batch Injection

D. Wellpad C Gas Injection Blowdown Header Total Gas


CM injected

Remarks

C. Total CM Required CM Dosage (ppm)

3

m /day

3

Margin (%)

m /month

0.15

0.002

0.06

45

0.574

17.23

Batch Injection

Tote Tanks/Month

0.0

10

8.6

=> Recommended monthly con sumption is 100 liter/day x 30 days x 1.2=3600 liter (2 tote tanks). It's based on p ump capacity.


CALCULATION SHEET

Chemicals for Package Vendor - 1 JOB No: JOB NAME : CLIENT :

Page

1

of

1


Water package Vendor's inform ation

Condensate Polishing Unit

Dosage at 100% w

Total water flowrate at injection point

Injection Rate during chemical injection

Injection pump capacity

duration

Injection Frequency

Consumpti on per one injection Monthly (package frequency vendor's information ) liter

Monthly Consumption (1 month = 30 days)

ppm

m3/hr

l/hr

l/hr

l/day

min

H2SO4 (98%)

Regeneration

40000

18

420

500

12,000

25

NaOH (30%)

Regeneration

40000

10.8

1265

1500

36,000

25

H2SO4 (98%)

Regeneration

40000

8.6

200

500

12,000

25

Once per day

84

30

2520

once a 8.3 day once a 8.3 day

liter/month

175

4

700

527

4

2108

BFW treatment Unit

RO units

NaOH (30%)

Regeneration

40000

7.7

900

1500

36,000

25

Once per day

376

30

11280

H2SO4 (98%)

ph Control

24

108

1.5

5

120

-

continuous

-

-

1080

H2SO4 (98%)

UF cleaning

1470

58

48

100

2,400

0.83

8 times a day

1.4

240

336

NaOH (30%)

UF cleaning

1200

58

175

220

5,280

0.83

8 times a day

2.4

240

576

UF cleaning

10

58

29

150

3,600

0.83

8 times a day

0.4

240

RO operation

5

108

5.4

10

240

-

continuous

-

-

NaOCl (2%) Ant isc alant (*)(10%) SMBS (30%)

Potable Water Dosing Unit

96 3888

RO operation

5

108

1.8

5

240

-

continuous

-

-

1296

CaCl2(5%)

Service

100

10

20

50

1,200

-

continuous

-

-

14400

NaHCO3(5%)

Service

100

10

20

50

1,200

-

continuous

-

-

14400

* Antiscalant is same chemical with scale inhibitor for hydrocyclone. / concentration to be confirmed later * For NaOH, allowable maximum concentration is 30% due to viscosity and freezing point (solidification).

Normal consumption Total chemical consumption for water packages

Consumption with 20% margin

H2SO4 98%

4,636

liter/month

5,563

liter/month

Note 1

NaOH 30%

13,964

liter/month

16,757

liter/month

Note 2

NaOCl 2%

96

liter/month

115

liter/month

Anti scal ant 10%

3,888

li ter/mo nth

4,666

lit er/mon th

SMBS 30%

1,296

liter/month

1,555

liter/month

CaCl2 5%

14,400

liter/month

17,280

liter/month

NaHCO3 5%

14,400

liter/month

17,280

liter/month

Note 1. 7.2 m3 of H2SO4 98% with 20% margin would be appli ed to consu mption for Neutralization Pi t. Total consumption of H2SO4 98% would be 12.8 m3/month. 2. 1 m3 of NaOH 30% would be applied to consumption for Neutralization Pit. Total consumption of NaOH 30% would be 18 m3/month. 3. Mixing facility for powder chemicals such as SMBS, CaCl2 and NaHCO3 shall be supplied.

1

CALCULATION SHEET


Page

1

of

1


Water package Vendor's inform ation

Condensate Polishing Unit

Dosage at 100% w

Total water flowrate at injection point

Injection Rate during chemical injection

Injection pump capacity

duration

Injection Frequency

Consumpti on per one injection Monthly (package frequency vendor's information ) liter

Monthly Consumption (1 month = 30 days)

ppm

m3/hr

l/hr

l/hr

l/day

min

H2SO4 (98%)

Regeneration

40000

18

420

500

12,000

25

NaOH (30%)

Regeneration

40000

10.8

1265

1500

36,000

25

H2SO4 (98%)

Regeneration

40000

8.6

200

500

12,000

25

Once per day

84

30

2520

once a 8.3 day once a 8.3 day

liter/month

175

4

700

527

4

2108

BFW treatment Unit NaOH (30%)

Regeneration

40000

7.7

900

1500

36,000

25

Once per day

376

30

11280

H2SO4 (98%)

ph Control

24

108

1.5

5

120

-

continuous

-

-

1080

H2SO4 (98%)

UF cleaning

1470

58

48

100

2,400

0.83

8 times a day

1.4

240

336

NaOH (30%)

UF cleaning

1200

58

175

220

5,280

0.83

8 times a day

2.4

240

576

UF cleaning

10

58

29

150

3,600

0.83

8 times a day

0.4

240

RO operation

5

108

5.4

10

240

-

continuous

-

-

RO units

NaOCl (2%) Ant isc alant (*)(10%) SMBS (30%)

Potable Water Dosing Unit

96 3888

RO operation

5

108

1.8

5

240

-

continuous

-

-

1296

CaCl2(5%)

Service

100

10

20

50

1,200

-

continuous

-

-

14400

NaHCO3(5%)

Service

100

10

20

50

1,200

-

continuous

-

-

14400

* Antiscalant is same chemical with scale inhibitor for hydrocyclone. / concentration to be confirmed later * For NaOH, allowable maximum concentration is 30% due to viscosity and freezing point (solidification).

Normal consumption Total chemical consumption for water packages

Consumption with 20% margin

H2SO4 98%

4,636

liter/month

5,563

liter/month

Note 1

NaOH 30%

13,964

liter/month

16,757

liter/month

Note 2

NaOCl 2%

96

liter/month

115

liter/month

Anti scal ant 10%

3,888

li ter/mo nth

4,666

lit er/mon th

SMBS 30%

1,296

liter/month

1,555

liter/month

CaCl2 5%

14,400

liter/month

17,280

liter/month

NaHCO3 5%

14,400

liter/month

17,280

liter/month

Note 1. 7.2 m3 of H2SO4 98% with 20% margin would be appli ed to consu mption for Neutralization Pi t. Total consumption of H2SO4 98% would be 12.8 m3/month. 2. 1 m3 of NaOH 30% would be applied to consumption for Neutralization Pit. Total consumption of NaOH 30% would be 18 m3/month. 3. Mixing facility for powder chemicals such as SMBS, CaCl2 and NaHCO3 shall be supplied.

CALCULATION SHEET


Page


1. Phosphate Consumption for HRSGs Na3PO4·12H2O Molecular weight Normal Steam Production

380 g/mol 120 ton/hr (for 4 or 5 HRSGs)

Maximum Steam Production

140 ton/hr

Phosphate solution concentration :

1 %

S.G. : 1

1.1 Normal Dosing rate for total HRSGs : PO4 maintenance x (Na3PO4·12H2O/PO4) x normal blowdown rate =

0.06 ppm

- Normal Daily consumption : Dosing rate x normal steam production rate =

172.9 g/day

Normal Daily consumption of phosphate solution of

1 % concentration

=> Consumption of liter/month (30days) => Consumption of liter/hr - Chemical Day tank capacity per each HRSG

17.3 liter / day 518.7 liter / month 0.7 liter / hr 1.0 m3

if tank capacity is converted to operating days

: in case of 5 HRSGs operation

11.6 days


14.5 d ays

2. Phosphate Consumption for Package Boiler

Na3PO4·12H2O Molecular weight

380 g/mol

Normal Steam Production

50 ton/hr


50 ton/hr


1 %

S.G. : 1

2.1 Normal Dosing rate : PO4 maintenance x (Na3PO4·12H2O/PO4) x normal blowdown rate =

0.03

- Normal Daily consumption : Dosing rate x normal steam production rate = Normal Daily consumption of phosphate solution of

1 % concentration

=> Consumption of liter/month (30days)

3.6 liter / day 108.1 liter / month

=> Consumption of liter/hr

0.2 liter / hr

- Chemical Day Tank capacity :

1


=> To tal Co ns um pt io n w it h 20% m ar gi n

ppm

36.0 g/day

752 l it er / m on th

277.6

(1 To te t an k)

m3 days

1

of

1

CALCULATION SHEET


Page

1

of

1


1. Phosphate Consumption for HRSGs Na3PO4·12H2O Molecular weight Normal Steam Production

380 g/mol 120 ton/hr (for 4 or 5 HRSGs)


140 ton/hr


1 %

S.G. : 1

1.1 Normal Dosing rate for total HRSGs : PO4 maintenance x (Na3PO4·12H2O/PO4) x normal blowdown rate =

0.06 ppm

- Normal Daily consumption : Dosing rate x normal steam production rate =

172.9 g/day

Normal Daily consumption of phosphate solution of

1 % concentration

=> Consumption of liter/month (30days) => Consumption of liter/hr - Chemical Day tank capacity per each HRSG

17.3 liter / day 518.7 liter / month 0.7 liter / hr 1.0 m3



11.6 days


14.5 d ays

2. Phosphate Consumption for Package Boiler

Na3PO4·12H2O Molecular weight

380 g/mol

Normal Steam Production

50 ton/hr


50 ton/hr


1 %

S.G. : 1

2.1 Normal Dosing rate : PO4 maintenance x (Na3PO4·12H2O/PO4) x normal blowdown rate =

0.03

- Normal Daily consumption : Dosing rate x normal steam production rate = Normal Daily consumption of phosphate solution of

1 % concentration

=> Consumption of liter/month (30days)

3.6 liter / day 108.1 liter / month

=> Consumption of liter/hr

0.2 liter / hr

- Chemical Day Tank capacity :

1


=> To tal Co ns um pt io n w it h 20% m ar gi n

ppm

36.0 g/day

277.6

752 l it er / m on th

m3 days

(1 To te t an k)


BANYU URIP PROJECT


02 Nov 12 Rev 2

MPI: Not Classified

Appendix - 2

APPENDIX


BANYU URIP PROJECT


02 Nov 12 Rev 2

MPI: Not Classified

Appendix - 2 SIMPLIFIED PFD


APPENDIX


BANYU URIP PROJECT


02 Nov 12 Rev 2

MPI: Not Classified

Appendix – 3

APPENDIX


BANYU URIP PROJECT


02 Nov 12 Rev 2

MPI: Not Classified

APPENDIX

Appendix – 3 WELL AND WELL-PAD DESIGN RATES – TABLE 10-3 FACILITIES DESIGN BASIS


IDBU-ED-BBPDB-000002

BANYU URIP PROJECT

Facilities Design Basis (FDB)

04 May 2011 Rev 3

MPI: Not Classified

Page 87 of 318

TABL E 10 - 3: BANYU-URIP FACILITY, WELL AND WELLPAD DESIGN RATES BU FACILITY, WELL, & WELLPAD DESIGN RATES Instantaneous Maximu m Peak Design Rates

Overall Facility Design

Carbonate Production Wells

30

Well & Wellpad Info

No. Production Wells & Max Instantaneo us rate/well (kblpd, Mscfd)

Clastic Production Wells

3

(4)

No. Production Wells & Max Instantaneous rate/well (kblpd, Mscfd)

(4)

Water Injection Wells

Gas Injection Wells

13

2

No. Water Injection Wells & Max rate/well (kbwpd)

No. Gas Injection Wells & Max rate/well (Mscfd)

4

1

(28)

(51)

Wellpad A

(20,26)

Wellpad B

10

1

5

(20,17)

(2 , 7)

(28)

10

1

4

1

(20,27)

(3, 5)

(28)

(45)

Wellpad C

10

2

(3 , 16)

0

Total Mscfd - Preliminary Tentativ Possible Total Gas Lift Total Oil (Production flowline e Future Liquids Supply kbopd & returned lift distance Flowline Wells kblpd Mscfd gas) (m) size

1

185

300

124

-

-

75

Production Flowl ines between Wellpads and CPF

Possible Future Total Mscfd Preliminary Wells Total Oil Total (Production Flowlin Liquids flowline kbopd & returned e size 3 kblpd distance (m) gas lift)

Water Injection Supply

Preliminary Water Injection Line Size

kbwpd

365

(1, 2)

-

Wtr Injection Lines G/L Lines Mscfd

(5)

kbwpd

Preliminary Water Injection Line Size

1

68

93

65

700

16"

20

112

14"

0

94

116

50

700

2x 14"

20

140

14"

0

75

96

50

2000

20"

20

112

14"

Notes: 1. The 4th or spare injection pump and facility can be used for downtime makeup to 440 kbwpd if needed. 2. Maximum water injection rate is 28 kbwpd per well. 3. Tentative flowline sizes to be confirmed during flow assurance simulations. 4. Existing BU-A2 well at Wellpad A was formerly earmarked as a fourth Clastic Producer but is now a "Future Use" well. 5. Water injection lines to be sized for maximum water injection capacity on wellpad. 6. Predicted peak rates were from reservoir simulation results, which are subject to uncertainty and future adjustment. They were intended to be used as guideline for facility design basis. Consult with Subsurface group when considering revise / optimize facility design based on the numbers shown in the table.

IDBU-ED-BBPDB-000002 Rev 3.doc


BANYU URIP PROJECT


02 Nov 12 Rev 2

MPI: Not Classified

APPENDIX

Appendix – 4 HEAT AND MASS BALANCE FLOW SUMMARY BY-CASE – TABLE 10-9 FACILITIES DESIGN BASIS


TABLE 10 – 9: HEAT & MASS BALANCE FLOW SUMMARY BY CASE

Fluid

Export Oil, kSTBD at 60 o F

Annual Aver age Rate

180

Stream Day Design Rate

185

Case-1

Case-2

Case-3

Case-4

Peak Oil & Minimum Produced Water

Peak Liquid & Peak Gas Injection

Peak Liquid & Peak Gas Injection with Low H S & High 2 C 6s Year 6

Peak Produced Water & Oil/Fuel Gas Turndown

18.5

Year 6

Year 5

Year 19

185.0

185.0

185.0

182.9

185.0 182.9

0.0

2.1

2.1

0.0

0.0

30.3

31.9

54.6

• From Carbonate Wells, kSTBD at 60 oF(1) • From Clastic Wells, kSTBD at 60 oF(1) • From Non-Solution Gas through Oil Producing Wells, Mscfd (1)

18.5

Total Liquid, kBPD

292

300

200.5

285.6

285.6

218.5

Produced Water, kBWPD

195

200

15.5

100.6

100.6

200.1

Fresh Water Injection kBWPD

254

260

204.9

210.8

210.8

102.5

Total Water Injection kBWPD

356

365

220.4

311.4

311.4

302.6

Gas Lift to wells, Mscfd

73

75

4.7

19.3

19.3

61.3

Gas Lift Compressor Suction, Mscfd

94

96(2)

50.8

96.5

97.1

105.5

Gas Injection to wells, Mscfd

73

75(2)

44.7

75.0

75.0

42.4

AGRU Inlet, Mscfd

29

30(3)

30.0

30.0

30.0

20.0

Sulfur Production, TPD

20

20.5(3)

18.2

18.0

12.5

11.5

-

30

0

0

0

0

Gas Flow back from Gas Injection Wells, Mscfd (1) Notes:

(1) Use compositions in Table 10-4. (2) Gas Lift and Gas Injection Compressors are sized with a 20% margin to improve facility availability and to handle swings in fuel gas demand with minimal flaring.

(3) Gas treatment and sulfur recovery systems are sized to handle: a. Peak fuel gas demand at 60 MW power generation and maximum HRSG steam generation b. Minimum 1.1% and maximum 1.8% H2S content in AGRU inlet c. Minimum fuel gas demand during black starts

CI-MHJK-TSJK-00002 Rev 0(110812).doc

Page 5 of 5


BANYU URIP PROJECT


02 Nov 12 Rev 2

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APPENDIX

Appendix – 5 WELL FLUID COMPOSITION TABLE 8-1 ~ TABLE 8-2 – AND TABLE 10-4 ~ TABLE 10-6 FACILITIES DESIGN BASIS


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IDBU-ED-BBPDB-000002 Facilities Design Basis (FDB)

MPI: Not Classified

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10.7.2. Well Fluid Composit ion Tables 10-4 and 10-5 below provide the produced hydrocarbon well fluid composition on a dry basis without gas lift to be used in the design of the CFF. Actual fluid properties may vary. Some variance should be anticipated and considered in the final detailed design.

TABL E 10 - 4: WELL FLUID COMPOSITION ON A DRY BASIS Carbonate Producers

Clastic Producers

Mole %

Mole %

Mole %

Hydrogen Sulfide

0.8496%

0.3598%

1.6469%

Methyl-Mercaptan Carbonyl Sulphide Carbon Dioxide Water Nitrogen Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane C6* Methyl- Cyclopentane Benzene Cyclohexane C7* Methyl- Cyclohexane Toluene C8* Ethyl-Benzene meta+para-Xylene ortho-Xylene C9* 1,2,4-Trimethylbenzene C10* C11+ Frac 1* C11+ Frac 2* C11+ Frac 3* C11+ Frac 4* C11+ Frac 5* C11+ Frac 6* C11+ Frac 7* C11+ Frac 8* C11+ Frac 9* C11+ Frac10*

0.0355% 0.0068% 21.4209% 0.0000% 0.0800% 21.1710% 1.6393% 0.8996% 0.2499% 0.4098% 0.2299% 0.2199% 0.0700% 0.0200% 0.2499% 0.0700% 0.6497% 0.5198% 1.0795% 0.7697% 0.1100% 0.6997% 0.3698% 1.2695% 0.5698% 1.5793% 2.6889% 5.6376% 7.1270% 7.4968% 6.8971% 5.7776% 4.1582% 2.6089% 1.4094% 0.9596%

0.0355% 0.0068% 18.2823% 0.0000% 0.2899% 22.2206% 1.4894% 0.7397% 0.2099% 0.3598% 0.2399% 0.2299% 0.0800% 0.0200% 0.2699% 0.0600% 0.7297% 0.6097% 1.2695% 0.8197% 0.1299% 0.7797% 0.4098% 1.4494% 0.6297% 1.8392% 2.7888% 5.8475% 7.3969% 7.7767% 7.1570% 5.9875% 4.3182% 2.7089% 1.4594% 0.9996%

0.0862% 0.0138% 43.6731% 0.0125% 0.1943% 46.0152% 3.3252% 1.8782% 0.5504% 0.9226% 0.5515% 0.5320% 0.1083% 0.0185% 0.1637% 0.0364% 0.1176% 0.0619% 0.0563% 0.0231% 0.0008% 0.0034% 0.0014% 0.0055% 0.0003% 0.0010% 0.0002% -

Well Fluid Dry Basis


Non-Solution Gas

(1)


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Page 89 of 318

Notes: (1) Non-Solution Gas is an assumed composition to be used for design simulations and represents a weighted average combined composition of about 15% original Clastic cap gas and 85% Case-1 injection gas.

TABL E 10 - 5: MOLECULAR WEIGHT, DENSITY AND CRITICAL PROPERTIES FOR PSEUDO COMPONENTS NBP 0 [ C]

MW

C6*

68.25

86.18

C7*

97.66

C8*

Liq Density 3 [kg/m ]

Tc [ C]

Pc [kPa]

662.5

235.8

3018.6

0.3719

0.2808

100.20

686.9

267.9

2726.6

0.4301

0.3331

124.70

114.23

705.6

296.4

2489.4

0.4878

0.3822

C9*

149.77

128.26

720.5

322.0

2291.6

0.5454

0.4288

C10*

162.58

135.60

837.4

379.9

3623.5

0.4627

0.4123

C11+ Frac 1*

179.83

148.91

827.8

395.0

3249.4

0.5208

0.4571

C11+ Frac 2*

213.37

172.97

837.1

425.5

2861.0

0.6056

0.5271

C11+ Frac 3*

251.54

203.35

846.9

458.5

2503.6

0.7078

0.6071

C11+ Frac 4*

292.02

239.39

856.5

498.7

2190.4

0.8368

0.6751

C11+ Frac 5*

334.80

281.91

865.8

536.7

1823.8

1.0328

0.7489

C11+ Frac 6*

380.27

332.00

874.8

575.8

1510.8

1.2771

0.8326

C11+ Frac 7*

429.01

390.94

883.6

616.7

1257.5

1.5648

0.9349

C11+ Frac 8*

481.35

460.25

890.9

660.0

1065.7

1.8689

1.0721

C11+ Frac 9*

537.72

541.71

896.4

683.5

778.9

2.3671

1.5007

C11+ Frac10*

598.83

637.40

900.2

725.7

582.4

3.1769

1.6781

Name

0

Vc [m /kgmole] 3

Ac entrici ty

Table 10-6 below provides an analysis of the initial formation water. With break through of the injection water and increasing water cuts, the following composition will change over time as it is diluted with injection water.



BANYU


04 May 2011 Rev 3

URIP PROJECT

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Page 90 of 318

TAB LE 10 - 6: FORMATION WATER CHEMISTRY TEST

RESULT

UNIT

METHOD

ACCURACY

1. Calcium, Ca

400.7

mg/L

AAS

0.01

2. Magnesium, Ma

43.4

mg/L

AAS

0.01

5,344.5

mg/L

AAS

0.01

456.4

mg/L

AAS

0.01

5. Barium, Ba

0.5

mg/L

AAS

0.01

6. Boron, B

84.9

mg/L

AAS

0.01

7. Lithium, Li

10.0

mg/L

AAS

0.01

8. Manganese, Mn

0.4

mg/L

AAS

0.01

9. Soluble Iron, Fe

2.1

mg/L

AAS

0.01

10. Insoluble Iron, Fe

3.4

mg/L

AAS

0.01

11. Stronium, Sr

36.7

mg/L

AAS

0.01

12. Hydroxide, OH

NI

mg/L

Titrimetric

0.1

13. Carbonate, CO 2

NI

mg/L

Titrimetric

0.01

14. Bocarbonate, HCO2

507.5

mg/L

Titrimetric

0.01

15. Sulfate, SO4

671.6

mg/L

Gravimetric

5.0

16. Chloride, CL

9,473.0

mg/L

Titrimetric

0.1

416.0

mg/L

Titrimetric

0.1

18. Nitrate, NO3

0.5

mg/L

Spectrometric

0.5

19. Silicate, SiO2

125.3

mg/L

AA.5

0.1

20. Sulfite, SO3

29.2

mg/L

Titrimetric

0.1

21. TDS (Measured)

18,282

mg/L

Gravimetric

1.0

22. TDS (Calculated)

17,185

mg/L

Calculation

-

0.37

Ohm-meter

Resistivity-meter

0.01

27,027

Umhos/cm

Conductivity-meter

1

F

Thermometer

1

3. Sodium, Na 4. Potassium, K

17. Total Alkalinity, CACO3

o

23. Resistivity @ 77 F o

24. Conductivity @ 77 F 25. Temperature

77

o

26. PH

7.95

-

PH-meter

0.05

27. Dissolved Oxygen

<0.1

mg/L

Winkler

0.1

1179.7

mg/L

AA.5

0.1

15

FTU

Spectrometric

1.0

<0.1

mg/L

Spectrometric

0.1

1.0116

-

Hydrometer

-

0.3

mg/L

AA.5

0.002

28. Total Hardness, CaCO 3 29. Turbidity 30. Oil Content o

31. Specific Gravity @ 77 F 32. Dissolved Mercury, Hg


Idbc-ts-przzz-c00004 Rev 2 Chemical System Study

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