1

Introduction

Background of studyFour oil producer wells will be drilled in Berlian East field. Few procedures are designed to cover the well completion operations for the Berlian East oil producers wells with maximum inclination of 90 degree.

Well objectivesTo complete the well safely without harm to personnel, no damage to the asset & environment.To complete the oil producer wells in M2/3, M7/8, M9/14 zones.

-Primary objective: to provide drainage points for each zonesTo install fit to purpose completion equipment & techniques to prolong well design life.To achieve an initial anticipated rate as per below for each wells.Well A01=3200 stb/dWell A07=2500 stb/dWell A08=2300 stb/dWell A11=1900 stb/d

2

P-TECHSTUDY

P-TECHSTUDY

Nodal Analysis

Nodal Analysis

Artificial LiftRequirement

Artificial LiftRequirement

MaterialDesign

MaterialDesign

CompletionDesign

CompletionDesign

SCOPE OF STUDY/DELIVERABLES

Sand ControlRequirement

Sand ControlRequirement

3

4 wells

1. To develop 3 prospective reservoirs:

2. -M2/3, M7/8 and M9/14

3. Deviated well, max angle 90°

4. 9 5/8” casing set just above M2/3 sand

5. 7” liner set across pay zones

6. Target Rate:

WELL COMPLETION OBJECTIVE

L-sand

Basement

M2/3

M7/8

M9/14

Well A1 Well A7 Well A8 Well A11

Target rate (stb/day) 3200 2500 2300 1900

LayersM2/3 &

M7/8 M7/8 M7/8 M9/14

NODAL ANALYSIS

Well A01 Performance Model Well A07 Performance Model Well A08 Performance Model

Well A11 Performance Model

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A01 Well Performance Model

Reservoir dataPressure: 1800 psiaTemperature: 215 FNet sand: 22 m (M2/3 & M7/8)Porosity: 26% (average)Permeability: 700 mD FTHP: 450 psia

Fluid parametersAPI: 41.4Rsi: 1400 scf/stbGOR: 1400 scf/stbWC: 0%

Sensitivity analysisGOR: 1400,1600,1800 scf/stbTubing: 2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”Pres: 1800 ,1600,1400 psia

Nodal Analysis Input

A-01 producer

A01

6

Sensitivity of tubing size

2-7/8” & 3-1/2” capable to deliver target rate of 3200 bopd

3-1/2” tbg

4-1/2” tbg

2-7/8” tbg

A01

Tubing size Oil rate (stb/day)Well A1 Well A7 Well A8 Well A11

2.375 2163.6 1887.9 1904.4 1538.42.875 3304.7 2789.5 2817.8 2163.5

3.5 4832.8 3901.4 3959.6 2828.44.5 7075 5291 5378.9 3516.6

2-3/8” tbg

7

Tubing Performance Analysis: Operating rate vs GOR as Pres depleted

Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb

A01

Reservoir pressure (psig)

Oil rate (stb/day)diff % diff

GOR 2.875 3.5

18001400 3304.7 4832.8 1528.1 31.619351600 3483.5 5045.5 1562 30.958281800 3467.8 4913.8 1446 29.42733

16001400 2493.9 3702.5 1208.6 32.642811600 2718.6 3911.7 1193.1 30.500811800 2829.1 4036.5 1207.4 29.91205

14001400 1655.3 2467.9 812.6 32.926781600 2008.5 2917 908.5 31.145011800 2150.3 3103.3 953 30.70924

8

Well Capacity vs Tubing Size

@max THP = 450 psia When WC = 0%• 3-1/2” tubing gives 32% higher rate then a 2-7/8” tubingWhen WC = 20%• 3-1/2” tubing gives 31% higher rate then a 2-7/8” tubing

A01

Reservoir pressure

(psig) Water cut

Oil rate (stb/day)

diff % diff

2.875 3.5

18000 3304.7 4832.8 1528.1 31.61935

10 2905.2 4235.7 1330.5 31.4115720 2494.6 3618.7 1124.1 31.06364

16000 2493.9 3702.5 1208.6 32.64281

10 2142.9 3166.4 1023.5 32.3237720 1778.3 2600.4 822.1 31.61437

14000 1655.3 2467.9 812.6 32.92678

10 1336.5 1974.6 638.1 32.3154120 924.1 1386.1 462 33.33093

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A01 Well Performance Model

Reservoir dataPressure: 1800 psiaTemperature: 215 FNet sand: 10 m (M7/8)Porosity: 25% (average)Permeability: 800 mD FTHP: 450 psia

Fluid parametersAPI: 41.4Rsi: 1400 scf/stbGOR: 1400 scf/stbWC: 0%

Sensitivity analysisGOR: 1400,1600,1800 scf/stbTubing: 2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”Pres: 1800 ,1600,1400 psia

Nodal Analysis Input

A-07 producer

A07

10

Sensitivity of tubing size

2-7/8” & 3-1/2” capable to deliver target rate of 2500 bopd

3-1/2” tbg

4-1/2” tbg

2-7/8” tbg

A-07

Tubing size Oil rate (stb/day)Well A1 Well A7 Well A8 Well A11

2.375 2163.6 1887.9 1904.4 1538.42.875 3304.7 2789.5 2817.8 2163.5

3.5 4832.8 3901.4 3959.6 2828.44.5 7075 5291 5378.9 3516.6

2-3/8” tbg

11

Tubing Performance Analysis: Operating rate vs GOR as Pres depleted

Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb

A07

Reservoir pressure (psig)

Oil rate (stb/day)diff % diff

GOR 2.875 3.5

18001400 2598.8 3649.8 1051 28.79611600 2772.1 3782.3 1010.2 26.708621800 2855.3 3843.1 987.8 25.70321

16001400 1885.8 2658 772.2 29.051921600 2162 2947.7 785.7 26.654681800 2296 3089.3 793.3 25.67896

14001400 1113 1580.5 467.5 29.579251600 1541.9 2115.3 573.4 27.107271800 1717.2 2336.7 619.5 26.51175

12

Well Capacity vs Tubing Size

@max THP = 450 psia When WC = 0%• 3-1/2” tubing gives 29% higher rate then a 2-7/8” tubingWhen WC = 20%• 3-1/2” tubing gives 27% higher rate then a 2-7/8” tubing

A07

Reservoir pressure

(psig) Water cut

Oil rate (stb/day)

diff % diff

2.875 3.5

18000 2598.8 3649.8 1051 28.7961

10 2262.3 3153.2 890.9 28.2538420 1920.3 2637.6 717.3 27.19518

16000 1885.8 2658 772.2 29.05192

10 1590.2 2213.4 623.2 28.1557820 1262.7 1729.3 466.6 26.98202

14000 1113 1580.5 467.5 29.57925

10 784.2 1142.9 358.7 31.3850720 0 0 0 0

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A01 Well Performance Model

Reservoir dataPressure: 1800 psiaTemperature: 215 FNet sand: 10 m (M7/8)Porosity: 25% (average)Permeability: 7800 mD FTHP: 450 psia

Fluid parametersAPI: 41.4Rsi: 1400 scf/stbGOR: 1400 scf/stbWC: 0%

Sensitivity analysisGOR: 1400,1600,1800 scf/stbTubing: 2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”Pres: 1800 ,1600,1400 psia

Nodal Analysis Input

A-08 producer

A08

14

Sensitivity of tubing size

2-7/8” & 3-1/2” capable to deliver target rate of 2300 bopd

3-1/2” tbg

4-1/2” tbg

2-7/8” tbg

A-08

Tubing size Oil rate (stb/day)Well A1 Well A7 Well A8 Well A11

2.375 2163.6 1887.9 1904.4 1538.42.875 3304.7 2789.5 2817.8 2163.5

3.5 4832.8 3901.4 3959.6 2828.44.5 7075 5291 5378.9 3516.6

2-3/8” tbg

15

Tubing Performance Analysis: Operating rate vs GOR as Pres depleted

Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb

A08

Reservoir pressure (psig)

Oil rate (stb/day)diff % diff

GOR 2.875 3.5

18001400 2817.8 3959.6 1141.8 28.836251600 3018 4144.8 1126.8 27.185871800 2990.9 4005.9 1015 25.33763

16001400 2108.3 2989.7 881.4 29.481221600 2310.9 3124.3 813.4 26.034631800 2419.1 3237.7 818.6 25.28338

14001400 1362.8 1904.9 542.1 28.458191600 1684.1 2290 605.9 26.458521800 1833.4 2480.8 647.4 26.09642

16

Well Capacity vs Tubing Size

@max THP = 450 psia When WC = 0%• 3-1/2” tubing gives 29% higher rate then a 2-7/8” tubingWhen WC = 20%• 3-1/2” tubing gives 27% higher rate then a 2-7/8” tubing

A-08

Reservoir pressure

(psig) Water cut

Oil rate (stb/day)

diff % diff

2.875 3.5

18000 2817.8 3959.6 1141.8 28.83625

10 2455.7 3426.6 970.9 28.3342120 2091.3 2880.2 788.9 27.39046

16000 2108.3 2989.7 881.4 29.48122

10 1790.5 2524 733.5 29.0610120 1453 2005.8 552.8 27.56008

14000 1362.8 1904.9 542.1 28.45819

10 1041.9 1455.1 413.2 28.3966720 592 849.4 257.4 30.30374

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A01 Well Performance Model

Reservoir dataPressure: 1800 psiaTemperature: 215 FNet sand: 15 m (M9/14)Porosity: 25% (average)Permeability: 600 mD FTHP: 450 psia

Fluid parametersAPI: 41.4Rsi: 1400 scf/stbGOR: 1400 scf/stbWC: 0%

Sensitivity analysisGOR: 1400,1600,1800 scf/stbTubing: 2-3/8’’,2-7/8”, 3-1/2”, 4-1/2”Pres: 1800 ,1600,1400 psia

Nodal Analysis Input

A-11 producer

A11

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Sensitivity of tubing size

2-7/8” & 3-1/2” capable to deliver target rate of 2300 bopd

3-1/2” tbg

4-1/2” tbg

2-7/8” tbg

A-11

Tubing size Oil rate (stb/day)Well A1 Well A7 Well A8 Well A11

2.375 2163.6 1887.9 1904.4 1538.42.875 3304.7 2789.5 2817.8 2163.5

3.5 4832.8 3901.4 3959.6 2828.44.5 7075 5291 5378.9 3516.6

2-3/8” tbg

19

Tubing Performance Analysis: Operating rate vs GOR as Pres depleted

Significant benefit using tubing size > 2-7/8” even when Pres @ 1400 psi & GOR 1800 scf/stb

A11

Reservoir pressure (psig)

Oil rate (stb/day)diff % diff

GOR 2.875 3.5

18001400 2006.2 2622.6 616.4 23.503391600 2194.5 2765.4 570.9 20.644391800 2177.8 2678.3 500.5 18.68723

16001400 1401 1815.3 414.3 22.822671600 1606.9 1993.6 386.7 19.397071800 1716.7 1815.3 98.6 5.431609

14001400 649 859.2 210.2 24.464621600 1063.4 1349.4 286 21.194611800 1227.8 1556.2 328.4 21.10269

20

Well Capacity vs Tubing Size

@max THP = 450 psia When WC = 0%• 3-1/2” tubing gives 26% higher rate then a 2-7/8” tubingWhen WC = 20%• 3-1/2” tubing gives 21% higher rate then a 2-7/8” tubing

A-11

Reservoir pressure

(psig)

Oil rate (stb/day)

diff % diff

Water cut 2.875 3.5

18000 2006.2 2622.6 616.4 23.50339

10 1715 2217.9 502.9 22.674620 1416.1 1789.5 373.4 20.86616

16000 1401 1815.3 414.3 22.82267

10 1128.1 1451.9 323.8 22.3018120 813 1009.8 196.8 19.48901

14000 649 852.9 203.9 23.90667

10 0 0 0 020 0 0 0 0

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Nodal Analysis - Conclusion

3-1/2” & 4-1/2” tubing can achieved overall target rate for A-01,A-07,A-08 & A-11 4-1/2” tubing carry significant gain against 3-1/2”, thus provides fastest depletion Tubing size selection restricted by production casing size If all zones come in as planned, 3-1/2” tubing will be used as it provides the flexibility

2-7/8" 3-1/2" 4-1/2"

A-01 x x

A-07 x x

A-08 x xA-11 x x x

All zones present will be completed in 7” casing

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No critical requirement for GL, however string will be equipped with minimal GLM to facilitate initial kickoff

Artificial lift requirement

NO GAS LIFT

NO FLOW!

23

WITH GAS LIFT

24

Result:The chart shows that required material is 13Cr.

Proposed tubing material: 13 Chrome

MATERIAL SELECTION

X

CO2mole %

H2Sppm

CO2 partial pressure atm

H2S partial pressureatm

6.35 0 7.73 0

25

SAND CONTROL

No core data available for Berlian East field.Based on the well test data conducted at BE-4 well in 1992, 4 pptb sand has been identified.Slotted liner will be used for all wells as a sand control mechanism

POSSIBLE PRODUCTION PROBLEMBerlian East field shows high percentage of C02 and low percentage of H2S. Possible corrosion problem might occur. Thus, reservoir surveillance and monitoring should be frequently conducted by:

Caliper survey:As and when required to determine the tubing corrosion.

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DUAL STRING WELL COMPLETION SCHEMATIC

Well type: oil producer

Completion type: Dual string w/PDG

Artificial lift: Gas lift

Zone: M2/3 & M7/8

Tubing: 3-1/2’’, 13 Ch

Completion acc: 9 Cr

PDG: Electronic

Sand control: Slotted liner

Brine: 10ppg

Packer setting method: Drop ball & chase

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SINGLE STRING WELL COMPLETION SCHEMATIC

Well type: Oil producer

Completion type: Single string w/PDG

Artificial lift: Gas lift

Zone: M7/8

Tubing: 3-1/2’’, 13 Ch

Completion acc: 9 Cr

PDG: Electronic

Sand control: Slotted liner

Brine: 10ppg

Packer setting method: Drop ball & chase

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WELL COMPLETION PLAN

1. RIH scrapper. Well clean up & displace completion fluid. POOH.2. RIH wireline gun. Correlate and fire guns. Kill well and POOH.3. Retrieve wear bushing & clean THS. Change TPR & test BOP. Land dummy

hanger.4. Run 3-1/2’’ single string completion. Displace packer fluid.5. Tubing integrity test & inflow test. Set & test packer.6. Install BPV. Nipple down BOP. Install tree. POOH BPV & install TWCV. Test

tree & retrieve TWCV.

WELLHEADChristmas tree: Solar Alert Block tree.Wellhead: Compact wellhead from Solar Alert.

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BACK-UP SLIDES

30

Gas lift design

BEFORE INJECT (NO GAS LIFT)

AFTER INJECT (WITH GAS LIFT)

WC (%)OIL RATE (stb/day) WC (%)

OIL RATE (stb/day)

0 4832.8 0 5086.5

20 3618.7 20 4008.8

40 2315.3 40 2910.2

60 645.5 60 1820.5

80 0 80 810.4

BEFORE INJECT (NO GAS LIFT)

AFTER INJECT (WITH GAS LIFT)

WC(%) RATE(stb/day) WC(%) RATE(stb/day)

0 3649.8 0 3982.5

20 2637.6 20 3113.2

40 1543.2 40 2239.9

60 0 60 1385.2

80 0 80 810.4

BEFORE INJECT (WITHOUT GAS LIFT)

AFTER INJECT (WITH GAS LIFT)

WC(%) RATE(stb/day) WC(%) RATE(stb/day)0 3033.8 0 3307.9

20 2249 20 2608.440 1399.8 40 1908.860 0 60 1209.680 0 80 558.2

BEFORE INJECT (WITHOUT GAS LIFT)

AFTER INJECT (WITH GAS LIFT)

WC(%) RATE(stb/day) WC(%) RATE(stb/day)

0 2302.3 0 2601

20 1645.7 20 2037

40 911.3 40 1481.3

60 0 60 933.8

80 0 80 429.7

Well A01

Well A11Well A08

Well A07

31

GUN TYPE & DEPTH

Reservoir Perforation interval

Gun type Gun size Shot density Phasing (degree)

M2/3, M7/8 & M9/14

wireline 2.825’’ 6 spf 45/135

Fluid table

No Type Treatment

1 Completion fluid 10 ppg (Drillwater + Nacl + 3% KCL)

2 Packer fluid 10 ppg (Completion fluid + Bioxide + Oxygen Scavenger + Corrosion inhibitor)

Reservoir: 8.28 ppg

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Perforation

Perforation type: WirelineCorrelation: GR/CCLGun type: 2.875’’ HSD gunCharges: Powerjet NOVASPF: 6 Phasing: 45/135OB/UB: PURE Dynamic underbalance