1. 1 Introduction Background of study Four 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 objectives  To 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 zones  To 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/d Well A07=2500 stb/d Well A08=2300 stb/d Well A11=1900 stb/d

2. 2 P-TECHSTUDYP-TECHSTUDY Nodal Analysis Nodal Analysis Artificial Lift Requirement Artificial Lift Requirement Material Design Material Design Completion Design Completion Design SCOPE OF STUDY/DELIVERABLES Sand Control Requirement Sand Control Requirement

3. 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 Well A1Well A7Well A8Well A11 Target rate (stb/day)3200250023001900 Layers M2/3 & M7/8M7/8 M9/14

4. NODAL ANALYSIS Well A01 Performance Model Well A07 Performance Model Well A08 Performance Model Well A11 Performance Model

5. 5 A01 Well Performance Model Reservoir data Pressure:1800 psia Temperature:215 F Net sand:22 m (M2/3 & M7/8) Porosity:26% (average) Permeability:700 mD FTHP:450 psia Fluid parameters API:41.4 Rsi:1400 scf/stb GOR:1400 scf/stb WC:0% Sensitivity analysis GOR:1400,1600,1800 scf/stb Tubing: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. 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 A1Well A7Well A8Well A11 2.3752163.61887.91904.41538.4 2.8753304.72789.52817.82163.5 3.54832.83901.43959.62828.4 4.5707552915378.93516.6 2-3/8” tbg

7. 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 GOR2.8753.5 1800 14003304.74832.81528.131.61935 16003483.55045.5156230.95828 18003467.84913.8144629.42733 1600 14002493.93702.51208.632.64281 16002718.63911.71193.130.50081 18002829.14036.51207.429.91205 1400 1655.32467.9812.632.92678 16002008.52917908.531.14501 18002150.33103.395330.70924

8. 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” tubing When 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 2.8753.5 1800 03304.74832.81528.131.61935 102905.24235.71330.531.41157 202494.63618.71124.131.06364 1600 02493.93702.51208.632.64281 102142.93166.41023.532.32377 201778.32600.4822.131.61437 1400 01655.32467.9812.632.92678 101336.51974.6638.132.31541 20924.11386.146233.33093

9. 9 A01 Well Performance Model Reservoir data Pressure:1800 psia Temperature:215 F Net sand:10 m (M7/8) Porosity:25% (average) Permeability:800 mD FTHP:450 psia Fluid parameters API:41.4 Rsi:1400 scf/stb GOR:1400 scf/stb WC:0% Sensitivity analysis GOR:1400,1600,1800 scf/stb Tubing: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. 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 A1Well A7Well A8Well A11 2.3752163.61887.91904.41538.4 2.8753304.72789.52817.82163.5 3.54832.83901.43959.62828.4 4.5707552915378.93516.6 2-3/8” tbg

11. 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 GOR2.8753.5 1800 14002598.83649.8105128.7961 16002772.13782.31010.226.70862 18002855.33843.1987.825.70321 1600 14001885.82658772.229.05192 160021622947.7785.726.65468 180022963089.3793.325.67896 1400 11131580.5467.529.57925 16001541.92115.3573.427.10727 18001717.22336.7619.526.51175

12. 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” tubing When 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 2.8753.5 1800 02598.83649.8105128.7961 102262.33153.2890.928.25384 201920.32637.6717.327.19518 1600 01885.82658772.229.05192 101590.22213.4623.228.15578 201262.71729.3466.626.98202 1400 011131580.5467.529.57925 10784.21142.9358.731.38507 200000

13. 13 A01 Well Performance Model Reservoir data Pressure:1800 psia Temperature:215 F Net sand:10 m (M7/8) Porosity:25% (average) Permeability:7800 mD FTHP:450 psia Fluid parameters API:41.4 Rsi:1400 scf/stb GOR:1400 scf/stb WC:0% Sensitivity analysis GOR:1400,1600,1800 scf/stb Tubing: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. 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 A1Well A7Well A8Well A11 2.3752163.61887.91904.41538.4 2.8753304.72789.52817.82163.5 3.54832.83901.43959.62828.4 4.5707552915378.93516.6 2-3/8” tbg

15. 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 GOR2.8753.5 1800 14002817.83959.61141.828.83625 160030184144.81126.827.18587 18002990.94005.9101525.33763 1600 14002108.32989.7881.429.48122 16002310.93124.3813.426.03463 18002419.13237.7818.625.28338 1400 1362.81904.9542.128.45819 16001684.12290605.926.45852 18001833.42480.8647.426.09642

16. 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” tubing When 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 2.8753.5 1800 02817.83959.61141.828.83625 102455.73426.6970.928.33421 202091.32880.2788.927.39046 1600 02108.32989.7881.429.48122 101790.52524733.529.06101 2014532005.8552.827.56008 1400 01362.81904.9542.128.45819 101041.91455.1413.228.39667 20592849.4257.430.30374

17. 17 A01 Well Performance Model Reservoir data Pressure:1800 psia Temperature:215 F Net sand:15 m (M9/14) Porosity:25% (average) Permeability:600 mD FTHP:450 psia Fluid parameters API:41.4 Rsi:1400 scf/stb GOR:1400 scf/stb WC:0% Sensitivity analysis GOR:1400,1600,1800 scf/stb Tubing:2-3/8’’,2-7/8”, 3-1/2”, 4-1/2” Pres:1800,1600,1400 psia Nodal Analysis Input A-11 producer A11

18. 18 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 A1Well A7Well A8Well A11 2.3752163.61887.91904.41538.4 2.8753304.72789.52817.82163.5 3.54832.83901.43959.62828.4 4.5707552915378.93516.6 2-3/8” tbg

19. 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 GOR2.8753.5 1800 14002006.22622.6616.423.50339 16002194.52765.4570.920.64439 18002177.82678.3500.518.68723 1600 140014011815.3414.322.82267 16001606.91993.6386.719.39707 18001716.71815.398.65.431609 1400 649859.2210.224.46462 16001063.41349.428621.19461 18001227.81556.2328.421.10269

20. 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” tubing When 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 cut2.8753.5 1800 02006.22622.6616.423.50339 1017152217.9502.922.6746 201416.11789.5373.420.86616 1600 014011815.3414.322.82267 101128.11451.9323.822.30181 208131009.8196.819.48901 1400 0649852.9203.923.90667 100000 200000

21. 21 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  All zones present will be completed in 7” casing

22. 22  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. 23 WITH GAS LIFT

24. 24 Result: The chart shows that required material is 13Cr. Proposed tubing material: 13 Chrome MATERIAL SELECTION X CO2 mole % H2S ppm CO2 partial pressure atm H2S partial pressure atm 6.3507.730

25. 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 PROBLEM Berlian 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.

26. 26 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

27. 27 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

28. 28 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. WELLHEAD Christmas tree: Solar Alert Block tree. Wellhead: Compact wellhead from Solar Alert.

29. 29 BACK-UP SLIDES

30. 30 Gas lift design BEFORE INJECT (NO GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC (%) OIL RATE (stb/day)WC (%) OIL RATE (stb/day) 04832.805086.5 203618.7204008.8 402315.3402910.2 60645.5601820.5 800 810.4 BEFORE INJECT (NO GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC(%)RATE(stb/day)WC(%)RATE(stb/day) 03649.803982.5 202637.6203113.2 401543.2402239.9 600 1385.2 800 810.4 BEFORE INJECT (WITHOUT GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC(%)RATE(stb/day)WC(%)RATE(stb/day) 03033.803307.9 202249202608.4 401399.8401908.8 600 1209.6 800 558.2 BEFORE INJECT (WITHOUT GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC(%)RATE(stb/day)WC(%)RATE(stb/day) 02302.302601 201645.7202037 40911.3401481.3 600 933.8 800 429.7 Well A01 Well A11Well A08 Well A07

31. 31 GUN TYPE & DEPTH ReservoirPerforation interval Gun typeGun sizeShot densityPhasing (degree) M2/3, M7/8 & M9/14 wireline2.825’’6 spf45/135 Fluid table NoTypeTreatment 1Completion fluid 10 ppg (Drillwater + Nacl + 3% KCL) 2Packer fluid10 ppg (Completion fluid + Bioxide + Oxygen Scavenger + Corrosion inhibitor) Reservoir: 8.28 ppg

32. 32 Perforation Perforation type: Wireline Correlation: GR/CCL Gun type: 2.875’’ HSD gun Charges: Powerjet NOVA SPF: 6 Phasing: 45/135 OB/UB: PURE Dynamic underbalance