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 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 4 wells 1. To develop 3 prospective reservoirs: 2. -M2/3, M7/8 and M9/14 3. Deviated well, max angle 90° /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) Layers M2/3 & M7/8M7/8 M9/14

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

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 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 A /8” tbg

7 Tubing Performance Analysis: Operating rate vs GOR as Pres depleted Significant benefit using tubing size > 2-7/8” even when 1400 psi & GOR 1800 scf/stb A01 Reservoir pressure (psig) Oil rate (stb/day) diff% diff GOR

8 Well Capacity vs Tubing 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

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 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 A /8” tbg

11 Tubing Performance Analysis: Operating rate vs GOR as Pres depleted Significant benefit using tubing size > 2-7/8” even when 1400 psi & GOR 1800 scf/stb A07 Reservoir pressure (psig) Oil rate (stb/day) diff% diff GOR

12 Well Capacity vs Tubing 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

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 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 A /8” tbg

15 Tubing Performance Analysis: Operating rate vs GOR as Pres depleted Significant benefit using tubing size > 2-7/8” even when 1400 psi & GOR 1800 scf/stb A08 Reservoir pressure (psig) Oil rate (stb/day) diff% diff GOR

16 Well Capacity vs Tubing 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

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 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 A /8” tbg

19 Tubing Performance Analysis: Operating rate vs GOR as Pres depleted Significant benefit using tubing size > 2-7/8” even when 1400 psi & GOR 1800 scf/stb A11 Reservoir pressure (psig) Oil rate (stb/day) diff% diff GOR

20 Well Capacity vs Tubing 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 cut

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  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 CO2 mole % H2S ppm CO2 partial pressure atm H2S partial pressure atm

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 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 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 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 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) BEFORE INJECT (NO GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC(%)RATE(stb/day)WC(%)RATE(stb/day) BEFORE INJECT (WITHOUT GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC(%)RATE(stb/day)WC(%)RATE(stb/day) BEFORE INJECT (WITHOUT GAS LIFT) AFTER INJECT (WITH GAS LIFT) WC(%)RATE(stb/day)WC(%)RATE(stb/day) Well A01 Well A11Well A08 Well A07

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 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