BU-31 ESP Replacement Opertaion_Final PPT.pptx

ESP Replacement

1. BU-31 ESP Replacement Operation Summary Down-hole Operation Department (DOD) June 21 st , 2024

2. BU-31 ESP Replacement Operation Summary General Information Operational Procedures Design Time versus Actual Time X-mas Photo

3. A. General Information Geological Layout Environmental Data Well Structure Well Data Casing Data Well History Reservoir Requirements Wellhead & X-mas Tree Reservoir Data Proposed Well Schematics

4. 1. Geological Layout MISSAN oilfields are located in MISSAN province in south eastern Iraq and close to Iraq-Iran border It is about 175km north to Basra city Oilfields consist of three producing oilfields, namely ABU GHIRAB, BUZURGAN and FAUQI oilfields

5. 2. Environment Data Climate is hot & dry Average temperature of July is 45 ℃ Average temperature of January is 11℃ Average annual rainfall is 165 mm

6. 3. Well Structure

7. 4. Well Data

8. 5. Casing Data

9. 6. Well History Dec 9 th , 2011: Complete as a producer in Mishrif, TD 4110m & PBTD 4080m and peroration interval (3854-3860m) April 4 th , 2012: Put into production, 2,400 BOPD with ZERO water production, WHP was 36kg/cm2 with chock size is 32/64". Dec 7 th , 2016: Conduct solvent & acidizing operation, oil production increased from 854 to 1350 BOPD. Dec 13 th , 2018: Production test shows Production rate:1256 BOPD and 8% water cut, WHP was 42kg/cm2 with chock size 36 /64". Feb 1 st , 2019: MIT logging showed casing deformation at 2816.2m with Min. ID of 5.48”, Redress deformed casing from 2817.3 to 2817.8m till passed freely up & down through this interval with 144mm (5.669") Casing Swage.

10. 6. Well History April 5 th , 2019: Start 1 st ESP Workover with production rate of 2641 BOPD and 8% water cut, WHP: 44kg/cm2 with chock size 29 /64". April 1 st , 2024: ESP Electrical failure and run life is 1823 days form spin test date. Production rate was around 2512bpd with water cut 20% before ESP shutdown. << Candidate BU-31 for ESP Replacement Operation >>

11. 7. Reservoir Requirements

12. 8. Reservoir Data

13. 9. Wellhead & X-mas Tree

14. 10. Proposed Schematic

15. BUCN-163 ESP Replacement Operation Summary General Information Operational Procedures Design Time versus Actual Time X-mas Photo

16. B. Operational Procedures S/D to open SSD & kill well N/D X-Mas Tree, N/U BOP and P/test. Unset ESP PKR & POOH existing ESP Production String Scrape 6-5/8" Liner RIH Acid Wash & Flowback String, set RTTS PKR, R/U CTU & P/test Conduct Acid Wash & Flowback Operation Kill Well, Unset RTTS PKR & POOH Flowback String M/U ESP assembly, RIH Production String with ESP N/D BOP, N/U X-Mas Tree & P/test Perform S/L Operation to set ESP Packer Conduct ESP Commissioning Operation

17. BU-31 ESP Replacement Operation Commenced @ 10:00 PM on May 26 th , 2024

18. 1. S/L to Open 2.812" SSD, Circulate & Kill Well 26 th −27 th , May 2024: Record SIWHP= 800psi, TCA= 0psi, CCA= 0psi. Bleed off gas, drop pressure from 800psi to 250psi, observe little oil. P/test TCA 300psi/5min and 1000psi/10mins, OK. Bullhead well with 1.01SG and 25m³ killing fluid through tubing with pump rate 120-150L/min and pump pressure 1100-1400psi. RIH with S/L GC to 2.812"SSD depth@ 2869.931,OK, POOH. RIH with S/L shifting tool to open 2.812"SSD, OK, POOH. Reverse circulate with 150m³ of 1.01SG killing fluid with return. Pump Rate:600-700L/min, Pump Pressure:100-200psi. Dynamic Losses approximately 10 m³/hr. Flow check for 1hr, static condition, no flow.

19. CSG Integrity P/test

20. 2. N/D X-Mas Tree & N/U BOP Stack 27 th May, 2024: Conduct PJSM. Install BPV into TH. N/D X-mas tree & check thread of TH, good condition. Keep filling the well 2m³/h through annulus with 1.01SG killing fluid. N/U DSA & BOP stack. Retrieve BPV, and install TWCV. Keep filling the well 2m³/h through annulus with 1.01SG killing fluid. Conduct function test of BOP stack & P/test, OK. Retrieve TWCV. Pipe Ram: 300 psi for 10mins, and 3500 psi for 15mins. Shear Ram: 300 psi for 10mins, and 3500 psi for 15mins. Annular BOP: 300 psi for 10mins, and 2500 psi for 15mins. Keep filling the well 2m³/h through annulus with 1.01SG killing fluid.

21. BOP Pressure Test

22. THS Observations N/D X-Mass tree, clean TS void area, TH seal neck and thread. Check TH thread in good condition. Check RX54 ring gasket, OK.

23. 3. POOH Existing ESP Production String Existing ESP Production String: Motor Guide + WELL LIFT + 450XPLX Motor + 450XPUX Motor + Lower Seal Section + Upper Seal Section + Pump Intake + Lower Pump 400PHUMX5XD + Middle Pump 400PHUMX5XD + Upper Pump 400PHUMX5XD + Pump Head + Discharge Head + X/O Sub, 2-7/8" OD VAGT Box x 3-1/2" OD VAM TOP Pin + 2-7/8" OD Tubing, T-95, VAGT Box x Pin, 1jt + 2.25" F Profile Landing Nipple, 2-7/8" OD VAGT Box x Pin (without plug) + 2-7/8" Blast Joint, T-95, VAGT Box x Pin + 2-7/8" OD Tubing Joint, T-95, VAGT Box x Pin, 1jt + 2.312" SSD, 2-7/8" OD VAGT Box x Pin (CLOSED) + 2-7/8" OD Tubing Pup Joint, T-95, VAGT Box x Pin + 6-5/8"OD Casing ESP Retrievable Packer, 2-7/8" OD VAGT Box x Pin + 2-7/8" OD Tubing Pup Joint, T-95, VAGT Pin x Pin + VAGT Coupling for 2-7/8" OD Tubing, VAGT Box x Box + 2-7/8" OD Tubing Pup Joint, T-95, VAGT Box x Pin + X/O Sub, 3-1/2" OD VAGT Box x 2-7/8" OD VAGT Pin + 3-1/2" OD Tubing Joint, T-95, VAGT Box x Pin, 2jts + 2.812" SSD, T-95, 3-1/2" OD VAGT Box x Pin ( OPEN ) + 3-1/2" OD Tubing, T-95, VAGT Box x Pin, 23jts + X/O Sub, 3-1/2" OD JFE Bear Box x 3-1/2" OD VAGT Pin + X/O Sub, 4-1/2" OD JFE Bear Box x 3-1/2" OD JFE Bear Pin + 4-1/2" OD Tubing, JFE Bear Box x Pin, 271jts + X/O Sub, 3-1/2" OD JFE Bear Pin x 4-1/2" OD JFE Bear Pin + Tubing Hanger, MSP/DRILEX, 3-1/2" API EUE Box Top x 3-1/2" JFE Bear Box Bottom

24. 3. POOH Existing ESP Production String 27 th −30 th May 2024: M/U LJ to TH. Back off lock down screw. P/U TH to 72MT(hook weight = 4.5MT) to unset PKR(overpulled 12MT), successful. Keep filling well 2 /h through annulus with 1.01SG killing fluid. P/U TH on rig floor, cut ESP cable & dismount penetrator. TH in good condition, NO scratch, Rubber Seals in good condition. Keep filling the well 2 /h through annulus with 1.01SG killing fluid. Reverse circulate with 1.01SG) killing fluid 50 with return Pump pressure 150-200 psi & pump rate 700-800 l/min Conduct flow check, static condition. POOH and L/D existing ESP production string to the surface. Keep filling the annulus 2 /h with 1.01SG killing fluid.  

25. POOH Observations TH in good condition, NO damages & scratches on TH body. TH rubber seals in good condition. 271jts of 4-1/2"OD Tubing, L80-13Cr, JFE Bear Box x Pin, good condition, no bending, erosion or corrosion. 25jts of 3-1/2" OD Tubing, T-95, VAGT Box x Pin, good condition, no bending, erosion or corrosion. 2jts of 2-7/8" OD Tubing, T-95, VAGT Box x Pin, good condition, no bending, erosion or corrosion. cover with wax & asphaltene. 2.812" SSD, upper SSD (Fully Open) & 2.312" SSD, lower SSD (Closed), good condition. 6-5/8" ESP Retrievable Packer, One packing element is damaged. No damage on PKR slip, good condition

26. POOH Observations

27. 6-5/8" ESP Retrievable PKR

28. 4. Scrape 7" Liner 30 th May− 2 nd June 2024 6-5/8" Liner Scraping String: 5-5/8" Tri-cone Bit (without nozzle) + X/O, 3-1/2" REG Box x 3-1/2" IF Box + 6-5/8" Rotate Scraper, 3-1/2" IF Pin x 3-1/2" IF Box + 3-1/2" DP Pup Joint, 3-1/2" IF Pin x 3-1/2" IF Box + 5-1/2" Fishing Cup, 3-1/2" IF Box x 3-1/2" IF Pin + 5-1/2" Fishing Cup, 3-1/2" IF Box x 3-1/2" IF Pin + 5-1/2" Columnar Magnet, 3-1/2" IF Pin x 3-1/2" IF Box + 3-1/2" DP Joint,G-105, 3-1/2" IF Pin x 3-1/2" IF Box, 1jt + 6-5/8" ESP Drift Sub, 3-1/2" IF Pin x 3-1/2" IF Box + 3-1/2" DP Pup Joint, 3-1/2" IF Pin x 3-1/2" IF Box + 4-3/4″ Jar, 3-1/2" IF Box x 3-1/2" IF Box + 4-3/4" Drill Collar, 4145H, 46.75ppf, 3-1/2" IF Box x 3-1/2" IF Box, 5jts + 3-1/2"Drill Pipe, G-105, 13.30ppf, 3-1/2" IF Box x 3-1/2" IF Box to Surface M/U & RIH 7"Liner scraping string to 3056.5m while scarping each stand up & down for five times between 2721.7m-3056.5m. Drift 3-1/2" DP joints with API drift properly. Keep filling the annulus 2 /h with 1.01SG killing fluid. Conduct 51 forward circulation for clean-up, with return. POOH & L/D the scraping string to the surface.  

29. 4. Scrape 7" Liner Scraper, bit & fish cubs very clean! After POOH

30. 5. RIH Acid Wash & Flowback String with RTTS PKR June 2 nd –7 th , 2024 Acid Wash & Flowback String with 6-5/8" RTTS PKR: 2-7/8" Mule Shoe, VAM TOP Box up + 2-7/8" OD Tubing Joint, VAM TOP Box x Pin, 2jts + X/O Sub, 3-1/2"OD VAM TOP Box x 2-7/8" OD VAM TOP Pin + 3-1/2" OD Tubing Joint, VAM TOP Box x Pin, 99jts + X/O Sub, 3-1/2" IF Box x 3-1/2" OD VAM TOP Pin + 6-5/8"RTTS Packer Assembly, 3-1/2" IF Box × Pin + X/O Sub, 3-1/2" OD VAM TOP Box × 3-1/2" IF Pin + 3-1/2" OD Tubing Joint, VAM TOP Box × Pin, 2jts + 2.812 SSD, 3-1/2" OD VAM TOP Box x Pin ( CLOSED ) + 3-1/2" OD Tubing Joint, VAM TOP Box × Pin, 113jts + X/O Sub, 4-1/2" OD VAM TOP Box × 3-1/2" VAM TOP Pin + 4-1/2"OD Tubing Joint, VAM TOP Box × Pin, 149jts + 4-1/2" OD Tubing Pup Joint, VAM TOP Box × Pin, 3m + 4-1/2" OD Tubing Pup Joint, VAM TOP Box × Pin, 1m + X/O Sub, 4-1/2" OD JFE BEAR Box × 4-1/2" VAM TOP Pin + 4-1/2" OD Tubing Joint, JFE BEAR Box × Pin, 23jts + XO Sub, 4-1/2" OD JFE BEAR Pin x 3-1/2" OD EUE Box

31. 5. RIH Acid Wash & Flowback String with RTTS PKR M/U & RIH acid wash & flowback string with 6-5/8" RTTS PKR to 3686.5m 6-5/8" RTTS PKR could not pass through TOL at 2673m. R/U circulation head. Conduct 85m³ forward circulation with 1.01SG working fluid with 71m³ return. --- Keep filling the annulus 2m3/hr with 1.01SG working fluid. Work string to pass 6-5/8" RTTS PKR through TOL, NO success. Observe string RIH only 30cm with 5MT slack off weight. Observe string jump out gently while P/U. POOH and rack back acid wash & flowback string to 995.3m. Observe minor scratches on RTTS PKR bottom entry section. Change 6-5/8" RTTS PKR Assembly with new assembly.

32. 1 st RTTS PKR Assembly

33. 5. RIH Acid Wash & Flowback String with RTTS PKR M/U & RIH acid wash & flowback string in stands to 3686.5m. New 6-5/8" RTTS packer assembly pass freely/easily through TOL. Keep filling annulus 2m3/hr with 1.01SG working fluid. Drift tubings & completion with API drift properly. Cont. M/U & RIH acid wash & flowback string to 3787.0m. Mule shoe sting into upper WQX packer for 4m. Keep filling the annulus 2m3/hr with 1.01SG working fluid. Drift tubings & completion with API drift properly. Set 6-5/8" RTTS PKR successfully at 2791.6m Rotate string 8 turns clockwise & S/O 10MT Conduct RTTS PKR P/test via annulus, OK. Pressure up to 1000psi for 10min, no return from tubing.

34. Acid Wash & Flowback String Schematic

35. 6. Conduct Acid Wash & Flowback Operation June 7 th –10 th , 2024 Flush 1.75″ CT with fresh water & P/test for CT. N/U CT BOP on T-Tree & N/U CT injector head on CT BOP. N/U flowback Lines & choke manifold on tubing wing valve & p/test. RIH CT to 3854.0m. Conduct acid wash operation per approved program. Displace 5.5m³ Demulsifier Fluid (CT at 3854m): Pump Rate = 0-0.8bpm, Pump Pressure = 22.3-940.4psi & WHP=0-18.4psi. Squeeze 3.5m³ Demulsifier Fluid (Drag CT F/3854m T/3860m): Pump Rate = 0.8bpm, Pump Pressure = 18.7-919psi & WHP=0-18psi. Squeeze 9.0m³ Self-diverting Acid (Drag CT F/3860m T/3854m): Pump Rate = 0.8-1.8bpm, Pump Pressure = 921-4624psi & WHP=32.6-203.9psi. Squeeze 5.5m³ Displacement Fluid (Drag CT F/3856m T/3854m): Pump Rate = 0.0-1.7bpm, Pump Pressure=23.6-2612.7psi & WHP=0.3-115.2psi. Wait 2hrs to react with formation while POOH CT to 1500m.

36. Acid Wash Operation Curve

37. Flowback Operation (72 Hours) Conduct N2 gaslift & flowback operation. Flowback parameters: CT Depth=1500m , Choke Size=32/64", N2 Pump Pressure=1421psi, N2 FR=1200m³/h, WHP=400psi, Back Pressure=120psi, WHT=48ºC, H2S=0ppm, BS&W=100%, Flow Rate=829.4FPD Con. N2 gaslift & flowback operation. Last Flowback parameters: CT Depth=2000m , Choke Size=32/64", N2 Pump Pressure=1494psi, N2 FR=1200m³/h, WHP=480psi, Back Pressure=120psi, WHT=54ºC, H2S=0ppm, BS&W=100%, Flow Rate=933.1FPD Cont. N2 gaslift & flowback operation. 3 rd Sample Analysis: pH=6, Density=1.0349SG, CL=19500ppm, Salinity=65900ppm, BS=0.5% ,W= 85% and Oil=15% Final Flowback Parameters: CT Depth=2500m , Choke Size=40/64", N2 Pump Pressure=1494psi, N2 FR=1200m³/h, WHP=280psi, Back Pressure=120psi, WHT=56ºC, H2S=0ppm, BS&W=70%, Flow Rate=1321.9FPD , Total Fluid Recovered=2999.2bbls.

38. 7. Kill Well, Unset RTTS PKR & POOH Flowback String POOH CT to surface while NF. R/D CT & flowback equipment. Total Fluid Recovered: 489m3 (3077bbl) Kill well by bullheading with 30m3 1.01SG working fluid. Pump Rate: 900-1000l/min & PP: 100-200psi. FC 30min, Well Static. P/U the string to 54MT, unset 7" RTTS PKR with 2MT overpull. Wait 30mins for PKR rubber element retraction. Conduct reverse circulation with 50m3 1.01SG working fluid. FR: 1200-1300 l/min & PP: 300-400psi. FC for 30min, well static. POOH & L/D acid wash & flowback string to surface. Check 6-5/8" RTTS packer in good condition . Keep filling the annulus 2m3/hr with 1.01SG working fluid.

39. 2 nd RTTS PKR Assembly

40. 8. RIH ESP Production String with CIL 12 th − 18 th June 2024 ESP Production String with CIL: ESP Assembly (6-Fin Type Motor Guide + Chemical Injection Sub + Zenith Sensor Gauge + 450 XPX ESP Motor + Lower Tandem Seal Section + Upper Tandem Seal Section + Pump Intake + Lower Pump Section + Upper Pump Section + Pump Head + Discharge Head 3 1/2" VAM TOP) + X/O Sub, 2-7/8" OD VAM TOP Box x 3-1/2" OD VAM TOP Pin + 2-7/8" OD Tubing Joint, VAM TOP Box x Pin, 1jt + Baker 2.25" F Nipple, 2-7/8" OD VAM TOP Box x Pin (without Blanking Plug) + Blast Joint, 2-7/8" OD 6.40ppf VAM TOP Box x Pin + 2-7/8" OD Tubing Joint, VAM TOP Box x Pin, 1jt + 2-7/8" OD Pup Joint, VAM Top Box x Pin + Baker 2.312" F SSD, CMD, 2-7/8" OD VAM Top Box x Pin (CLOSED) + 2-7/8" OD Tubing Pup Joint, VAM TOP Box x Pin + 2-7/8" OD Tubing Joint, VAM TOP Box x Pin, 1jt + X/O Sub, 2-7/8" OD JFE Bear Box x 2-7/8" OD VAM TOP Pin + 2-7/8" OD Tubing Pup Joint, JFE Bear Box x Pin + D&L ESP Retrievable Packer, 2-7/8" OD JFE Bear Box x Pin + 2-7/8" OD Tubing Pup Joint, JFE Bear Box x Pin + X/O Sub, 3-1/2" OD VAM TOP Box x 2-7/8" OD JFE Bear Pin + 3-1/2" OD Tubing Joint, VAM TOP Box x Pin, 2jts + 3-1/2" OD Pup Joint, VAM TOP Box x Pin + X/O Sub, 3-1/2" OD JFE Bear Box x 3-1/2" OD VAM TOP Pin + Baker 2.812" F Profile SSD, 3-1/2" OD JFE BEAR Box x Pin ( OPEN ) + X/O Sub, 3-1/2" OD VAM TOP Box x 3-1/2" OD JFE BEAR Pin + 3-1/2" OD Pup Joint, VAM TOP Box x Pin + 3-1/2" OD Tubing Joint, VAM TOP Box x Pin, +/- 29jts + X/O Sub, 4-1/2" OD VAM TOP Box x 3-1/2" OD VAM TOP Pin + 4-1/2" OD Tubing Joint, VAM TOP Box x Pin, 269jts + X/O Sub, 4-1/2" OD JFE Bear Box x 4-1/2" OD VAM TOP Pin + X/O Sub, 3-1/2" OD JFE Bear Pin x 4-1/2" OD JFE Bear Pin + TH, 11" X 3-1/8", 3-1/2" API EUE Box Top x 3-1/2" JFE Bear Box Bottom

41. 8. RIH ESP Production String with CIL Hold PJSM. M/U & RIH with jetting tool to flush TS with 800L/min for 20 min, L/D jetting tool. Conduct TH dummy run into TS, OK. Keep filling well from annulus with 2m³/h of 1.01SG working fluid. M/U & RIH to 64.4m. R/U S/L & Set 2.25" CV into 2.25" Landing Nipple P/test tubing integrity, 500psi for 5mins, 4400psi for 15mins,OK. Keep filling well from annulus with 2m³/h of 1.01SG working fluid. M/U 6-5/8" D&L ESP Retrievable PKR to 73.7m. S/L RIH with 2.34" GC to 2.312" SSD, NO Success . Find thread damage between X/O Sub (2-7/8"JFE Bear Box x 2-7/8" VAM TOP Pin) & 2-7/8" Tubing Pup Joint , JFE Bear Box x Pin (ESP PKR bottom pup joint) Change X/O sub & tubing pup joint. M/U 6-5/8" ESP PKR to 74.7m. Conduct S/L with 2.34"GC to 2.31"SSD for drifting, OK, and POOH.

42. Damaged X/O & Pup Joint

43. 8. RIH ESP Production String with CIL Connect penetrator below & above ESP PKR & cable splicing. Resume M/U & RIH ESP production string to 1005.4m. Keep filling well from annulus with 2m³/h of 1.01SG working fluid. Drift all tubular with API standard drift. Use TRS to monitor torque. Conduct S/L to drift tubing, NO success . RIH 2.84"GC to 805-806m (100m above 2.81”SSD), no success. RIH 2.81" check valve to same depth @ 805-806m, no success. Adjust/calibrate power tong & TRS for optimum make-up torque. POOH & rack back string to 200.01m (3-1/2"tubing NO. 12 & 13) Check NO.12 coupling ID was smaller than drift ID, change tubing joints. RIH 2.81” C.V to set 2.81”SSD, successful.

44. Damaged Tubing Joint

45. 8. RIH ESP Production String with CIL M/U & RIH ESP production string with CIL in stands to 382.58m (finish RIH all 3-1/2" OD VAM TOP tubing). Keep filling well from annulus with 2m3/hr of 1.01SG brine. Drift all tubular with API drift. Use TRS to apply optimum make-up torque. Conduct S/L operation with RIH 2.84" GC to 2.81" SSD, OK. Set 2.81“CV into 2.81" SSD and p/test tubing integrity, 500psi/5min, 4000psi/10min, OK. Resume M/U & RIH ESP production string with CIL to 1112.5m. Keep filling well from annulus with 2m3/hr of 1.01SG brine. Drift all tubular with API drift. Use TRS to apply optimum make-up torque. Conduct S/L operation, set 2.81"CV into 2.81" SSD and P/test tubing integrity, 500psi/5min, 4000psi/15min, OK. Keep filling well from annulus with 2m3/hr of 1.01SG brine

46. 8. RIH ESP Production String with CIL Resume M/U & RIH ESP production string with CIL to 1940.5m. Keep filling well from annulus with 2m3/hr of 1.01SG brine. Drift all tubular with API drift. Use TRS to apply optimum make-up torque. Conduct S/L operation with RIH 2.81" CV to 2.81" SSD and set 2.81" check valve into 2.81" SSD and P/test tubing integrity, 500psi/5min, 4000psi/15min, OK. Keep filling the well from annulus with 2m3/hr of 1.01SG PKR fluid . Resume M/U & RIH ESP production string & M/U TH to 3002.9m. Keep filling well from annulus with 2m3/hr of 1.01SG brine. Drift all tubular with API drift. Use TRS to apply optimum make-up torque. Conduct S/L operation to P/test tubing integrity, OK. Set 2.81" CV at 2.81" SSD. P/test @ 500psi/5min & 4400psi/15min. Keep filling the well from annulus with 2m3/hr of 1.01SG PKR fluid .

47. 8. RIH ESP Production String with CIL M/U LJ into TH and rotate to align TH on RF with orientation of TS. Pull out cable properly for space out lower pigtail. Install penetrator feed-through to TH. Connect LPT to feed-through and conduct cable splicing. Cable Integrity after TH LPT Splice: P-P: 5.9 Ω Balance, P-G: 205M Ω Sensor Readings after TH LPT Splice: Pi: 3703psi, Pd: 3698psi, Ti: 97℃, Tm: 98℃, Vx: 0.009G, Vz: 0.014G Vt: 120V & Ct: 10mA Land TH into TS completely, TD at 3013.316 . Tighten up lock-down screws. P/U & S/O Weights: 62.0MT & 60.0 (4.5MT weigh of Hook) Keep filling well from annulus with 2m³/h of 1.01SG Packer Fluid .

48. RIH ESP Production with CIL

49. P/test Tubing Integrity (after M/U TH)

50. 6. N/D BOP, N/U X-Mas Tree & P/test 18 th –19 th June, 2024: Back off & lay down LJ from TH. Install BPV. N/D BOP stack. Keep filling well from annulus with 2m³/h of 1.01SG Packer Fluid . N/U TS adaptor with 1 st master valve. P/test TH sealing & TS ring gasket, OK. N/U remaining parts of X-mas tree. 3000psi for 15mins. Keep filling well from annulus with 2m³/h of 1.01SG Packer Fluid. Retrieve BPV & install TWCV. P/test X-mas tree integrity at 4500psi, OK. Retrieve TWCV. Keep filling well from annulus with 2m³/h of 1.01SG Packer Fluid.

51. N/U X-Mas Tree

52. P/test TH Sealing & TS Ring Gasket & X-Mas Integrity

53. 7. Perform S/L Operation to Set ESP Packer June 19 th 2024: R/U S/L unit. Conduct S/L operation to close 2.812" SSD, OK. Set 2.312" check valve into 2.312" SSD, OK. R/U pumping unit. Pressure up tubing to set 6-5/8" D&L ESP PKR, OK. Bleed of pressure to zero. 500psi for 5min & then 2000psi for 30min. Use 7m³ of 1.01SG packer fluid to fill up tubing. Conduct annulus P/test 500psi/15min, OK. Bleed off pressure. Conduct S/L operation to retrieve 2.312" check valve, and R/D S/L unit. Install cap on X-mas tree and close all valves. Use 15m³ of 1.01SG packer fluids to fill up annulus. PKR depth confirmed @ 2941.24m

54. Set 7″ ESP Packer & TCA P/test

55. 8. ESP Start-up & Spin Test June 19 th −21 th 2024: Hold PJSM. Conduct necessary preparations for ESP spin test. ESP Start-up: Start-up ESP with 1 st rotation FWD at 40Hz and increase to 45Hz. Observe flow at surface. S/D ESP manually to change rotation. Start-up ESP with 2 nd rotation REV at 40Hz and increase to 50 Hz. Observe NO surface flow, identified 1 st rotation is Right Rotation. Start-up ESP with Right Rotation at 40Hz and increase gradually to 45Hz. Observe flow at surface. Keep ESP running & continue monitoring and recording the data.

56. 8. ESP Start-up Test & Commissioning Motor: 450 XPX 187/2335/52 Upper & Lower Pumps: 400PMXSXD 96 FLEX31 HS < ESP spin test start at 11:00 AM on June 20 th , 2024 > Keep ESP running while for 10 ½ hrs using waste tank & tankers. Fluid Sample @ 15:00 Analysis: Water Cut: 40%, Blank Viscosity @ 90ºC : 68.5 mPa.s @ 90ºC, Sand Content: 0% Cont. ESP spin test for 13 hrs while diverting to BUS3 DGS. S/D the ESP @ 10:30 AM on June 21 st & secure the well. < BU-31/BHDC-113 ESP Replacement Operation Finished Successfully at 11:00 AM on June 21 st , 2024 >

57. Final Running Parameters Controller Data: Frequency: 55Hz, Motor Amp: 34A, Volt out: 335Volts Sensor Readings: Pi: 2590Psi, Pd: 4217Psi, Ti: 111C°, Tm: 121C°, Vx: 0.4G, Vz: 0.1G, Ct: 10.0mA Surface Parameters: WHP: 400psi, CHP: 0psi, Choke size: 24/64” W/C: 0% & Flow rate: 2,150 bbl/day

58. ESP Cable Integrity

59. ESP Spin Test Records

60. BU-31 ESP Replacement Operation Summary General Information Operational Procedures Design Time versus Actual Time X-mas Photo

61. Operation Rate of Progress

62. Operation Rate of Progress

63. Operation Time Analysis

64. Rate of Progress Chart

65. None-Productive Time (NPT)

66. BU-31 ESP Replacement Operation Summary Start Date: May 26 th , 2024 @ 22:00 Finish Date: June 21 st , 2024 @ 11:00 AM Designed Days: 25.85 Days NPT: 2.85 Days Actual Days: 25.54 Days Ahead of Plan: + 0.31 Days Rig Contractor: BHDC-113 S/L, Engineering, Fluids Services & Stimulation : COSL ESP (POOH): Baker Hughes ESP (RIH) & Completion : Baker Hughes

67. BU-31 ESP Replacement Operation Summary General Information Operational Procedures Design Time versus Actual Time X-mas Photos

68. X-Mas Tree

69. THANKS