FQCS-50H_ESP Workover Operation_Final PPT.pptx

Workover, Fishing

1. FQCS-50H ESP Workover Summary Down-hole Operation Department (DOD) June 26, 2023

2. FQCS-50H ESP Workover Summary General Information Operational Procedures Design Time versus Actual Time X-Mas Photo

3. A. General Information Geological Layout Environmental Data Well Data Casing Data Well History Well Schematic Reservoir Requirement Reservoir Data Wellhead & X-Mas Tree 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 Data

7. 4. Casing Data

8. 5. Well History FQCS-50H is located in the south area of Fauqi Oilfield. The was drilled in Feb, 2019. On Mar 19th, 2019, ESP started for production. It tripped on 3 rd of June 2022. The running life was 1172 days.

9. 6. Well Schematic

10. 7. 4” Perforated Liner

11. 8. Reservoir Requirements

12. 8. Reservoir Data

13. 9. Wellhead & X-Mas Data

14. 10. Proposed Wellbore Schematic

15. FQCS-50H ESP Workover Summary General Information Operational Procedures Design Time versus Actual Time X-Mas Photo

16. B. Operational Procedures S/L operation & kill well N/D X-mas Tree and N/U BOP stack Release ESP packer, POOH existing ESP production string Scrape and Drift the 6-5/8″ Liner RIH acidizing string with 6-5/8″ RTTS packer Conduct deep penetration acidizing & flow back operation M/U and RIH ESP production string Land TH into tubing spool N/D BOP ,N/U X-mas tree and P/T S/L to set ESP packer Spin test

17. FQCS─50H ESP Workover Operation Commenced @ 13:00 on 13 th May, 2023

18. 1. S/L operation & kill well 13 th ─ 15 th May 2023: R/U kill line from mud pump to X-mas tree, P/test 300psi/5mins, 3000psi/15mins, P/test surface lines up to 500 psi, OK. Check and record the SIWHP= 450psi, TCA= 0psi,CCA= 0psi. Bleed off the gas from WHP through flare line, the pressure from 450psi to 0psi, oil was found and stop bleed off. P/test TCA 300psi/5min and 1000psi/10mins, OK. Bullhead well with 1.01SG and 40m³ killing fluid through tubing with pump rate 200-300L/min and pump pressure 800-1000psi.

19. CSG Integrity P/test

20. 1. S/L operation & kill well 13 th ─ 15 th May 2023: R/U S/L Lubricator and BOP, P/Test same to 2000psi/15mins. S/L operation RIH w/ 2.83" GC to drift tubing @2859.38m top of 2.812” SSD without obstruction. RIH 2.812" shifting tool to 2859.38m open 2.812” SSD successfully. POOH 2.812" shifting tool to 2829m with obstruction. Try many time to release the 2.812" shifting tool, no success. BHDC RIH cutter to cut the S/L at the top of 2.812" shifting tool. POOH cutter. R/D BHDC S/L equipment. Reverse circulate the well with 1.01SG killing fluid 50m³. Pump rate 1m³/min, pump pressure 530-550psi, no return.

21. 2. N/D X-Mas Tree & N/U BOP Stack 15 th ─ 16 th May 2023: Hold PJSM. Install BPV into tubing hanger. N/D X-mas tree. THS was in good condition. N/U BOP Stack. Connect the kill & choke manifold. Retrieve BPV & install TWCV. Conduct BOP function test, OK. Keep filling the well with 1.01SG working fluid 5m³/hr. Close 4-1/2" pipe ram & P/test between adapter flange and tubing spool with 300psi/10min and 3500ps/15min, ok. P/T choke & kill manifolds for 300psi/10mins, 3500psi/15mins, ok. Annular BOP pressure test 300psi/10mins, 2500psi/15mins, ok. Shear ram pressure test 300psi/10mins, 3500psi/15mins, ok.

22. BOP Stacks P/test

23. THS Observations

24. 3. Release ESP Packer, POOH & L/D Production String 16 th − 20 th , May 2023: Existing ESP Production String: Motor Guide + WELL LIFT H 150, Pressure Reading, W/Bull Nose + Lower Motor + Upper Motor + Lower Tandem Seal + Upper Tandem Seal + Pump Intake + Lower Pump + Middle Pump + Upper Pump + Ported Pump Pressure Sub + Discharge Head + X/O Sub, 2-7/8" JFE Bear Box x 3-1/2" VAM TOP Pin + Tubing Joint, 2-7/8" JFE Bear Box x Pin, 1jt + 2.31" WX Landing Nipple (without plug), T-95, JFE Bear Box x Pin + Blast Joint, T-95, 2-7/8" JFE Bear Box x Pin + Tubing Joint, T-95, 2-7/8" JFE Bear Box x Pin, 1jt + X/O Sub, T-95, 2-7/8" VAGT Box x 3-1/2" JFE Bear Pin + Tubing Pup Joint, T-95, 2-7/8" VAGT Box x Pin + 6-5/8" D & L ESP Retrievable Packer, L80-13Cr, 2-7/8" VAGT Box x Pin + Tubing Pup Joint, T-95, 2-7/8" VAGT Box x Pin + X/O Sub, T-95, 2-7/8" JFE Bear Pin x 2-7/8" VAGT Pin + X/O Sub, T-95, 3-1/2" JFE Bear Box x 2-7/8" JFE Bear Box + Tubing Joint, C-90, 3-1/2" JFE Bear Box x Pin, 2jts + 2.812" SSD (OPEN), T-95, 3-1/2" JFE Bear Box x Pin + Tubing Joint, C-90, 3-1/2" JFE Bear Box x Pin, 10jts + X/O Sub, T-95, 4-1/2" JFE Bear Box x 3-1/2" JFE Bear Pin + Tubing Joint, L80-13Cr, 4-1/2" JFE Bear Box x Pin, 282jts + Tubing Pup Joint, L80-13Cr, 4-1/2" JFE Bear Pin x Pin + Tubing Hanger, Cameron, 4-1/2" API EUE Box top x 4-1/2" JFE Bear Box bottom

25. 3. Release ESP Packer, POOH & L/D Production String Retrieve TWCV. M/U landing joint to TH with safety valve. Back off the lock down screws on tubing spool. Slightly pick up string to 70MT with hook weight 3MT, then start to P/U slowly to weight 76MT, release ESP packer with 6MT overpull. Wait for ESP packer element retract for 30 min. Pick up TH above rotary table. Cut ESP cable below lower pigtail. Check reading. L/D TH. TH in good condition. Penetrator & cable in good condition. Conduct reverse circulation with 1.01SG work fluid 120m³ to kill the well, pump rate 786L/min, pump pressure 315psi, no return. POOH & L/D existing ESP production string to surface. Keep filling well with 1.01SG working fluid 5m³/hr, no return.

26. Tubing Hanger Check TH thread in good condition. TH metal seal need to be grinned to reuse. Rubber seals need to be changed.

27. Tubing Joints All 282 jts 4-1/2" JFE Bear tubing joints found in good condition. All 12 jts 3-1/2" JFE Bear tubing joints found in good condition. All 2jts 2-7/8” JFE Bear tubing joints found in good condition, No thread damage, no bending, erosion with little external/ internal layer of corrosion. Blast joint & all available pup joints as the same as tubing joints, all are in good conditions.

28. Flow Control Device Flow control device was in good condition and no damage Box/Pin thread. 2.812" SSD in OPEN status & good condition.

29. S/L Shifting Tool After open SSD, S/L shifting tools stuck and we had to run S/L cutter to cut line as deep as possible. S/L shifting tool recovered at 3-1/2” tubing joint at 2,763m, 96m above the 2.812" SSD.

30. 6-5/8" ESP Packer ESP Packer seals/rubber were damaged

31. 4. Scrape & Drift 6-5/8" Liner 20 th − 27 th May 2023: 6-5/8" Liner Scraping String: 5-1/2" Tri-cone Bit (without nozzle) + X/O (3-1/2''REG B x NC38 B) + DP 3-1/2" G105 13.3ppf IF Box x Pin, 1jt + Junk basket x 2 + 3-1/2" DP Pup Joint + 6-5/8" Scraper + DP 3-1/2" G105 13.3ppf IF Box x Pin, 1jt + 6-5/8“ ESP Packer Drift Sub + 3-1/2" DP Pup Joint + 4-3/4″ Jar + 4-3/4" DC X 6 joints + 3-1/2" DP to surface.

32. 4. Scrape & Drift 6-5/8" Liner Note: Keep filling well with 1.01SG working fluid 5m³/hr, no return. Change pipe ram to 3-1/2". P/test 3-1/2" pipe ram & annular preventor, OK. Install wear busing. M/U & RIH 6-5/8"Liner scraping string to 756m. Wait on repair rig electrical power cut. Resume M/U & RIH 6-5/8"Liner scraping drillstring to 1726m. Stop operation due to oil flow through drillpipe. Bullhead down with 1.01SG working fluid, 20m3 string & 70m3 annulus with 0 to 400psi pump pressure. Observe the well & flow check for half an hour, OK. Cont. M/U & RIH 6-5/8"Liner scraping string to 2116m.

33. 4. Scrape & Drift 6-5/8" Liner R/U return flow line & connections and switch rig pump to trip tank pump to fill up the annulus. Resume M/U & RIH 6-5/8"Liner scraping string to 2575m. Slip & cut 20m drilling lines. Wait on repair of mud pump electrical power connections. Resume M/U & RIH 6-5/8"Liner scraping string to 2777m. Stop operation due to blocked road & not having enough water. Wait on repair electrical connections for mud pumps & drawworks M/U & RIH 6-5/8" Liner scraping string to 3075m & scrape RTTS & ESP packer setting depths

34. 4. Scrape & Drift 6-5/8" Liner Conduct 50m3 forward circulation down string with 1.01SG working fluid, no return. Conduct 80m3 reverse circulation down annulus with 1.01SG working fluid, no return. POOH & L/D 6-5/8"Liner scraping string to the surface Scraper & Junk sub in clean conditions, no debries

35. 5. RIH acidizing string with 6-5/8″ RTTS packer 27 th May − 1 st June 2023: Acidizing & Flowback String: Mule Shoe, 2-7/8" JFE Bear Box up + Tubing Joint, 2-7/8" JFE Bear Box x Pin, 16jts + X/O Sub, 2-7/8" EUE Box × 2-7/8" JFE Bear Pin + 6-5/8" RTTS Packer , 2-7/8" EUE Box × Pin + X/O Sub, 3-1/2" VAM TOP Box × 2-7/8" EUE Pin +Tubing Pup Joint, 3-1/2" VAM TOP Box × Pin + Tubing Joint, 3-1/2" VAM TOP Box × Pin, 59jts + X/O Sub, 4-1/2" VAM TOP Box x 3-1/2" TOP Pin + Tubing Joint, 4-1/2" VAM TOP Box × Pin, 236jts + Tubing Pup Joint, 4-1/2" VAM TOP Box × Pin + Tubing Pup Joint, 4-1/2" VAM TOP Box × Pin + Tubing Joint, 4-1/2" VAM TOP Box × Pin, 1jt Note: Keep filling well with 1.01SG working fluid 5m³/hr, no return.

36. 5. RIH acidizing string with 6-5/8″ RTTS packer Change to 4-1/2" pipe ram and P/test, OK. --- 300 psi for 10min & 3500psi for 15min. R/U BHDC TRS & Jam system. M/U & RIH acidizing & flowback string to 156m. --- Keep filling well with 1.01SG working fluid 5m³/hr, no return. --- Check tubing thread condition & drift by API standard drift --- Use BHDC TRS & JAM systems to monitor & control M/U torque. Work on power connection from generator to drawworks & pumps. Resume M/U & RIH acidizing & flowback string to 2462m Repair drawworks band brake calibration. Resume M/U & RIH acidizing & flowback string to 2661m. Repair the rig. Resume M/U & RIH acidizing & flowback string to 3082.45m

37. 5. RIH acidizing string with 6-5/8″ RTTS packer Work on acidizing & flowback string to run into 4" perforation liner, no success. Set RTTS packer at 2924.911m. --- End of acidizing & flowback string at 3079.822m, P/U weight 46T. --- Rorate string 2 turn to right hand & slack off 7T per RTTS PKR Engineer Fill up the annulus with 20m3 of 1.01SG working fluid. P/test 6-5/8" RTTS PKR from annulus, OK. --- 300psi for 5min & 1500psi for 15min

38. RTTS PKR P/test

39. Acidizing & Flowback WBS

40. 6. Conduct acidizing & flow back operation 1 st ─ 9 th June 2023: R/U CT equipment, acidizing pump, acid tank, and flowback equipment. Connect pumping lines from pump to CTU. Wait on stimulation treatment fluids. Receive 1 st load of stimulation treatment fluids, 5 tankers. Wait on 2 nd load of IDC stimulation treatment fluids. Prepare & mix treatment fluids by IDC pumping crew. Hold PJSM and HSE meeting with relevant personnel on well site. Flush 1.75" CT with 6 m³ of fresh water. M/U BHA and conduct 15klbs pull test on connector. P/T to 1000psi, 3000psi for 5 min & to 5500psi for 15 min, Ok.

41. 6. Conduct acidizing & flow back operation Perform CT Pipe Pickling as following: --- Pumping 5% HCL 5bbls (0.8m³), Pump rate=0.8bpm, Pump pressure=647-696psi. --- Pumping Displacement fluid 35bbls (5.6m³), Pump rate=1.0bpm, Pump pressure=1128-1404psi. Open the well, RIH 1.75" CT to 3679m. --- Perform pull tests & break circulation with fresh water every 500m. RIH 1.75" CT to 2368.4m, observe 2T slack off at 2368.4m, attempt to get through the obstruction point while pumping treated water, with success, Pump rate 0.8-1.2bbl/min. Continue RIH 1.75'' CT to 3679m while pumping treated water, Pump rate 0.8bbl/min, total pump treated water 100bbls.

42. 6. Conduct acidizing & flow back operation Perform acidizing operation for Asmari unit A with 1.75" CT as approved program as follow: --- Pump Preflush 130bbls (20.7m³), Pump rate=1.0-1.5bpm, Pump pressure=517-2918psi, WHP=0psi. --- Pump 15% HCL 35bbls (5.6m³), Pump rate=1.5bpm, Pump pressure=2354-2979psi, WHP=0psi. --- Squeeze 15% HCL 805bbls (128m³) and 15% VDA 735bbls (116.87m³) alternately, Pump rate=1.5-1.7bpm, Pump pressure=632-4138psi, WHP=0-156psi. --- Squeeze Over-flush 200bbls (31.80m³), squeeze Fresh water 35bbls(5.6m³). Pump rate= 1.7bpm, Pump pressure= 3739-4000psi, WHP= 0psi --- Bullheading fresh water 100bbls(15.9m³) through CT annulus. React with formation for 2hrs, meanwhile POOH CT to 1500m.

43. Acidizing Operation Curve

44. 6. Conduct acidizing & flow back operation Conduct Gas Lifting & Flowback Operation. --- Gas lift by Pumping N2 Through CT & Record Flow Back data every 0.5 hour. --- Last Flow Back parameters: CT depth=2000m, Choke size=50/64", N2 Pumping Pressure=1387psi, N2 FR=1201m³/hr, --- WHP=204psi, Back Pressure=91psi, BSW=60% water, PH=6, WHT=44℃, H2S=0PPM, Flow Rate= 1411.68BFPD, Cumulative Volume: 6262.01bbls . P/U 51T to release RTTS packer.Wait half of hour to retract rubber of packer.Close annular BOP, Reverse Circulation with 1.5 times well bore of kill fluid.PP:174psi, FR:500L/Min, no return. POOH aciding and flowback string to surface.

45. 7 . M/U and RIH ESP production string. ESP production string BHA: 5.50" Motor Guide + Base Gauge + Motor + Lower protector + Upper protector + Pump Intake+AGH + Lower Pump + Upper Pump + DPS + Discharge Head + 2-7/8" OD VOM TOP Tubing Joint, 1 joint + Baker 2.250" GR Profile Landing Nipple + 2-7/8" OD Blast Joint + 2-7/8" OD VOM TOP Tubing Joint, 2 joints+ Baker 2.250" SSD (Closed) + 2-7/8" OD VOM TOP Tubing Joint, 1 joint + Praxis ESP Retrievable Packer, for 6-5/8" OD 20-28ppf casing + X/O Sub, 3-1/2" OD VOM TOP Box x 2-7/8" OD VOM TOP Pin + 3-1/2" OD VOM TOP Tubing Joint x 2 joints + Baker 2.810" F Profile SSD (Open)+3-1/2" OD Tubing Joint, L80-13Cr, 9.20ppf, 3-1/2" OD 9.20ppf VAM TOP Box × Pin, (10 Jts)+X/O Sub, L80-13Cr, 4-1/2" OD 12.6ppf VAM TOP Box x 3-1/2" OD 9.20ppf VAM TOP Pin+4-1/2" OD Tubing Joint, L80-13Cr, 12.6ppf, 4-1/2" OD 12.6ppf VAM TOP Box × Pin , (283 Jts)+X/O Sub, L80-13Cr, 4-1/2" OD 12.6ppf JFEBear Box x 4-1/2 " OD 12.6ppf VAM TOP Pin+Tubing Hanger, Cameron, 11" x 4-1/16", 4-1/2" API EUE box top x 4-1/2" JFE Bear box bottom.

46. 8.Land TH into tubing spool Land TH into tubing spool smoothly.the penetrator was damaged when R/D BOP. M/U BOP and change penetrat or.

47. 9.N/D BOP, N/U X-mas tree and P/T 1. X-mas tree P/T integrity 2. TH sealing and ring gasket 3. Set packer

48. 10.S/L to set ESP packer Bleed off the pressure slowly as engineer' instruction.

49. 11.SPIN TEST

50. FQCS-50H ESP Workover Summary General Information Operational Procedures Design Time versus Actual Time X-Mas Photo

51.  Estimated vs Actual Progress

52. Estimated vs Actual Progress

53.  Final schematic FQCS-50H_Oil Producer_ESP Workover_Final Diagram

54. FQCS-50H ESP Workover Summary General Information Operational Procedures Design Time versus Actual Time X-Mas Photo

55. X-Mas tree

56. THANKS