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202-076
' RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERA S MAY 21 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations s t . Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Ap o r r Plug for Redrill 0 Perforate New Pool 0 Repair Well Il Re-enter Susp Well 0 Other:Surface Excavation ' IBJ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-076 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22953-01-00 7. Property Designation(Lease Number): ADL 028297 8. Well Name and Number: PBU P1-18A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 10641 feet Plugs measured None feet true vertical 9236 feet Junk measured None feet Effective Depth: measured 10538 feet Packer measured 9740 feet true vertical 9151 feet Packer true vertical 8470 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 4463 9-5/8" 27-4491 27-4477 5750 3090 Intermediate Production 10597 7" 26-10623 26-9222 7240 5410 Liner Perforation Depth: Measured depth: 10070-10438 feet SCANNED JUN 1 1 V8 True vertical depth: 8757-9068 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-9797 24-8520 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Hydro Set Packer 9740 8470 true vertical depth) i 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 738 1776 5533 2137 630 Subsequent to operation: 716 4116 6675 1964 610 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-215 Authorized Name: Worthington,Jessica Contact Name: Worthington,Jessica Authorized Title: Well Intervention ngeer Contact Email: Jessica.Worthington(rD_bp.com f// Authorized Signature: c t"\J1á1JZ1'(1 5/IfiK Contact Phone: +1 907 564 4281 Form 10-404 Revised 04/2017 6',./ I//5/ RBDM MAY 2 4 1018 iv/� Submit Original Only • • Daily Report of Well Operations P1-18A ACTIVITYDATE SUMMARY ***WELL SHUT IN ON ARRIVAL***(secure) DRIFTED W/3.76" WRP DRIFT CLEANLY TO 8,300' SLM SET 4 1/2" SS CATCHER 8,246' SLM 6/12/2017 ***CONT WSR ON 6/13/17*** COST PLACEHOLDER SET 4 1/2" WRP W/ HES DPU @ 8246' MD. 12/24/17: WFD WRP MONTHLY RENTAL FOR 06/30/17 - 12/29/17 MO 2, 3, 4, 5, 6, 7 (CF) 01/23/18: COST UPDATED AS NEEDED Per a few SORAC pricing discrepancies in the original ticket (WEATHERFORD OPS SUPERVISOR) (CF) 02/11/18: WFD WRP MONTHLY RENTAL FOR 12/30/17 -02/28/18. MO 8, 9 (MM) 03/17/18: WFD WRP MONTHLY RENTAL FOR 03/01/18 - 03/30/18. MO 10 (CF) 04/21/18: WFD WRP MONTHLY RENTAL FOR 04/01/18 - 04/17/18. MO 11 (CF) FINAL 6/13/2017 04/17/18: PULL 4-1/2"WFD WRP FROM 8,246' MD (All intact) T/I/O = 1870/1830/Vac. Temp = SI. Bleed TP (SL request). No wellhouse, flowline, scaffold or hydraulics. Drilling scaffold on well. Bled TP from 1870 psi to 1272 psi (all gas) in 2 hrs 20 min. Monitor for 30 min. Tbg increased 15 psi during monitor. FWHPs = 6/13/2017 1287/1530/vac. ***CONT WSR FROM 6/12/17*** (secure well) PULLED BK-S/O FROM STA#3 © 8,210' MD SET BEK-FLOW SLEEVE IN STA#3 @ 8,210' MD PULLED EMPTY 4 1/2" SS CATCHER FROM 8,246' SLM. SET 4 1/2" WRP W/ HES DPU @ 8246' MD. 6/13/2017 ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** T/I/O= 1300/1540/0. Circ out(Secure Well) Pumped 5 bbls 50/50 methanol, followed by 340 bbls of 9.8 brine down tbg. Taking returns up IA and to P1-13 flowline. Pumped 20 bbls diesel down tbg to freeze protect TxIA after U tube. CMIT TxIA**PASSED**to 2829/2841 psi. Max applied pressure = 3000 psi. Target pressure = 2700 psi. Pumped 1.53 bbsl of dsl down tbg to reach test pressure. 15 min loss T/IA 20/19 psi, 30 min loss T/IA 18/18 psi. Bled back 2.5 bbls. Pumped 8 bbls of 50/50 methanol down P1-13 FL to FP. 6/15/2017 SV,WV,SSV=closed IA,OA=OTG FWHP=15/42/0 Hung AFE sign on well. T/I/O =Vac/10/0+. Temp = SI. TBG & IA Fluid Depression w/ N2 (Surface CSG leak). Wellhouse removed. Flow line disconnected. Drill scaffold installed. TBG & IA FL @ surface. Bled WHPs to BT to 0 psi. Used 3 bottles of N2 to depress 5 bbls of fluid down the TBG, taking returns through the IA. Allow TBG & IA to U Tube for 1 hr. TBG FL @ 150' (2.3 bbls). IA FL @ 160' (2.8 bbls). Bled WHPs to 0 psi. Monitor for 30 min. WHPs & FLs unchanged. FWHPs = 0/0/0. 6/17/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:00 Surface CSG Excavation & Repair. No work performed. 6/17/2017 Cost of Excavation Shoring Box for June 16 to June 17. Surface CSG Excavation & Repair. No work performed. 6/24/2017 Cost of Excavation Shoring Box for June 18 to June 24. T/I/O = 0/0/0. (Dry hole conversion). Set 4" H TWC#431 @125", Performed LTT on TWC (Pass). RD upper tree, RU Temp#31, PT'd 5000 PSI (Pass). RDMO. ***Job Complete***. 6/24/2017 FWPs = TWC/0/0. See log for details. Surface CSG Excavation & Repair. No work performed. 6/26/2017 Cost of Excavation Shoring Box for June 25 to June 26. • i Daily Report of Well Operations P1-18A T/I/O = TWC/0/0. Temp = SI. Surface CSG Repair. Staged equipment. Began building gravel ramp for cuttings box containment. 6/27/2017 SV= C. MV= 0. IA, OA= OTG. 17:30. T/I/0 = TWC/0/0. Temp = SI. Surface CSG Repair. Continued building gravel ramp for cuttings box containment. 6/28/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 T/I/0 = TWC/0/0. Temp = SI. Surface CSG Repair. Complete building gravel ramp for cuttings box containment. WS builds Cuttings Box containment and RU Dewatering tank. Used Watson Drill Rig to drill -5' of Dewatering hole, SD do to signs subsidence. Backfilled Dewatering hole and raised pad behind wellhouse. 6/29/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 T/I/0 = TWC/0/0. Temp = SI. Surface CSG Repair. Placed rig mats on the ramp to cuttings box. Began excavation around cellar box and pulled box. Found another CMP cellar box below the first one and pulled it. Set Dewatering CMP to a depth of-9'. 6/30/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 T/I/O = TWC/0/0. Temp= SI. Surface CSG Repair. Cleaned out cuttings box and organize around site. Excavate gravel to expose well float. 7/1/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 T/I/O = TWC/0/0. Temp = SI. Surface CSG Repair. Set up area for Hot Work. Pre Hot Work Open Flame meeting with crew, WSL, BP Safety, LPC OSM, LPC OTL. Cut float from around wellhead with a torch while maintaining an N2 purge on the OA. BP Safety monitored the OA returns during N2 purge-CO = 0, H2S = 0. LELs = 0. 02 = 0.7. Used excavator to pull concrete from around well. 7/2/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 T/I/0 = TWC/0/0. Temp = SI. Surface CSG Repair. Set up Dewatering from Dewatering CMP. Level gravel around wellhead. Set up Shoring Box system. Begin Hydro Excavation around wellhead. 7/3/2017 SV= C. MV= 0. IA, OA= OTG. 17:00 T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation. Uninstalled & Reinstalled shoring box&excavated cellar. Excavated cellar to-9'. 7/4/2017 SV, MV= C. IA, OA= OTG. 18:00. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation. Installed Rig Mats around shoring box. Excavated cellar gravel - 5'. 7/5/2017 SV= C. WV= C. IA, OA= OTG. 20:00. T/I/0 = TWC/0/0. Temp = SI. Surface CSG Repair. Excavated cellar to 13' 1"from bottom of OA. 7/6/2017 SV= C. MA= C. IA, OA= OTG. 18:30. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation. Excavated cellar to 14' unable to go deeper due to cement @ 9 o'clock position under the shoring box wall. 7/7/2017 SV, MV= C. IA, OA= OTG. 18:00. T/I/O =TWC/0/0. Temp= SI. Surface CSG Excavation. Removed rig mats around shoring box& backfilled the subsidence around shoring box. 7/8/2017 SV, MV= C. IA, OA= OTG. 18:00 7/9/2017 SUrface casing repair-Job clean up and RDMO. Job on temp hold Surface CSG Excavation & Repair. No work performed. 7/15/2017 Cost of Excavation Shoring Box for July 10 to July 15. Surface CSG Excavation & Repair. No work performed. 7/22/2017 Cost of Excavation Shoring Box for July 16 to July 22. Surface CSG Excavation & Repair. No work performed. 7/27/2017 Cost of Excavation Shoring Box for July 23 to July 27. • Daily Report of Well Operations P1-18A T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation. Pumped -300 bbls of water out of excavation hole to the Tiger Tank. Began to dig gravel up behind well to build back up with compacted lifts for WSS rig mats. 7/28/2017 SV, MV= C. IA, OA= OTG. 17:45 Surface CSG Excavation & Repair. No work performed. 7/29/2017 Cost of Excavation Shoring Box for July 29. Surface CSG Excavation & Repair. No work performed. 8/4/2017 Cost of Excavation Shoring Box for July 30 to August 4. T/I/O = TWC/O/O. Temp = SI. Surface CSG Excavation & Repair. Build up pad at 12 o'clock position & level. Installed ramp @ the 6 O'clock position for excavator& removed 3 panels. Removed cement from casing w/excavator. Will need to use a jack hammer to remove remaining cement. Installed hand rails on shoring box. 8/5/2017 SV, MV= C. IA, OA= OTG. 18:00. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. Leveled pad @ the 12 &6 o'clock positions for WSS rig mats. 8/6/2017 SV, MV= C. IA, OA= OTG. 18:00. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 8/7/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 8/8/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 8/9/2017 SV, SV= C. IA, OA= OTG. Surface CSG Excavation & Repair. No work performed. 8/12/2017 Cost of Excavation Shoring Box for August 7 to August 12. 8/16/2017 T/I/O = Surface CSG Excavation & Repair. No work performed. 8/19/2017 Cost of Excavation Shoring Box for August 13 to August 19. Surface CSG Excavation & Repair. No work performed. 8/26/2017 Cost of Excavation Shoring Box for August 20 to August 26. Surface CSG Excavation & Repair. No work performed. 9/2/2017 Cost of Excavation Shoring Box for August 27 to September 2. T/I/O = TWC/O/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/3/2017 SV, SV= C. IA, OA= OTG. TWO = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/4/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp= SI. Surface CSG Excavation & Repair. No work performed. 9/5/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/6/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/7/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/O/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/8/2017 SV, SV= C. IA, OA= OTG. Surface CSG Excavation & Repair. No work performed. 9/9/2017 Cost of Excavation Shoring Box for September 3 to September 9. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/10/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/11/2017 SV, SV= C. IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. No work performed. 9/13/2017 SV, SV= C. IA, OA= OTG. S • Daily Report of Well Operations P1-18A Surface CSG Excavation & Repair. No work performed. 9/15/2017 Cost of Excavation Shoring Box for September 10 to September 15.. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. SIM OPS with Rig Site Control. Mobed 32 1yd bags of pea gravel on pallets. Staged on edge of pad in staging area by Rig. 9/16/2017 SV, MV= C. IA, OA= OTG. 17:30 Surface CSG Excavation & Repair. No work performed. 9/18/2017 Cost of Excavation Shoring Box for September 18. T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. SIM OPS with Rig Site Control. DeWater excavation hole with Vac trucks.. Use Super Sucker to clean silt out of bottom of hole. Continue Dewateringthroughnight. the ni ht. 9/19/2017 SV, MV= C. IA, OA= OTG. 19:00 T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. SIM OPS with Rig Site Control. Continue dewatering. Placed 2 layers of industrial fabric in bottom of dewatering hole. Placed 6" of pea gravel on top of fabric to stabilize excavation hole floor. Continue Dewateringthroughnight. the ni ht. 9/20/2017 SV, MV= C. IA, OA= OTG. 17:00 T/I/O = TWC/0/0. Temp = SI. Surface CSG Excavation & Repair. SIM OPS with Rig Site Control. Continue dewatering. Lifted 8'x15' CMP with crane, swung over wellhaed and lowered to floor of excavation hole. Lifted Icy Super Sacks of Pea gravel, swung them over the excavation hole, pulled bottom ties and poured the gravel into the excavation hole between the shoring box and CMP for backfill. 9/21/2017 SV, MV= C. IA, OA= OTG. 17:00 Surface CSG Excavation & Repair. No work performed. 9/22/2017 Cost of Excavation Shoring Box for September 22 to September 23. Surface CSG Excavation & Repair. No work performed. 9/24/2017 Cost of Excavation Shoring Box for September 24 to September 30. Surface CSG Excavation & Repair. No work performed (Safety Stand Down). 10/1/2017 Cost of Excavation Shoring Box for October 1 to October 3. Surface CSG Excavation & Repair. No work performed. 10/4/2017 Cost of Excavation Shoring Box for October 4 to October 9 . Surface CSG Excavation & Repair. No work performed. 10/10/2017 Cost of Excavation Shoring Box for October 10 to October 14 . Surface CSG Excavation & Repair. No work performed. 10/15/2017 Cost of Excavation Shoring Box for October 15 to October 21. Surface CSG Excavation & Repair. No work performed. 10/22/2017 Cost of Excavation Shoring Box for Sunday, October 22 to Saturday, October 28. T/I/O = SI/0/0. Temp = SI°. Wireless install (WOLP). Installed and pressure tested wireless pressure gauges on IA/OA. FCO complete and ready to turn over to Operations. SV, WV, SSV= C. MV= O. IA, OA= OTG. 1700 hrs. 10/22/2017 Surface CSG Excavation & Repair. No work performed. 10/29/2017 Cost of Excavation Shoring Box for Sunday, October 29 to Saturday, November 4. Surface CSG Excavation & Repair. No work performed. 11/5/2017 Cost of Excavation Shoring Box for Sunday, November 5 to Saturday, November 11. Surface CSG Excavation & Repair. No work performed. 11/12/2017 Cost of Excavation Shoring Box for Sunday, November 12 to Saturday, November 18. Surface CSG Excavation & Repair. No work performed. 11/19/2017 Cost of Excavation Shoring Box for Sunday, November 19 to Saturday, November 25. Surface CSG Excavation & Repair. No work performed. 11/26/2017 Cost of Excavation Shoring Box for Sunday, November 26 to Saturday, December 2. • Daily Report of Well Operations P1-18A Surface CSG Excavation & Repair. No work performed. 12/3/2017 Cost of Excavation Shoring Box for Sunday, December 3 to Saturday, December 9. Surface CSG Excavation & Repair. No work performed. 12/10/2017 Cost of Excavation Shoring Box for Sunday, December 10 to Saturday, December 16. Surface CSG Excavation & Repair. No work performed. 12/18/2017 Cost of Excavation Shoring Box for Sunday, December 18 to Saturday, December 24. Surface CSG Excavation & Repair. No work performed. 12/18/2017 Cost of Excavation Shoring Box for Sunday, December 11 to Saturday, December 17. Surface CSG Excavation & Repair. No work performed. 12/27/2017 Cost of Excavation Shoring Box for Sunday, December 25 to Saturday, December 31. Surface CSG Excavation & Repair. No work performed. 12/27/2017 Cost of Excavation Shoring Box for Sunday, December 18 to Saturday, December 24. Install heater in cellar(pre SC repair). No wellhouse. Installed heater in cellar and covered with visqueen to thaw. 16:00 hrs. 2/7/2018 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took CSE and Scaffold permits Live. Crew performed snow removal on the pad and set up work area. Brand Scaffold Crew began scaffolding set up in excavation hole. Scaffold frame complete, crew will assemble decking tomorrow. 2/11/2018 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took CSE and Scaffold permits Live. Brand Scaffold Crew complete scaffolding set up in excavation hole. 2/12/2018 Scaffold inspected by Bob Carmichael. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. HWOF &CSE Permits (LIVE). BP Safety Terry Hunt sniffs & inspects scaffolding. Use Circular Saw to cut CMP @ 9 o'clock position for access to ladder/OA CSG valve. DHD maintained N2 purge for 45 min & installed N2 cap @ 10 psi. 2/14/2018 IA, OA= OTG. 18:00. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. HWOF & CSE Permits (LIVE). BP Safety Tim Hunt sniffs & inspects scaffolding. DHD maintains OA N2 purge. Pulled circ port and inspected cement for upper window(dry with no fluid). Drilled holes into lower conductor @ 9 o'clock position for window @ 0", 6", 12", 18" (very small amount of fluid @ bottom of window). Window measurements from middle of OA CSG valve, top of upper window @ 32.5", bottom @ 50.5". Lower window measurments from middle of OA CSG valve @ top of lower window @ 120.5", bottom @ 139.5". Cut 18"x18" window's into upper& lower conductor& remove/clean cement for UT inspection. DHD installed N2 cap on OA @ 10 psi. 2/15/2018 IA, OA= OTG. 20:00. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Mistras UT'd upper& lower windows. 2/16/2018 IA, OA= OTG. 12:00. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. HWOF & CSE Permits (LIVE). BP Safety Tim Hunt sniffs & inspects scaffolding. DHD maintains OA N2 purge. 18 " remaining on vertical cut on the conductor @ the 12 o'clock position. Vertical cut on the 6 o'clock position is completed. Wellhead dropped 1" after cut 6 o'clock was completed (Stopped the job) & Notified town engineer. Made multiple measurements & marks to monitor for movement overnight. 2/17/2018 IA, OA= OTG. 18:00. • • Daily Report of Well Operations P1-18A T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. HWOF &CSE Permits (LIVE). BP Safety Tim Hunt sniffs & inspects scaffolding. DHD maintains OA N2 purge. Used Hydraulic flange spreader on the conductor 6 o'clock position to Pry open conductor and wellhead dropped 3/4" (Stopped the job).. Evaluated the use of the Well 2/18/2018 Support Structure. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Snow removal for WSS. 2/19/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No work performed. 2/20/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No work performed. 2/21/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Removed snow& built gravel pads for WSS. Scaffolding modified &adjusted for tree removal & knuckle installation. 2/22/2018 IA, OA= OTG. 18:00. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No work performed due to weather. 2/23/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Snow Removal & check on equipment.. 2/24/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No work performed due to weather Phase 3. 2/25/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No work performed unable to make it to location. 2/26/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Crew did snow removal on pad and around well. 2/27/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Well Support BPV Crew removed Dry Hole Tree and THA. Installed WSS Knuckle on well in preparation for installing the Well Support Structure. Wellhead was taken to Well Support API Shop Valve 2/28/2018 Tent. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Did snow removal around well. Rigged up the Well Support Structure to the 2250 Crane. Lifted WSS and placed over the well. 3/1/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Attempted to cycle jacks on Well Support Structure but was unable to move them, possible icing. Put parachutes and heaters around jacks and motors. Adjusted the Iron Cross. 3/2/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Worked on Well Support Structure. 3/3/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Encoder C not functioning, measured by hand. Adjusted WSS for attaching Iron Cross and Bonnet. Flew in IC and bolted up to Knuckle on well. Raised WSS to IC. Flew in Bonnet and bolted it up on WSS to secure IC. Did a Tare on the WSS weights to zero them out. Raised WSS up to put 20 KIPS of pull on well. EncoderA=11.42, B=11.53, C=11.26, D=11.1 3/4/2018 IA, OA= OTG. 17:30 • Daily Report of Well Operations P1-18A T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Opened Civil, CSE & HWOF permits. Did N2 purge, LELs=0, 02=<1% at bleed tank. Crew cuts conductor off to -11' below OA CV. Found 2 leaks @ -3.6'. Will clean off the remaining cement and clean up the OA casing to see if there are any more leaks. 3/5/2018 IA, OA= OTG. 18:15 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Opened Civil, CSE & HWOF permits. Temporarily plugged the 2 holes discovered yesterday. Did N2 purge, LELs=0, 02=<1% at bleed tank. Crew pulls remaining concrete off of casing and cleans casing with a wire wheel. Put 20 psi on OA with N2. Used soapy water to locate any leaks on casing down to the 11' mark. No other leaks detected. The 2 holes found yesterday are @ -3' 7" below the bottom of the OA casing valve. Work area cleaned up. 3/6/2018 IA, OA= OTG. 17:30 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/7/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/8/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/9/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. 3/10/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/10/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/11/2018 _ IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/12/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/13/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/14/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/15/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Apllied Bake Lok to the 2 holes in the surface casing @ the 9 o'clock position. Installed heater&adjusted trunk to point @ Baker Lok for curing process. 3/16/2018 IA, OA= OTG. 18:00. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Welders reverified measurements for sleeve. N2 IDLH testing, maintained N2 OA purge for 3 hr atmospheric test. During test maintained LEL = 0%, CO = 0%, H2S = 0%, 02 = 20.9%. 3/17/2018 IA, OA= OTG. 16:00. • S Daily Report of Well Operations P1-18A T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/18/2018 IA, OA= OTG. T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/19/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. Staged non-mobile equipment for upcoming work. 3/20/2018 IA, OA= OTG _ T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/21/2018 IA, OA= OTG T/I/0 = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/22/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Issued HWOF & CSE permits. RU OA N2 purge. Work was shut down due to CSE safety concerns of Emergency Response time. 3/23/2018 .IA, OA= OTG 12:00. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots & replaced encoder on platform C. 3/24/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/25/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/26/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/27/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened new Non-Routine Snow Removal permit. Cleaned snow around well and WSS. Cleaned snow on the pad. 3/28/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. No Permitted Work performed today. Took Well Support Structure screen shots. 3/29/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Issued HWOF, Civil &CSE permits. RU OA N2 purge. Emergency Response team on location. OA returns @ BT - H2S=0 ppm, CO=50 ppm, LELs=6.2%, 02=<1%. Welders attached top welding band and welded vertical welds on band. Tack welded thermal couples on top band for Electricians to RU heat pads. Heat pads are attached on the upper band. Strapped OA to 17'+ below OA valve with no liquid. 3/30/2018 IA, OA= OTG 19:00 • Daily Report of Well Operations P1-18A T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Issued HWOF & Civil permits. RU OA N2 purge. Emergency Response team on location. OA returns @ BT- H2S=0 ppm, CO=80 ppm, LELs=8.2%, 02=<1%. Platform weight= 42.8 KIPS -A=11.1, B=11.3, C=12.5, D=7.8. Electricians did Pre-Heat and 4hr Bake Out upper band. Platform weights = 20.5 KIPS -A=5.7, B=5.9, C=4.9, D=4.0. Welders attach bottom band and do vertical welds. Welders do top and bottom circumference welds on top band. 2 hr Post Weld Bake Out. Electricians wrap the heat blanket on the bottom band. 3/31/2018 IA, OA= OTG 19:00 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened Non-Routine Snow Removal permit. Cleaned snow around well and WSS. Cleaned snow on the pad. 4/1/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE & Non-Routine Snow Removal permits. Cleaned snow around well, WSS & pad. Electricians remove heat pads from top band and RU &test bottom heat pads. 4/2/2018 IA, OA= OTG 17:30 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE & HWOF permits. Electricians heat lower band and do a 4 hr Bake Out. Welders grind off the thermal couples on upper band and clean up. Welders weld top and bottom circumference on bottom band. Did a 2 hr post weld Bake Out. 4/3/2018 IA, OA= OTG 18:45 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Had to standby due to SIM OPS issues with SL on P1-09. Opened CSE & HWOF permits. Electricians pull all of there heat pads and cords from excavation hole. Welders grind of thermal couples and buff bottom band. Century Inspection did Mag Test on both collars. Crew&Welders place the Casing Ssleeve halves in the cellar. 4/4/2018 IA, OA= OTG 17:00 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE & HWOF permits. Welding Crew completes the vertical welds on the Casing Sleeve. 4/5/2018 IA, OA= OTG 17:15 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE & HWOF permits. Welding Crew completes the circumference welds on the Casing Sleeve. Century Inspection did Mag Testing on Casing Sleeve welds. 4/6/2018 IA, OA= OTG 17:00 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE & Civil permits. AOGCC inspects Casing Sleeve welds. Wrapped surface casing with Denzo wrap and greased the seams. Performed Man Down & Rescue Drill with Beacon Emergency Response Team. Placed Conductor Sleeves in hole and strapped them into place. 4/7/2018 IA, OA= OTG 16:00 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE &Civil permits. Welders attach and weld Conductor Sleeves. Cut off the top of the CMP (culvert) to make level around the top of the excavation hole. 4/8/2018 IA, OA= OTG 16:00 • • Daily Report of Well Operations P1-18A T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Opened CSE & Civil permits. Scaffolding Crew breaks down and removes scaffolding from Excavation Hole. Jewelry is replaced on the OA and Control and Ballance lines. Crew cleans up around work area. 4/9/2018 IA, OA= OTG T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Took Well Support Structure screen shots. Remove Bonnet&Vertical support member. Lowered WSS & installed travel bolts. Installed heaters to thaw rig mats for removal. IA, OA= OTG. 19:00. 4/10/2018 T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Removed WSS & loaded on SOW. Unable to excavate around shoring box, gravel is frozen. Hooched around shoring box& bake overnight. 4/11/2018 IA, OA= OTG. 18:00. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Excavated around shoring box w/Super Sucker. Removed 4 panels from shoring box. Removed 2' CMP from sump hole @ 3 o'clock position. Backfilled 8' CMP w/gravel, Final cellar depth @ 26". Begin to build pad up for grade. 4/12/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Completed snow removal &finished grading gravel. Continue with De-Mobe. 4/13/2018 IA, OA= OTG. T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. De-Mobe &conduct snow removal for S-Riser& Rig scaffolding for TRP. 4/14/2018 IA, OA= OTG. T/I/O=TWC/0/0. Installed THA. FMC performed PPPOT-T (PASSED). RD TEMP#31 . Installed upper tree . Torqued all flanges. RU CIW lubricator#840 with H-plug CIW pulling tool . Stabbed onto tree and PT'd against the TWC . (PASSED) Removed TWC#431 . 4/14/2018 Installed tree cap and PT'd to 500 psi (PASSED) . RDMO***Job Complete*** . T/I/O = TWC/0/0. Temp = SI. Surface Casing Excavation & Repair. Continue De-Mobe of location. 4/15/2018 IA, OA= OTG. ***WELL SHUT IN ARRIVAL***(surface csg excavation) SET 4 1/2" WHIDDON ON WRP @ 8246' MD. 4/16/2018 ***CONTINUED ON 4/17/18 WSR*** T/I/O = SSVNacNac. Temp = SI. AOGCC OA Integrity Test to 1199 psi PASSED (Surface Csg Repair). State waived witness. Used 5 bbls diesel to pressure OAP from a Vac to 1199 psi. Monitored for 5 min. OAP decreased 28 psi and no leaks observed at surface. Bled OAP to 0 psi (1.9 bbls). Tags hung. Final WHPs = SSVNac/0. 4/17/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 17:30 hrs. ***CONTINUED FROM 4/16/18 WSR***(surface csg excavation) PULLED BK-FLOW SLEEVE FROM STA 3 @ 8210' MD AND SET BK-OGLV IN STA 3. PULL 4-1/2" WHIDDON C-SUB FROM 4-1/2"WRP @ 8,246' MD (Empty) EQUALIZE & PULL 4-1/2" WFD WRP FROM 8,246' MD (All intact) 4/17/2018 ***WELL S/I ON DEPARTURE*** PAD OP NOTIFIED JOB COMPLETE &WELL STATUS T/I/O = 600/2100/600. Temp = 150°. WHPs (post SC repair). ALP = 2100 psi and is online. No leaks or anomolies observed. 4/26/2018 SV= C. WV, SSV, MV= O. IA, OA= OTG. 22:30. T/I/O = 640/1990/760. Temp = 142°. WHPs (post SC repair). ALP = 1990 psi, &open @ casing valve. TP increased 40 psi, IAP decreased 110 psi, OAP increased 160 psi, &Temp decreased 8°, since 4/26/18. No leaks or anomolies observed. 4/28/2018 SV= C. WV, SSV, MV= O. IA, OA= OTG. 11:30 • r Daily Report of Well Operations P1-18A T/I/O = 610/1960/50. Temp = 152°. Conductor Top Job (assist SP). ALP = 1960 psi, open @ CV. Used 50 gals of 15.8 lbs cement to fill conductor to 6' below the top of the conductor. Heater installed in well house w/door open. Tree cap bled to 0 psi. 4/29/2018 SV= C. WV, SSV, MV= O. IA, OA= OTG. 13:30 T/I/O = 610/1940/65. Temp = 152°. Conductor Top Job (assist SP). ALP = 1940 psi, open @ CV. Used 56 gals of 15.8 lb class G cement to fill to top of the conductor. Heater removed from wellhouse. 4/30/2018 SV= C. WV, SSV, MV= O. IA, OA= OTG. 15:00 Fluids Summary Gals Type 115 Gal Class 'G' , ,'' k ,',,,,10..„-,,,,,,,,„,,,, 0 . '' ' lit. „yam � b .F *** :ii f ii 41 - 7044:*7''' 47 '81844;4,,8\fr 1 rte' a /a w, ', e a ery moi;, t'2 f \, y Fiit Y � f i s T . j _...e9: r' 4. ' -t.', 11401.:'' ,*.,.- :\..\\ . ,, \ '' '\ ,''' '''':'?)",f \ tt II \ t \Ili , w?�z 4, 744 ,6444 , 4 1 m F ; ` . • • • E iNtliiii' 7j 4' ' ..$" r sdr x -,: Nrt Jt t e rt s?p ,,, a f Ids ,r a<< • fi 4.� 41 • ✓' • 4 M ,„ ,,,'----.. ir.,: -- ,y,,-:::, • l # fl � k N, „....,„\ � � w tt ,..1.\* 4 �ro tea: £ a`s,�': • "„iir r 44 ti y i*'4 } • 4« t R 'ON • , 6 N �' b 2 N w .�,M s;..,:',,,'''.,'. •..;• g % `gam .4 , $ d" _.y-41 ^i , a ,4 �, y- wA M F + ;rA.' t. 4...k ' ,r { t= • rte. y • w . / 00 w A i :01.- r' r r 1 3g s a P. t� � Q -'&`r� � '''''',--t.":„.. �}p 7 'di' � y r R 'fie ^"' t ' 1 ,' , , 4.''',11,;,.. .:*.„'''* , '‘1 t., 1 ik'' 4 . s kms-- IFi= 4-1/16"CNV WELLI-EAD= FAC GEN 5 • P1 —1 8 A Cslit E NOTES**: ES ;""A 4-12-CHROME TBG 8 7- CACTUATOR= BAKER C KB.ELEV= 37.3' BF.8_EV= 8.8' 1744 KOP= 4491' C Max Angle= 48°@ 7540' - 2227' -4-1/2"CAMCO BAL-O SVLN,D=3.813" Datum MD= 10164' • GAS LFT MANDRILS Datum TVD= 8800 SS ST MD IVO DEV TYPE VLV LATCH PORT DATE 20"CONDUCTOR&SURFACE CSG SLEEVE --I8'I 6 4187 4177 7 KBG-2 DOME BK 16 04/13/17 '1 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 93"X 12'X.500"(04/08/18) X) 6797 6248 44 KBG-2 DOME BK 16 04113/17 Minimum ID =3.725" 97$6' 3 8210 7267 42 KBG-2 SO BK 28 04/17/18 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 4-1/2" HES XN NIPPLE 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OF WI If STOCK H 4491' 9-5/8" MILLOUT WINDOW 4491'-4507' ,441414141414141414141414141414' 9-5/8"CSG,40#,L-80,D=8.835" —I 4610' 44.4.44.4.4.1.444.4.1.4.4. 7"CSG,26#,L-80 BTC x0 TO 13CR-80 H 9631' ->( X 1 1 9720' 4-1/2"HES X NP,Cs=3.813" X 9741' -'4-1/2"X 7"BKR S3 PKR,ID=3.875" 1 1 - 9766' ---14-1/2"HES X NI3,ID=3.813" 1 1 - 9786' -14-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR 80,.0152 bpf,ID=3.958" H 9798' - / \- E, 9798' -I-[4-1/2"WLEG,C=3_958 I 9796' H ELMD LOGGED ON 05104/04 PERFORATION SUMMARY REF LOG: 0_4 9838' -7"Ma RICER JOINT ANGLE AT TOP PERF: 31°a 10071' Note:Refer to Production DB for historical pert data SCE SPF INTERVAL Opn/Sgz SHOT _ SOZ 3-3/8" 4 10070-10090 0 05/04/04 3-3/8" 4 10091-10111 0 05/11/03 3-3/8" 6 10205-10220 0 05/19/02 2-7/8" 4 10241-10271 0 05/15/03 33/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428- 10438 0 05/17/02 7"CSG,26#,13CR-80 VA M TOP XO TO L-80 BTC -I 10639' PBTD H 10638' 1/11/1111111111111111 04,414141414.4.444/4/411111111111 7"CSG,26#,L-80 BTC,.0383 bpf,D=6.276" -I 10623' - •yA--- A DATE REV BY DONNE ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 06/23/17 BSE/JMD SET WRP(06/13/17) WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 06/23/17 ZV/JMD GLV C/O(06/13/17) PERMIT No: 2020760 08/15/11 PJC DRAWING CORRECTION 04/12/18 JA/JNO 20"GOND&SURFACE CSG SLEEVE API lb 50-029-22953-01 05/20/15 PJC PERE CORRECTIONS 04/18/18 RCB/JMD GLV C/O&PULLED WRP(04/17/18) SEC 16,T12N,R14E,1394'FSL&880'FEL 03/22/17 JM) MINOR WBS CORRECTK)NS 04/17/17 ZV/JM) GLV C/O(04/13/17) BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, May 20, 2018 10:31 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GPMA Field O&M IL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak, Ops West Area IL;Al', RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Burton, Kaity; Duong, Lea; Sauve, Mark A; Schultz, Kirsten L Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO VN/€11 Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Producer P1-18 (PTD#2020760) Surface Casing Repaired external-email: 0 All, Producer P1-18(PTD#2020760)was made Under Evaluation to put on production and assess the results of the surfacs4 casing repair.The well was brought online on 04/25/18 and follow up monitors by DHD have not produced any visible signs the surface casing is leaking.This proves the success of the repair and the well now meets operability criteria.The well is classified as OPERABLE. Please respond with any questions. Andrew Ogg SCANNED M4 2 22018 Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, GI' s Well Integrity Engineer Sent: Sunday, Apr , 2018 10:10 AM To: AK, OPS EOC Specia' s; AK, OPS GPMA Field O&M TL; AK, OPS GPMA OSM; AK, OPS LPC Board Operator; AK, OP LPC DS Operator; AK, OPS LP 0S Ops Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Burton, Kaity; Duong, Lea Cc: AK, GWO Completions Well Integrity; GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SU T Well Integrity; AK, GWO Well Integrity Well In • ••ation; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, - ic; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Rom., ouis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Producer P1-18 (PTD# 2020760) POP : -valuate surface casing repair r.. All, Producer P1-18(PTD#2020760)was made NOT OPERABLE on 04/19/17 due to a surfacecasi eak.On 04/13/18 excavation and repair sleeve welding was completed on the surface casing in accordance with appy ed Sundry 317-215. On 04/17/18 DHD performed a passing OA integrity test.The well will now be classified as UNDER EVAL TION to put on production and monitor to ensure the surface casing leak has been mitigated. 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 4/,c4 'g DATE: 4/9/2018 P. I. Supervisor Ii FROM: Adam Earl SUBJECT: Casing Sleeve Petroleum Inspector PBU P1-18A BPXA PTD 2020760; Sundry 317-215 4/7/18: I traveled out to PBU P1-18A to witness a 9 5/8" welded surface casing sleeve. Jon Arend was the BP representative on the job. The 20" conductor was cut away from the 9 5/8" casing and the sleeve installed. All welds appeared sealed and looked nicely done. The sleeve was 92 3/8" long. I have attached several pictures from all angles. Attachments: Photos (7) • SCOW 2018-0407_Surface_Csg_PBU_P 1-18A_ae.docx Page 1 of 5 , • • e ", yia t t r .' . % 9 7F t. ,; ., .� R ( W 441)4 U 'b ct i ' p, o boI aa) UIQ , r, �' d . o o - f N f/�3� 00 N r. P,� .. . .... } o Ct. �' . . M ..; fi a CO ' � �` ' t L Q.- m , ._ ; Q x • , u) a - ._. • • .6.' , . ' _ i ! 111 t. '6�x ry t f d ,e t.' a_n: ': C • . IP' 4. 1 x ifU 0 ai 03 I Q `t�.. i \ Q� 4-i '-';:) '; 4.—::";:',-.4'.6..:1*1 00 . ., _,..., . i. ,0., , , 4:41(31V) ¢ei , t t°1 N 4. ,, *Ilk UIQ 1 N oo , 7., / 0 l el -100a11111,"--- �_. 4 .17.\ f , t il ' .,, ; i 11 Z y�� terI/M + ,* 4 0 0.... ,..., .,. •-• , . ''' ' ' \ . . \ ' , \ \ , -•. , >< 0 0 -ci 6 ct I -‹ oc 1..; ,--, ,--. ,r) 1 71- : 00 iiiiii " 11111 cc9 I-, v)I (--- . . cp 7i- (=> 0() ,--, (-4 *1/4 f kaw,ilit , '14 ... . „, . I . , , .. .... . :41 ,.„. .....-, .... 4- .. , ., .. . . , .• . • •,.,,' ;, • 1 - t, • -, , •, • ,- . _ _..,......_ '..•::-:'.-,•Z ',•";,,,:,:, , ,, • II , 0x U O N m QI oo 44 I tn = w �I, 91 a o 0 fli ' ' . -_. 9 .. a4 U CC ; i ,, • .... 0 O aa`'. ** .....4* E.. r kY A3 'a d4 : r i . ILL1/ / / n i , I I 1 I i '. :;" • - • • 4)",\ �OF jj A THE STATE Alaska Oil and Gas N�► ia��, of .� j /� �`L1-1J Conservation Commission - 1-1 ,2___ -- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *M Main: 907.279.1433 .SA Fax: 907.276.7542 www.aogcc.alaska.gov Jessica Worthington Well Intervention Engineer SCANNED JUN 0 5 Fr h BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, PBU P1-18A Permit to Drill Number: 202-076 Sundry Number: 317-215 Dear Ms. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,/ Daniel T. Seamount, Jr. Commissioner f7" DATED this / day of June, 2017. RBDIUIS (A—JUN - 2 20�" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI•N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well ® . Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Surface Excavation 10• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-076 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22953-01-00 • 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I1 PBU P1-18A • 9. Property Designation(Lease Number): 10. Field/Pools: RECEIVED 11 ADL 0028297 - PRUDHOE BAY,PRESENT WELL CONDITION SUMMARY PT MCINTYRE OIL. MAY 2 5 2017 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): AC[�'�ld+lOt■ea/�C 10641 • 9236 , 10539 9152 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 4463 9-5/8"40#L-80 27-4490 27-4476 5750 3090 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 24-9797 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and TVD(ft): 9740, 8470.30 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic EI 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 , Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil I WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington,Jessica be deviated from without prior written approval. Contact Email: Jessica.Worthington@bp.com Authorized Name: Worthington,Jessica Contact Phone: +1 907 564 4281 Authorized Title: Well Intervention Engineer Authorized Signature: Date: LI 5 /� COMMISSION USE ONLY Conditions of approval:Notify C•u fission so that a representative may witness Sundry Number: --/ 3 1 ` 2-16 - 1 5 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance V / / Other: ' l + I Post Initial Injection MIT Req'd? Yes 0 No Dr; Spacing Exception Required? Yes 0 No Subsequent Form Required: 10 --- 4-0 f7 Approved by' / APPROVED BYTHE COMMISSIONER COMMISSION Date: /1 7 1,77573gi'ORIGINAL RBDMS JUN - 2 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. p Attachments in Duplicate f (H( Attachments S723-.•17 • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED MAY 252017 RE: BP Exploration (Alaska), Inc. ACC Report of Sundry Well Operations Summary May 25, 2017 To Whom it May Concern: Attached please find the Sundry Application to do a Surface Excavation to perform a - Surface Casing Repair on P1-18A, PTD # 202-076. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • by 0 Date: May 19, 2017 From: Jessica Worthington, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: P1-18 Surface Casing Excavation Repair Objective This program is intended to guide the execution of a surface casing excavation -- repair. The well will be securely braced by a well support structure, excavated to depth near 15 feet, sleeve welded to straddle the extent of corrosion on casing, pressure tested and then backfilled. Well Detail Current Status: Not Operable Previous Test: MIT-OA to 1200 psi, Fail, Fluid returns to surface Integrity Issues: Surface casing leak -10 feet Relevant History: 5/6/2017 PPPOT-IC passed to 3500 psi 4/13/2017 MIT-IA Passed to 2670 psi, set LGLV in sta#4 &6, set OGLV in sta#3 4/12/2017 Set DGLV in sta#4 &6 2/15/2017 Set LGLV in sta#6&OGLV in sta#4 1/9/2017 LockCem conductor top job 7/12/2015 MIT-OA Failed post wellock treatment, bubbling in conductor 6/27/2015 WellLock conductor top job Procedure: 1 S Secure well 2 V Secure well support structure to THA, remove wellhouse and flowline 3 SP Excavate well per engineered plan to depth near 15 feet 4 SP Cut windows in conductor to ensure corrosion is straddeled; remove h v�"� conductor; notify AOGCC inspector for opportunity to inspect P 5 SP Sleeve casing to straddle corrosion; active purge OA with N2 0 1,10 6 SP NDE sleeve installation; pressure test OA, to observe for fluid to surface 7 SP Apply external anti-corrosion coat to sleeve 8 SP, Backfill around well and remove well support structure; install tree; pull plug V, and POP S 1 of 1 • • m • o• 0 0 0 0 o r r — o4vvLn 0 y o 0 0 0 0 0 i 0) If) co • V N- N N N m ' l[) N- N- N- CO O (0 (3) O O O O N- CO 10 N N 'Cr CO r N l() r CO (3) o) CO I I , i i I- O) O I•- O co in V N N N CO N- N CO O r- ‘_(=> O O 10 ( O C.) p Q 4-I co Q r O I- O O M (-NJ N N � m d 0 0 I 92 JJ 0 5 0? = Q JcU) t •N N �$ 4# cD fn _ U rnaoNcoNco � O CV N N O) N 4 t 0,O o co _co .1- N- co in O N. G) V o) O 6) O _O _O O GF- WHII 7) 0 0 0 0 0 C) Ou_ DODz z w 0 0 0 m O D Etw r D U (/) 0_ CI_ dF- • • U, N l6 co c0 M O N O O Lf) t co O V `- CO p N- 00 0 0 0 0 O CO O O O O > F a O t IN N- C . LC) N C) LCD N 't O) 0 • p N- I- CIO 0) O C O O > a COMMCOODCOMM 0 0 t— w 0 0 w z W w 0 w H H a ggY ° 0 o O O O N Cb O O J J J U U t N N- M O = M d d fl- O '--- N N M M ¢ ¢ ¢ W 0 J 0 CD 0 0 0 0 0 0 0 0 0 U_ _0 Z U_ J W W 0 Z Z 0 p r-1-1 ° J fa ¢ ¢ ¢ = a W a O O O W c Z 0 Z = elf w W W a H H ¢ J ¢ ✓ E 2 0 co co co co co as 00 < 0 � o a a = 00LC) CDNNcccc O = p a, I- O) O O CO O N 0 0 N N N M M ,r mp 0 0 0 0 0 0 y mad O a = H E- co a E a 2 0 co co cn co co a) CL 0 U C m a a W a W W W W a000Qaaaa a 0 a wH m M N M N N N N 0 N 0 0 CD O O O O o 0 0 0 0 0 0 0 0 0 W Z 0 N N N N N N N N Z U ¢ W m ,r \ T- = = 00 = =0 u) 0 d W 0 pW W a W 0 O Ln Ln L1") In In lC) Lf) CO p W J -1 ¢ O W W ¢ ¢ a co E a a cn a a, E Q Q Q Q Q Q Q Q oo op op op co op co co a sco 0 LL. a a a s COQ- MO- 0 -100w a a ¢ ¢ m m a E cn co a cC Ifi =" 4-1/16"CNV • VUELLI-EAD= FMC GEN 5 SAFETY NOTES: ***4-12"CHROME TBG& 7" ACTUATOR= BAKER P 1 -18A CHROME CSG*** KB.ELEV= 37.3' BF.ELEV= 8.8' I I KOP= 4491' Minx Angle= 48'@ 7540 ( 2227' J--14-1/2"CAMCO BA L-0 SVLN,D=3.813"i Datum M)= 10164' GAS LFT MANDRELS DbtumTVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 6 4187 4177 7 KBG-2 DOME BK 16 04/13/17 I 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 'yl 4 6797 6248 44 KBG-2 DOME BK 16 04/13/17 Minimum ID =3.725" 9786' 3 8210 7267 42 KBG-2 SO BK 28 04/13/17 2 9246 8045 33 KBG-2 DAN BK 0 01/06/10 4-1/2" HES XN NIPPLE 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 (TOPOF WHIPSTOCK j 4491j 9-5/8" MILLOUT WINDOW 4491'-450T ffffrf119-5/8"CSG,40# L-80,D 8,835"j-[ 4610' I '�'�A�Od'�'i i�i�i'��i�i�i� [r CSG,26#,L-80 BTC XO TO 13CR-80[---I 9631' I—x >< ' ' [ 9720' ,-141/2"HES X NIP,D=3.813" , X X I 9741' I-14-1/2"X 7 BKR S3 PIR,ID=3.875" J ' , { 9766 H4-1/2"HES X NP D=3.813"J I I { 9786' j-14-112"HES XN NP,ID=3.725 14-1/2'TBG 12.6# 13CR-80 0152 bpf,ID=3.958" i— 979W j / \— [ 9798' J—4-1/2"WLEG,ID=3.958 1 { 9796' {—{FEND LOGGED ON 05/04/04 , PERFORATION SUMMARY REF LOG: 9838' ,1---17"MARKER JOINT ` ANGLE AT TOP PERF: 31'@ 10071' Pbte:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 10070-10090 0 05/04/04 3-3/8" 4 10091- 10111 0 05/11/03 3-3/8" 6 10205-10220 0 05/19/02 2-7/8" 4 10241- 10271 0 05/15/03 3.3/8" 6 10292- 10418 0 05/20/02 3-3/8" 6 10428-10438 0 05/17/02 1r CSG,26#,13CR-80 VAM TOP XO TO L-80 BTC — 10639' rt,,,,,,,,•- PBTD 10638' __.___ ______._ ___-- -__ ____-_____J .____-_-__J ......1.114 -----__._1—t_.--._______ 1.41••••••• 17"CSG,26#,L-80 BTC, 0383 bpf,D=6 276"]--{ 10623' ] IhAtt0•1.4•0A DATE REV BY COMMENTS DATE REV BY COM M34TS PRUDHOE BAY MT 12/08/99 ? ORIGINAL COMPLETION 02/20/17 ATO/JMIDGLV C1O(02115/17) WELL P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 03/22/17 JM) MOOR WBS CORRECTIONS PERMT No: 2020760 07/17/10 RLW/PJC ELM)LOGGED 05/04/04 04/17/17 ZV/JM) GLV GO(04/13/17) AR No: 50-029-22953-01 08/15/11 PJC DRAWNG CORRECTION SEC 16,T12N,R14E,1394'FSL&880'FEL 08/15/11 MSS/PJC GLV GO(08/05111) 05/20/15 PJC 'PERE CORRECTIONS BP Exploration(Alaska) • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Conductor Top Job 11 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-076 3. Address: P.O.Box 196612 Anchorage, Development 21 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22953-01-00 7. Property Designation(Lease Number): ADL 0028297 8. Well Name and Number: PRUDHOE BAY UN PTM P1-18A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 10641 feet Plugs measuredfeet ECk E 1 V iE C true vertical 9236 feet Junk measured feet FEB Effective Depth: measured 10539 feet Packer measured 9740 feet F Ep 0 6 2014 true vertical 9152 feet Packer true vertical 8470 feet AOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 4463 9-5/8"40#L-80 27-4490 27-4476 5750 3090 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth: Measured depth: 10070 10090 feet 10090-10110 feet 10205-10220 feet 10240-10270 feet 10292-10332 feet 10332-10398 feet 10398-10418 feet 10428-10438 feet True vertical depth: 8757-8774 feet feet 8774-8791 feet 8872-8885 feet 8902-8927 feet 8945-8979 feet 8979-9034 feet 9034-9051 feet 9060-9068 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-9797 24-8520 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Hydro Set Packer 9740 8470 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Top of Conductor Treatment descriptions including volumes used and final pressure: SCANNED WIti7' 0 it117 2 Bbls Water/Musol,12 Gallons Halliburton LockCem,Atmosphere Pressure. 3 4 i1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 458 2031 5177 2080 703 Subsequent to operation: Shut-In 270 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development 11 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil N7 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-553 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,q(( Phone +1 907 564 4424 Date 2/2/17 Form 10-404 Revised 5/2015 RBD MS I a . El - 8 2017 Submit Original Only • 41 a 0 0 0 0 0 1C N- O r O O ct t LO U N O o 0 0 0 0 6. CD c") I� N N N CO ()) O O O CO I� 0') V7 N N co - N 10 'CrCO 0) O) CO 01 I I I I I I— C)) O CO CO CO 1.0 V N N N M - N CO O) }I CO C O O N- N ot10 N Ea - 0) o o rn a a Z co co o r N N N U O N Mr• I- W CO co U CMO J COO L COO M C) *k 4# .N 0 N J C') J 4* (0 U = N N ("NI - - N O N - O CO CO N- C C0 LO 0) CO N- J CA CA al OO _O CI- w � H •0 0 0 U caDQ » DU U O O O O Z Z rYO O O m O D c c D 0WCL 0 0 l- • 0 = o — - -- cco o-0 Z 0 a) a) a T° . m as 2 co N N a) N N L > O ao to 3 11 Q a) 4- a) —O o ' Q S? c 20 p o cri o 3 c c ., a) +. c in O _ S?0 I Y Y o_ !Z (0 Y SZ Q s? O a c L o 3 p 3 O O O p O Ion E -0 C a N 3 3 0 Y 3 o c CC a) -0 0`� ° 06 -a ',_ = CO a) a) N CL o I _ = a 3 c Q CO a) > Q C co a) 0 3 m f° C ca J H as a) n N 0 < o C 0 m a o L J >>� 3 0) U) C � f0 O U a C U L Q > OO cv v) � v� H -C a) n ~ ° o N O co < • li Q r .c a) .c • o-- o .c C o = °a o c co Q 7 to r co L c L N • r L M C a) a-. !? L a) a) N J +� .� f�6 O N N N 7 N (O r N r ++ r 2' U) Q 7 a) p a) U) O a) a) a) . ozi i_ CLCC 2 - O o aa)) _ yin 2 0 a N Q 0 2 _ C� Q G 0 0 co .;U 70 s- _ •�• s- CD as � O s_ 0 O ` ° 0 �[ �O O O O a M > (n r a) Q II U O II i fn CO O r co >� N Or • s a) 7 • N 0 r N .- Q -C —O Q •Ca z ° sz 0 o E j i .- di , C� C U C7 2 0) O U O o 1_ 0 , 01._ -0 S o 00 0 c°)0 0 OCD 0 • 0 O HO o Q u) Q } C lz II c — C co II C a) II a) n- C II 0 II — >_ • — O a 0 V < 0 ° < O U < O U Q 0 cn c < o . Q U 0 O > 0 o 't CO a) O ci O 0 0 —. -)a 0 o0 U, 0 n a) II . a) QW (A - Qv) > c3o) < c5Z < Qfn p a) u) Q C N� V) H � d 0 I1 "O II (n a II Q II Q ll 73 O II > II 0 II A ? -a I1 FT c aEi o ° u aa15 i u) 1 1 ai = u o u a0 a) m II O E H 0 m 0 Q. 0 0 o .�ozi Ce co 2 4- -c) .= o z o 0) o cc o o u) v � O � II o o 11 0 0 0 Q- U O v — CU `s`) .c-n- Co M SCUM N ©U co .SP> M " a0o L I I co0p E I I aoo N II aoo 11 aoo I I Co !� I I aoo N coOrn N N a) N O N Q N fl N Q E N > N c > 5 ci c-Y U) > E v) > E U) > p O U) > E a) o U > = 0 U) 3 Zr; U) u) U O u) u) U) (n _ (n U) Q N u) (n < �' — U) II U) U II v) cco cn m u) �, v) t CO } = v) rn> c, = > II 3 II II a) 5 II II *. II as > II c U) II w (n O 0 0 -p a) O E O E O LN O E 0 - OaU) a) in > - a) > - a) > - a) = > - o � > - a) > - 0 > - - H _cr () H7 EU) HUu) HUsU) H 3 .SU) HO > (n H = U) H5U) W H N. N- r- r- CD r r r r r r r .- >- >- 0 0 o 0 o o o 0 H N N 0 ,_ N M In > r r r r r r I— r r rr r r r r r r r r r 0 Q • • tT c L O I c U) as a) I U) Q Q O L O O Q(6 U) J -C C CO Q 0 CO O • m a.+ %-• a N RS a_ E a� Q c Y O cn ~ 0 H 8 -0 'I a L N < CD Z U O It d a Q 0 < .0)0 m E II Q W (n > > 0 II O CeEon_ L O YO 0 d 0 c II O j TREE= • 4-1116"CNV • P1 1NELLHEAD= FMC GEN 5 SAFETY NOTES: ""4-12"CHROME TBG 8 7" 18A CHROME CSG*** ACTUATOR= BAKER C KB.EIV= 37.3' BF.ELEV= 8.8' I I KOP= 4491' Max Angle= 48"@ 7540' I 2227' —4-1/2"CAMCO BAL-O SVLN,ID=3.813" Datum MD= 10164' GAS LIT MANDRELS Datum TVD= 8800'SS ST MD ND DEV TY FE VLV LATCH FORT DATE 6 4187 4177 7 KBG-2 DMY BK 0 08/05/11 Minimum ID =3.726" @ 9786' 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 4-1/2" HES XN NIPPLE I I 4 6797 6248 44 KBG-2 DMY BK 0 08/05/11 3 8210 7267 42 KBG-2 DMY BK 0 08/05/11 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 1 19652 8393 30 (KBG-2 DMY BK 0 01/06/10 9-5/8" MILLOUT WINDOW 4491' -450T TOP OF WI/PS/Da( H 4491' 9-5/8"CSG,40#,L-80,D=8.835" H( 4610' 7"CSG,26#,L-80 BTC XO TO 13CR-80 H 9631' X ' 9720' —I4-112"HES X NP,D=3.813" X 9741' H4-1/2"X 7"BKR S3 PKR D=3.875" ' 9765' H4-1/2"HES X NP,D=3.813" j 9786' H4-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR 80,.0152 bpf,D=3.958' H 9797' 9798' —I4-1/2"'LEG,D=3.958" 9796' H ELMD LOGGED ON 35/04/04 PERFORATION SUMvfARY REF LOG: 0-4 9838' H 7"MARKER Jour ANGLE AT TOP PERE 31°@ 10071' Note:Refer to Production DB for historical perf data SIZE SFS NTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 10070- 10090 0 05/04/04 3-3/8" 4 10091- 10111 0 05/11/03 3-3/8" 6 10205- 10220 0 05/19/02 2-7/8" 4 10241 -10271 0 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428-10438 0 05/17/02 7"CSG,26#,13C R-80 V A M TOP XO TO L-80 BTC H 10539' 1-- •v rrr,,,f t e- FBTD H 10538' / 11111111111111111/111 111111111111 7"CSG,26#,L-80 BTC,.0383 bpf,D=6.276" --{ 10623' /.1.1.1.1.1.1.1.1.1.1. DATE REV BY COMv NTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 07/17/10 RLW/PJC EL%)LOGGED 05/04/04 WELL: PI-18A 05/05/02 N2M SIDETRACK(P1-18A) 08/15/11 PJC DRAWING CORRECTION PERMIT Na- 2020760 10/11/05 JDM/PAG ADPERF CORRECTION 08/15/11 MSS/PJC GLV 00(08/05/11) AR No: 50-029-22953-01 10/25/07 JLJITLH GLV C/O(10118/07) 05/20/15 PJC PERF CORRECTIONS SEC 16,T12N,R14E 1394'FSL 8 880'FEL 05/17/08 DTRJTLH GLV C/O(04/27/08) 02/03/10 JLJ/PJC GLV 00/01/06/10) BP Exploration(Alaska) • y OF Tjf� • • h�•e\,177,-. THE STATE Alaska Oil and Gas Fi-,,—spa �, of e T c � ® Conservation Commission -.,4), _ =_=_-__., „. _ __ ALAS��`r1 4/50C-7. -: 333 West Seventh Avenue i ' ��. I. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Interventions & Integrity Engineer BP Exploration(Alaska), Inc. S DEQ FF-B P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P1-18A Permit to Drill Number: 202-076 Sundry Number: 316-553 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P91L4, 1e-,_ Cathy . Foerster Chair DATED this J?' ay of November, 2016. RBDMS IA- r uv - 7 2016 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ® . Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other Conductor Top Job Er ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-076 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JJ. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22953-01-00 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 2 PTM P1-18A• RECEIVED Property 9. ADL 0028297Designation(Lease Number): 10• PRUDHOE BAY,PT MCINTYRE OIL J C 1 2 6 2016 11. PRESENT WELL CONDITION SUMMARY /l./ 3 / Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): J 10641 ' 9236 4 10539 9152 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 4463 9-5/8"40#L-80 27-4490 27-4476 5750 3090 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 24-9797 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and TVD(ft): 9740, 8470.30 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary a Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® ' Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 2 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Interventions&Integrity Engineer Signature '1.,..640017 Phone +1 907 564 4102 Date i0 d j) i COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: \L-Q.- 53 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No t!if< Spacin Exception ? I' Subsequent Form Required: /�� t ,tquir-3 iS�Yes 0 No /v im 4- a/4 APPROVED BYTHE Approved by: }�/� // COMMISSIONER COMMISSION Date: // S—4I / ORIGINAL RBDMS NOV� 7 2016 ( "I2 iii 0///b Submit Form and Form 10-403 Revised 11/2015 Approved applica ion is valid for 12 months from the date of approval. /�� Attachmgnts in Duplicate • • P1-18 Conductor Top Job Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Kaity Burton (907) 564-5554 C,c 4 c History aA C)fr- c> On 04/09/11 P1-18 failed an MIT-OA with fluid to surface in the conductor pipe. The LLR from the OA was estimated at 0.2 gpm @ 200 psi. An OA fluid depression utilizing nitrogen indicated a surface casing leak near the surface. The well was reclassified as "Not Operable". A Well Lock treatment was performed on the conductor in the summer of 2015 but the conductor was not topped off with the second stage of Well Lock that was originally planned due to ongoing investigations into the V-101 conductor Well Lock job. A post Well Lock MITOA failed with a slight leak to the conductor still present. A second Sundry was approved to perform an OA downsqueeze with cement. This job was cancelled because sufficient injectivity into the OA shoe could not be established after several tries in December of 2015 and again in February of 2016. The top of the well lock is —15" below the top of the conductor. Current Status The well is currently classified as "Non Operable" by BP due to the OA x Conductor leak. Objective The objective of this job is to complete the 2nd stage of the Conductor top job with a cementitious - material. Vt.p. , to vv.c e t ►ezr Jr. 201D koeu..Lam- o2 LA-r ( A-ss G c ep — 1,/1 TEs-r»t w e¢.w^-Y -a Procedural steps Special Projects 1. Clean out the conductor void to the top of the original well lock. 2. Fill the conductor void to surface with cementitious material. DHD 1. POP well Under Evaluation and monitor conductor for leakage. 2. Designate well as Operable if well has no leakage from the conductor. • • • TREE= 4-1/16"CM!WELLHEAD= FMC GEN 5 �r ACTUATOR= BAKER C ■ I -18 A SAFETY NOTES:CHROME CSG"****x 4-12"CHROME TBG&7" KB.ELEV= 37.3' BF.ELEV= 8.8' I I KOP= 4491' Max Angle= 48°@ 7540' 2227' —I4-1/2"CAIv1CO BAL-O SVLN,ID=3.813" Datum full)= 10164' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 4187 4177 7 KBG-2 DMY BK 0 08/05/11 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 Minimum ID = 3.725" @ 9786' 4 6797 6248 44 KBG-2 DMY BK 0 08/05/11 4-1/2" HES XN NIPPLE { . 3 8210 7267 42 KBG-2 DMY BK 0 08/05/11 2 9246 8045 33 KBG-2 MY BK 0 01/06/10 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OF WHIPSTOCK I 4491' 9-5/8" MILLOUT WINDOW 4491'-4507' *> 9-5/8"CSG,404,L-80,N=8.835" H 4610' 1.1.111.1.1.1.11.1.1.1.1.1. 17"CSG,26#,L-80 BTC XO TO 13CR-80 H 9631' I—X X ' •I 9720' H4-1/2"HES X NIP,ID=3.813" I 4-1 X9741" I� f2"X 7"BKR S3 PKR,13-3.875" ' 9765' H4-1I2"HES X NIP,ID=3.813" I ' I 9786' H4-1/2"HES XN NIP,13=3.725" 4-1/2"TBG,12.6#.13CR-80..0152 bpf,ID=3.958" H 9797' I— / I 9798' H4-1/2"WLEG,13=3.958" I 9796' HELP/ID LOGGED ON 05/04/04 I PERFORATION SUMMARY 0- I 9838' H7"MARKER JOINT I REF LOG: ANGLEAT TOPPERF: 31°@ 10071' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10071-10091 0 05/04/04 3-3/8" 4 10091-10111 0 05/11/03 3-3/8" 6 10205-10220 0 05/20/02 2-7/8" 4 10241-10271 0 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428-10438 0 05/20/02 17"CSG,26#, 13CR-80 VAM TOP XO TO L-80 BTC —I 10539' F- ,1.1.1.1.1,1.1.1.1.1.- FBO I—I 10538' �111�1�1111•11�+1111 17"CSG,26#,L-80 BTC,.0383 bpf,ID=6.276"H 10623' i�1�1�111�1�1�1� 4.4.1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/99 ? ORIGINAL C OM PL ETION 07/17/10 RLW/PJC ELM)LOGGED 05/04/04 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWNG CORRECTION PERMIT No: 2020760 10/11/05 JDMIPAG ADFERF CORRECTION E 08/15/11 MSS/PJC GLV Ct0(08/05/11) API No: 50-029-22953-01 10/25/07 JLJ/TLH GLV C/O(10/18/07) SEC 16,T12N,R14E,1394'FSL&880'FEL 05/17/08 DTWTLH GLV C10(04/27/08) 02/03/10 JLJ/PJC GLV C/0/01/06/10) BP Exploration(Alaska) 2 • • a> Q o 0 0 0 0 0 ix, g2 - r- O co 0 LO LC) U 1) 0 0 0 0 0 0 i O) Lo cr V co 'ct N- N N N cY m LO I� 00 MCO O O O co in N N V co r N LC) 'Cr CO O O) CO I— O) O 00 N- co co in N N N M N CO 0) (1) ON- N � OM O) OLO Lom O O MN- T- (1)V as Q C I I I I CO 00 r` CO co M tY N N N LC) 10 N 0) r I— L � co w coo ) y N N •Cf) �$ M U coNON b _ N d7 N t +' () . - co rm co co O c CO V L() CO N- J V O a) 0) Z Z Z C)O 000 cF- wI- I- H O O LL0 p p Z z Lt0 0 0 m ODCCWIYD 0 ( a. O a I— d Ln R CO N- CO CO O N C7) O) i . 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N Et LL aaaaaaaa ¢ Q m CI- u_ E: d � a • V.-RA cu^M Y' u'ci r, tai N ESL)•,• 4N C) • • OF T • *3'',., /� � THE STATE Alaska Oil and Gas OConservation Commission L � �t333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 KA 04, Main: 907.279.1433 �ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington r. Interventions & Integrity Engineer SCANNED iN 2 42017, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P1-18A Permit to Drill Number: 202-076 Sundry Number: 316-400 Dear Mr. Worthington: The AOGCC denies the enclosed application for sundry approval relating to the above- referenced well. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless reconsideration has been requested. Sincerely, #,' / 447tc __ Cathy '. Foerster Chair DATED this /Tof August, 2016. RBDMS 0- AUG L 5 1016 STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION co..* RECEIVED APPLICATION FOR SUNDRY APPRO AUG 0 1 2016 • 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well RI• Aenicettdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Squeeze Iiif_ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-076 _ 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0- 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22953-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No IZI PTM P1-18•- 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028297 • PRUDHOE BAY,PT MCINTYR-OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10641. 9236 , 10539 9152 Casing Length Size MD TV' Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 4461 9-5/8"40#L-80 28-4490 28-4476 5750 3090 Intermediate Production See Attachment See Attachment See Attachme,. See Attachment See Attachment See Attachment Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Si Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-11Q '1-.6#13Cr80 13Cr80 23-9797 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer l" Packers and SSSV MD(ft)and TVD(ft): 9740, 8470.30 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore�Ie, ic 0 13.Well Class after proposed work: Detailed Operations Program ® BO• • m Q O 0 0 0 0 0 cotio � � .- o o v v O co to O u, f� 0 yO0ooco w u) d v CO (OCOOo 0 N- M Lo N N V" CO N to r N' O O O O I I I I I H O O O) CO CO Co IC) CO N CV N CO c- N CO C)) C incoC) E oC) C)C) O O C) CA r 0, O p QOr 4.0 03 C) O Cfl CA M CM N N 1 O N C C• G~ acp c3 co co co M • d 1:k c6- N to O • in �$ 4t CO (N1 C 00 NN U N O N () N 4". _ CO Cn O CO O r- C co V C4) co N- C) d O W �0 000 C W H H H 'y0 0000 cc D Q O D D 0 0 0 LL, 0 0 0 Z ZIX000m 0JafY D 0_CD aCICH • • 1 II mill 1 d N R m O M O N O O Ln O CO C 7 00 Q O C N O C r- 1D 0 co r- CO co O 0 co co p 0 CO CO 00 CO 0) O) 0) I- 0.a 0 I- N coh. 0) C N O N m6 M Ln 0) C 0) 0 h- r- O 0) 0) p 0) O O > O DO O 00 CO CO O 0) 0 F w 0 w wz W W W 0 F- H J 0 w a) 55Y 70 > mO O W Y Y 1 ir g t 0 0 0 O N CO CO 00 J Q OQ w W w Q- O ,- N N CO CO C C < < < W a O- 0 Z 0 C 4) 0 0 0 O O O O O U_ U_ U_ J W W O -I O p T— c— c— V— z z z 0 ❑ ❑ J ❑ J 2 0 0 0 W Z 0 Z LW w W o_ 1- H- < J < C.) Q 2 2 O cn cn cn cn cn CO 4-1 •x- 4.0 I a Q0 r- r O O LL) O N N CO CO G O O C 0) M O N Q C d O O (N CV N co co C G p 0 0 0 0 0 0 0 0 cs)R r r r r r r r r RS L 0 tL2 0_' = S I H O1- O_ J O_ co ec ' 2 O cn cn cn cn cn AW EL 0 0 c LL_ LL_ 0: LL_ CC CC tY D: w a. n- W 0- LL LLI W W ;, < < a. < o a_ a_ a_ a O t m a Y I- co CO N CO CV N N N ❑ C 0 p 0 0 0 0 0 0 0 0 Ow z c N N N N N N N N Z w Q W J N LL To T- V- V- co V- p d 0 O Ili W W Q O Lo 1.0 L() LU Ln L0 L) < ❑ J I- J J J ❑ G✓ d J_ J_ < < O U) LL Li U cn o_ c m E 2 0 0 0 Q Q Q Q Q oc00000 rrrr 7 r r r r r Tr LL a co O u- N cc W — V— V— 030- 0- 0- 0 -I O 0 w o_ CL a_ Cl_ a. 0_ O Q_ 0_ Q Q m m LL LL Ln cn d ct i bp • • Well: P1-18 Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Kaity Burton (907) 564-5554 Expected Start Date: August 10th, 2016 History The original well was drilled as the Nuvuk 18 to test the Nuvuk prospect beneath the Kuparuk. On 04/09/11 P1-18 failed an MIT-OA with fluid to surface in the conductor pipe. An OA fluid depression utilizing nitrogen indicated a surface casing leak @ -11 feet deep. The well was reclassified as "Not Operable". A Sundry was approved in 2015 to perform a well lock treatment on the conductor. This job was performed in June of 2015 but did not entirely seal off the OA x Conductor leak. A second Sundry was approved to perform an OA downsqueeze with cement. This job was cancelled because sufficient injectivity into the OA shoe could not be established after several tries in December of 2015 and again in February of 2016. This Sundry is for a revised OA downsqueeze to be circulated down to perforations @ -2200' MD - since the cement cannot be pumped down into the open shoe. Job Economics There are 286mbo estimated to be recovered as a result of operating this well again. Current economics do not support a rig-workover, therefore this alternative integrity repair is proposed to maintain integrity/operability of the well long term. Objective Cement the OA (9-5/8" x 7") annulus to seal off a fluid leak (0.2 gpm @ 200 psi) from the OA to conductor @ -11'. Objective is to have cement in the OA from -2300' MD to surface to restore integrity and operability. Post-Job Evaluation This well is a producer so an AA will not be applied for, however the following BP internal criteria will evaluate the integrity of the non-rig workover: • MITOA, MITIA, and MITT Long-Term Integrity Monitoring ➢ Record WHPs daily ➢ 4-year (quadrennial) MITIAs and MITTs • I TREE= 4-1/16"CIW WELLHEAD= FMC GENS P1-18 �U rrellt CHROME COTES: ***4-12"CHROME TBG&7" ACTUATOR= BAKER C KB.ELEV= 37.3' BE.ELEV= 8.8' I I) ' KOP= 4491' Max Angle= 48°@ 7540' 121271-14-1/2"CAMCO BAL-O SVLN,ID=3.813" Datum MD= 10164' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE --— 6 4187 4177 7 KBG-2 WY BK 0 08/05/11 - - 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 Minimum ID = 3,725" @ 9786' <t 4 6797 6248 44 KBG-2 DMY BK 0 08105/11 4-1/2" HES XN NIPPLE �b(4 3 8210 7267 42 KBG-2 DMY BK 0 08/05/11 /G 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OF WHIPSTOCK I 4491' 9-5/8" MILLOUT WINDOW 4491'-4507' 9-5/8"CSG,404,L-80,ID=8.835" —I 4610' x.1.111.1.1.1.11.1.1.1.1.4 7"CSG,26#.L-80 BTC XO TO 13CR-80 I— 9631' l•-X >< ' 9720' H4-1/2"HES X NIP,ID=3.813" X `, 9741' H4-112"X 7"BKRS3 PKR,ID=3.875" ' 9765' H4-1/2"HES X NIP,ID=3.813" ' ' 9786' H4-1/2"HES XN NIP,D=3.725" 4-112"TBG,12.64,13CR-80..0152 bpf,ID=3.958" I— 9797' I-- / \----I 9798' 1-14-1/2"WLEG, D=3.958" I 9796' H ELMD LOGGED ON 05/04/04 PERFORATION SUMMARY 9838' H7"MARKER JOINT REF LOG: ANGLEAT TOP PERF: 31°@ 10071' Note.Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 4 10071 -10091 0 05/04/04 3-3/8" 4 10091-10111 0 05/11/03 3-3/8" 6 10205-10220 O 05/20/02 2-7/8" 4 10241 -10271 O 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428-10438 O 05/20/02 7"CSG,26#,13CR-80 VAM TOP XO TO L-80 BTC — 10539' I--- ••••itrvym• PBTD --1 10538' ttttt•tttttttttttttttt 7"CSG.264,L-80 BTC,.0383 bpf,ID=6.276" -I 10623' ,AtrtitAtiti,,AvA At.tAn DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 07/1 7/10 RLW/PJC ELMD LOGGED 05/04/04 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWNG CORRECTION PERMIT No: 2020760 10/11/05 JDM/PAG ADEERF CORRECTION 08/15/11 MSS/PJC GLV C/O(08/05/11) AR No: 50-029-22953-01 10/25/07 JLJ/TLH GLV 0/0(10/18107) SEC 16,T12N,R14E, 1394'FSL&880'FEL 05/17/08 DTR/TLH GLV 0/0(04/27/08) 02/03/10 JLJ/PJC GLV C/0/01/06/10) BP Exploration(Alaska) 2 • III TREE= 4-1/16"CM/ WELLHEAD= FMC GEN 5QQ AFETY NOTES: "*"4-12"CHROME TBG&7• ACTUATOR= BAKER P1-18 Proposed t HROMEDSO*** KB.ELEV= 37.3' BF.ELEV= 8.8' l" ?:p' KOP= 4491' OA Cement from 2300' MD to surface Max Angle= 48`@ 7540' Datum MD= 10164' :.',1! >;° Datum TVD= asoo'ss f !.J Tubing Patch over perforations @ 1 1• =2300'7;N:670 D 1 C1 Minimum ID = 3.725" @ 9786' L n,� o µ ,��-� �vr or uo,uat�1 4-1/2" HES XN NIPPLE 3 azlo 4z KBG-z only BK 0 osro5nl 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OF WHIPSTOCK H 4491' 9-5/8" MILLOUT WINDOW 4491' -4507' 01'"01'441411W 9-5/8"CSG,40#,L-80,ID=8.835" --I 4610' 1.1.1111.1.1.11.1.1.1.1.1. 7"CSG,26#,L-80 ETC XO TO 13CR-80 — 9631' -X >< ' , 9720' H4-1/2"HES X NIP.ID=3.813" I X 9741' I—4-112"X 7"BKR S3 PKR,ID=3.875" ' ' 9765' H4-112"HES X NIP,ID=3.813" ' ' 9786' H4-1/2"HES XN NIP,D=3.725" 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,ID=3.958" H 9797' J---- / \--I 9798' H4-1/2"WLEG.D=3.958" 9796' H ELMD LOGGED ON 05/04/04 I PERFORATION SUtu?vIARY ill""_J 9838' I—7"MARKER JOINT I REF LOG: ANGLEATTOP PERE: 31°@ 10071' Note.Refer to Production DB for historical per/data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 4 10071-10091 0 05/04/04 3-3/8" 4 10091 -10111 0 05/11/03 3-3/8" 6 10205-10220 0 05/20/02 2-7/8" 4 10241-10271 0 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428-10438 0 05/20/02 7"CSG,26#, 13CR-80 VAM TOP XO TO L-80 BTC —I 10539' i— ••91.1t•IPIP1/i•• PBTD — 10538' 4 44000* 7"CSG,26#,L-80 BTC, .0383 bpf,ID=6.276" —I 10623' 1•...f•...•1•0•0•0 DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 07/17/10 RLW/PJC ELMD LOGGED 05/04/04 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWNGCORRECTION PERMIT No: 2020760 10/11/05 JDM/PAG ADPERF CORRECTION 08/15/11 MSS/PJC GLV CIO(08/05/11) API No: 50-029-22953-01 10/25/07 JLJ/TLH GLV C!O(10/18/07) SEC 16.T12N,R14E,1394'FSL&880'FEL 05/17/08 DTR/TLH GLV C/O(04/27/08) 02/03/10 JLJ/PJC GLV C/O/01/06/10) BP Exploration(Alaska) 3 ! • , TREE= 4-1/16"CIW WELLHEAD= FMCGEN5 P1-18 Proposed P&A ROME FYNOTE': ***4-12"CHROME TBG&7" ACTUATOR= BAKER C KB.ELEV= 37.3' BF.ELEV= 8.8' I .1; F ,'. ' I KOP= 4491' <ty. I Cement Plug#3 circulated down tubing, Max Angle= 48°@ 7540' Datum tufo= 10164' • ,„ ' through perforations @—2300' MD and up Datum TVD= 8800'SS `..::t ."Ay;• ,°, IA to surface 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 Minimum ID =3.725" @ 9786' OM 4 6797 6248 44 KBG-2 DMY BK 0 08/05111 4-1/2" HES XN NIPPLE 3 8210 7267 42 KBG-2 DMY BK 0 08/05/11 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OFWHIPSTOCK 4491" 9-518" MILLOUT WINDOW 4491' -4507' ttt•tt•ttt• t ttt14 4 9-5/8"CSG,404,L-80.hD=8.835" H 4610' •-4.4•.1. 4.1-+144.1.1. . . 17"CSG,26#.L-80 BTC XO TO 13CR-80 9631' @ Cement Plug#2 circulated down tubing' \w' 9720' 4-112"HES X NIP,ID=3.813" through tubing punches above production packer, and up IA .,g kr ! tog9741' H4-1/2"X 7"BKR S3 PKR.ID=3.875" Ilia Cement Plug#1 pumped FB or laid in w/CT • 9765' 4-1/2"HES X NIP,ID=3.813" '`'` `" 9786' H4_1/2"HES XN NIP, D=3.725" 414 4-1/2"TBG,12.64,13CR-80..0152 bpf,ID=3.958" - 9797' 979$' 4-1/2"WLEG, ID 3.958" o° 9796' H ELMD LOGGED ON 05/04/04 1 • o tin PERFORATION SUMMARYMagPfai 9$3$' -7"MARKER JOINT REF LOG. ANGLEAT TOP PERE: 31°©10071' I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ff 3-3/8" 4 10071-10091 0 05/04/04 3-3/8" 4 10091 -10111 0 05/11/03 1 3-3/8" 6 10205-10220 0 05/20/02reirAil 2-718" 4 10241-10271 0 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428-10438 0 05/20/02 Magraigi ilillOiWagigin 7"CSG,264,13CR-80 VAM TOP XO TO L-80 BTC - 10539' - FBTD - 10538' ►•ttt•t•t•tttt•t•t•• 4 7"CSG,26#,L-80 BTC,.0383 bpf,ID=6.276" -I 10623' 1.4.MAW.At; DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 07/1 7/10 RLW/PJC ELMD LOGGED 05/04104 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWING CORRECTION PERMIT No: 2020760 10/11/05 JDM/PAG ADPERF CORRECTION 08/15/11 MSS/PJC GLV C/O(08/05/11) API No: 50-029-22953-01 10/25/07 JLJ/TLH GLV C/0(10/18/07) SEC 16,T12N,R14E, 1394'FSL&880'FEL 05/17/08 DTRrTLH GLV C/0(04/27/08) 02/03/10 JLJ/PJC GLV C/O/01/06/10) BP Exploration(Alaska) 4 • Job Notes 1 • SC Leak to conductor(@ -11') treated with well lock. • MITOA post well lock still showed trace fluids leaking to the conductor. • There are no known leaks in the tbg or IA. • The OA has an open shoe (not cemented by the rig), but could not be broken down with 2500 psi of applied surface pressure on the OA. • The rig freeze protected the OA with crude down to -2500' MD. Cement Calculations OA fillup volume of Cement to 2300' MD 65 Bbls Total cement to pump 80 Bbls Key Parameters Ppg: 15.8 ppg Class G - Mix on the fly Slurry Temperature: between 80° and 110°F API fluid loss: 40 - 200 cc Thickening Time: Minimum 4 hours Compressive Strength: 2000 psi in 24-48 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 65 0 2:00 65 0 5:30 52 0 10:00 46 0 16:30 42 0 24:00 39 0 5 411 • Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"40#x 8.835" 9-5/8" x 7" annulus 0 4491' 7" 26# x 7" 0.028 2300' 65 4187' (to circulating 7"26#x 4- 6.276" 7"4-1/2" annulus 0 sleeve) 1/2" x 4.5" 0.0186 4187' 78 4187' (to circulating 4-1/2" tubing 0 sleeve) 4-1/2" 12.6# 3.958" .0152 4187' 64 -SlkklineiFuUbore 1. Set 2.313" nipple reducer in XN plug in tubing tail @ 9786' MD. 2. Set PXN or XXN plug in nipple reducer. 3. MITT to 2500 psi. 4. Pull DGLV from station #6 @ 4187' MD. Set circulating sleeve in same. 1. Perforate through 4-1/2" tubing and 7" casing. 10' of HES 2.5" BH charges 180-deg phased charges from 2282' MD - 2292' MD (across the bottom collar of the first full joint of tubing below the SSSV landing nipple). Reference attached tubing tally dated 4/8/2002. 2. Set 2.813" ID retrievable patch (Northern Solutions) across perforations @ 2282' - 2292' MD. Pfo55V w#o� }-4/ ` C5 aC e, ...Jai proiects ,Fx.��r��/r�lf.'..',57,�,/�.%, f �l� ,;;� i�',,,y r/if;-.r t!F?,' `f,,.,�/•'i.`.F %,r 1. CMIT TxIAxOA to 2500 psi to ensure: A) There is clean pressure communication through the perfs from the IA to OA. B) That the perforations did not penetrate the 9-5/8" casing. Note: Be prepared for some leakage from the OA to the conductor and vac-out as necessary. 2. RU to pump down the IA and take returns from the OA to Tiger Tank. Pump the following fluids to clean the OA up prior to the cement job: Stage Volume Cumulative Fluid (bbl) barrel count 1. Spear 5 5 Neat methanol 2. Flush 50 55 9.8 ppg brine @ 160 deg F 3. Flush 100 155 180F heated freshwater + 2 gal/bbl surfactant + 2 gal/bbl Mutual Solvent 4. Brine 110 265 9.8 ppg brine @ 160 deg F Note that the 9.8 ppg brine will FP in the permafrost. 6 • • . Special Projects!Futlbore Cement OA 1. Rig up a vac truck to take returns from the conductor. The surface casing leak may result in returns to the conductor throughout the job, including 9.8 ppg brine and cement. 2. RU LRS to TBG taking returns from IA to open top tanks through a choke. 3. RU cementers to the OA with a Tee upstream of the OA for washing up through, and include the option to circulate across the top of the OA. 4. Pump the following down the OA taking returns from the IA. Have LRS spear in with methanol and then continuously circulate 160 degF seawater or 1% KCI down the TBG, taking returns out the IA while pumping cement into OA. Max pressure in the OA is 2500psi (note that it has been pressure-tested to this pressure in the recent past and leaked only slightly to the conductor). Stage Volume Cumulative Fluid (bbl) barrel count 1. Spear 5 5 Neat methanol 2. Flush 50 55 9.8 ppg brine @ 160 deg F 3. Spacer 5 60 Freshwater 4. Cement 80 140 Neat Class G cement 5. Spacer 5 145 Freshwater 5. If CMIT-TxIAxOA in previous step has failed. - After 70 bbls of cement away slow cement pump rate to -1 bpm. Shut in choke to a minimum and walk squeeze pressure on TBGxIA up to -2500psi then SD LRS pump on TBG. Hold -2500psi squeeze for 20 minutes then open choke to -900 psi while LRS is brought back on line and reestablishes circulation down the TBG. Keep the IA returns choked back to -900 psi for the remainder of the job. Note: This step of the procedure may not be required. The idea is that if the 9-5/8"SC has holes from the perforations, a squeeze can be performed to remediate the holes. However if the CMIT- TxIAxOA performed earlier in this procedure passes, no holes were put in the 9-5/8"and a squeeze is not needed. 6. NOTE: Choking back IA returns to -900psi will hold the cement in the OA in place. 7. If CANT-TxlAxOA has passed - Divert the cement upstream of the OA after 76 bbls, to prevent wash up from entering the OA. Keep OA shut in and IA pressure Cad -900 psi for the remainder of the lob. Wash up upstream of the OA. 7 • I • Special Projects t Fullbore Cement OA (cont'd) 8. After diverting last cement upstream of OA, leave OA shut-in and pump the following down the TBG taking returns up the IA: Fluid Volume Rate Note (bbl) (bpm) 1. 1.25ppb gel pill 10 Max Purpose: to remove any cement that might have entered the IA 2. Seawater at 60 Max 160degF possible at 160degF 3. 1.25ppb gel pill 10 Max Purpose: to remove any cement that might have entered the IA 4. Seawater at - Min Circulate until cement has developed 500psi 160degF compressive strength ** 5. Diesel at 160 F 140 Min Purpose: freeze protect TBG and IA. **Circulating until cement has reached 500psi compressive strength will allow cement to set up and prevent diesel freeze protect from contaminating cement job. Time to 500psi compressive strength should be about 4-6 hrs. 9. After finishing circulation on Tbg x IA, hold open bleed on OA for 1 hour, sniff for LEL's, then ND gate valve and manually clean any residual cement from the valve and VR profile. (See MOC #10083 for specific deviation details allowing for this operation). 10. Grease the OA gate valve to clear of all cement & NU valve. Special projects 1. Strap TOC in OA. 2. Pump squeezecrete into OA and squeeze per RP to 2500 psi. DHD 1. WOC (squeezecrete) for at least 2 weeks and MITOA to 1200 psi to verify no leaks to conductor. Slickline/Fullbore 1. DGLVs. 2. MITT to 2500 psi. 3. MITIA to 2500 psi. 4. Run Generic GLV design. 5. Pull Tubing Tail plug. 6. Set WRDP-2 SSSV. 8 • • Well Integrity Coordinator 1. POP under evaluation and monitor conductor and cellar for any fluid leakage. Integrity Engineer 1. Add quadrennial (four year) MITTs and MITIAs to Anncomm. 9 • • • : EIr EXPLORATiON Wellbore Equipment Report „ 13A E.,e,..2 7..7EN77.-.P. `,MPI.E77,2 1 V.Jeld D. A922.031.7n E,.,eff..51..ei. .G.V2002 rielti. 70INT 1.1ACP,ATTP.5, 5pad: 'Otter;17,c6_,_ CaVELOPMENT MtItIlir...7--6.-3.7...v 0.00..P. Imtelet'. 6412032 tryz... 0.70 i70 "ItreHLT *. :11 ITUVNG 2,2Fion 1.!..,!..116.00.'!11 n912 Its!2 ' A33IS,` ----- , `..1) f27-7.3C,HD ELE,,A.71C.2.NI-F12t7 5' '.:1r.0 :,:',1 57 7,03, 7.,OD :-1.1514:S 1.4.A.M3.7zR 4 503 , 5 75. - 4 50; -____ . ,.. 233 , P7.!-- 1,66-17-3k V. AC .: i i -" .-,...i: ,., ,. i"3:j31 VG JOINTS 4 552 52 2 . 2! 1260i' ,.'.... 3562 V6.M. Af.-..r; 3 .. . 18705 27.8 FLIP.1T XC 4 6:? . 3 55 2 214 57 i 2 60 '3!-REC V.A.A,.ACE 1 26.4 :XC THREADS5_053 , 2.5' 2.224.53i 0.00i'.co NKA.!VA 1 3 55,5' , --:-. ICAMCO SAFETY VALVF. 4 TT51 ' 5 2? 2 22?14; 3:261 0CR NEW VA 1 3 r113! , - ; 1 X C THREADS .771 < . 7 62 2 7.32A'1 6 05i'32R60 i NEW VIA, i 3 MA, i PUP JT X.0 4500 I 0 SD 2..235 041 12 53. '3!:$355!VA3.4 ACE! 3_?55 ..7'51W';.1011,4 I S : 4 560 4t2 .9'2',93 2.244 94; 1:1 60!'ar."...57,PC,k'ANI 4:75.1 3 358 Lp.,!...!P,I:T X C : 4 5;47' _ r.,5.?, 4,178.87 12 691 4 3E.F.50!VAN}ACE; I CAN1r..:0 TAM.A1G2 Ar.r t-AT01.3K : 4,.5.7,3 ,. &89 z.185.75 I 0.001 SCR 1 HSDT i 2 517.9' I.PUP XI'x.0 , 4503 i 9.50 4.191.54 12.601.^,-If.:Ata IVAU AZ,,E 9,R96, e.560- 25 ' 1,05555 4.20.3.55 *la 5-0!T3C.R50 0.4114 ACMI a 858 i i !RUp,„7.T xc , 4 6X; 1 , 9 66i 6.290.131 12.601'3CRPZIV.0.2,4 Al..".."E! .3.2.5..a I CAVICO OW Xl5G2 vs'r-Dv RI< * n*5rx) --. 5 BS. 5,299.951 0.991 _9T3; ;,Hscr : 3,s4A,,,f)! !PUP JT1 X0 4.503 I ' 392 8.308.81i '12.50113cR50!v,anb.4 ACE! 3.258 _ ...., Tlf.5N5 JOINTS : 4 5,03 IT; 1,4 i 0 41 5.31;n! s 2 s-ot,,ac.4.6.c.!vi....m Ar.....E: 3 558, . . pup JT X(1 , 4.503 t 9.65' 6.787.22! 12..50:'.34SP.53 YAM ACE 1988i CSM cro.01.J4 Kew.vs.°-*,*Cy 5K ; 4 550 1 , 5. .95, 000L_KR h4SCT i 0 9119' gl.)P,..1T XC 4 f.'1712 ! 9 91' 5.803.97 12.60 11.171;R65'T./A.6,1ACR 1 TUBING,R5ii-..-77-s. 2 .4 500 a ' 1 256 25 8.613.88 12.60!i8t.ta50 LAM Ac5--3 3.958 . . _. . 4.500 1 g..37' .1.204114 r 12.90:11.7..R80 1).+A.2,1 ACT4 1.95.12 , . 1 CAVT.A3 Gl.tri-K5C32!PP 1'r".:Ni fIK 4,ler, 5.89' 8/10.01 0.00 9C3t INISCT ! 5,..9p.,... e-.500 ! 5.51! 52'81C T.2.50'137.A80 VM.ACE 3.955' TURING.20:1•473 ; 4 500 2A ",.039 53j P...225 51 !2 50 15C5.80 VA0.1 ACE; 3.985 P20 JT:so A. 9 55! 0,215 44 '.'250 ISCR50 VAN1.,;,,-..E. 3,953 I* 01 5K i 4 500' ' i n 91 IRJP Si X0 4 5030' !, ! 9.59 3.252 2(11 IT.6,3 13CR50 1JAP.1 ACE. 3.358 c114:70:01,Ni 1:22 v.,,t, ov•sic j :::::1 ri i 375 55 92631181 12 6c! 130350 vAtal AC,E, 3.558 N ur JT XC1 ...... ___.„ ......_ ... 2.1,,IP.52y0 1 USING,i0NTS.,,- ,1„JP..,,,1r XC H'Es x NIPPLE 1 A 51)0 i 1 1485 9.641!74 12 50'.tnP.so vAN.1 ACE!i 3.359 5 5m1 9,6151 nn 0 op, 9CR t..16.A-,..-r ! 1.309. ' A 5,Na 1 g95 i 9. 55 491 1.4-60!1,3C110-:vADR A CE 3 9501 • , . ,. 4.51,-.-,! i 1 42.041 9.568.351 12.50:13C.R5S Mare,A,CE! 19531 . 4.5013 1 4.500 1 3.591 9.'10.301 12.60 ',3C5.6.7: 't.,,,440 AcEl 3_?6,8! 1.14 9.720.251 12.60, 9CR 14.037 i I 3t..J?_IT XO 4 Irr, ,7 15:,111.1 5 T2-1 421 12 Tin:IICR57.7k.'4,‘4 ACtr51 3. .958 .3,AKEF'.:tr,3'PAcKE r; 7.003 1 ' 3.78' 3,741.21 26.00. 9CR ;Nr.,, -1, CT 2 5'7.55' - 1-LiBlf4G P..1.P..,77 4.”,n1): 7 19/1 g '44.59 12(la i 13C.FZEZ 1.4:517.,Y , 33.911 I Ht77.9 X NIPPLE . A.500 1 s.15 1;?Id r'n ;2AI') 9(2.R. i f.45.61 'TUBING PUP J.* - ! 4.500i 2 13.72, 3.75-135 12,601 12CR80:NSCT 2.255 IHES 1414 Nov NIPPLE ' 4 50' ". 1 21 :5.75,152 12 50! 9CR 141)1117 3l'1.,?., . .. 171.18INN3 F-F.F...17 .:, 4'.5.001 i 3 35 0,755 7a **2 30,11.3c880 INC..5cT 3958 .. . - ---1 hATI._-E-6. 5,1.370 I , 7?.:05 54 "2 5..C1., 747.9: 142C.7 21)1111 1------------ ! -74,, ._-_- ! ......- ; ,fl'-...r1' ' 10 • • OF 771,0&'‘'\ �7��� THE STATE Alaska Oil and Gas ��� ®fAT i\ S}(/\ sKA Conservation Cornmission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 OM www.aogcc.alaska.gov Aras Worthington 50 Wells Engineer 0 BP Exploration (Alaska), Inc. aiD - `77t P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P1-18A Sundry Number: 315-616 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it. may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster glay Chair DATED this of October, 2015 Encl. sG RBDMS OCT 14 20c RECEIED STATE OF ALASKA 9fl • • ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROSL P 3 Q 2013 20 MC 25.280 lo I 131 ) 5 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ P s� ult own❑ Suspend 0 Perforate o Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ® Re-enter Susp Well 0 Other OA Cement Sqgpeze 0' 4195vr ,u 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-076 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development H 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22953-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 Nom PTM P1-18A' 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028297, PRUDHOE BAY.PT MCINTYRE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10641 • 9236 • 10539 - 9152 • Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 4461 9-5/8"40#L-80 28-4490 28-4476 5750 3090 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10070-10438 8756.52-9067.85 4-1/2"12.6#13Cr80 13Cr80 23-9797 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and ND(ft): 9740, 8470.30 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal RI • 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development ® ' Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: . Oil ® Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned o Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Worthington,Aras J Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signaturer/3D,,,,...X %S Phone +1 907 564 4102 Date /� COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 6.ca Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No Eir Subsequent Form Required: J.t7 — O 4.- (1APPROVED BYTHE Approved by: 424//4„...) 94144.44"__ COMMISSIONER COMMISSION Date:A.43_73� RBDMSJ C1 4 2015 ORIGINAL Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate jole( Wt-- /0 ;E)-,C,/C ! ! w Q O 0 0 0 0 0 co � cy) — � o v v LO N 0 CO lf) In LC) f� U v) OO000O O V V co • N- N N N m r IC) I- N- CO O (.0 O) O O O Cr) LO N N V M N If) O O) O) co 0 F- a7 O O7 co CO co O co N N N M ,- N CO O) 4.0 O O M N O) O t O) C3 O� O) 2 I 44.+ co Q O) O O O7 M co T.., N N (Ni O N = a O I— O CL O O 0 1 OJco cO co C7 C = U ' Q) *k -1-1 M J _ CO 1* O 07a0C4CON O CV CV N O) N 4 t O CO 3 O d N- = co CC) C) O N- J O) O O) Z Z Z a)O 000 7500000 0 O u O p O Z Z c Q O O ada. � by • • P1-18 OA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Chidi lgkobokwe (907) 564-4755 History On 04/09/11 P1-18 failed an MIT-OA with fluid to surface in the conductor pipe. The LLR from the OA was estimated at 0.2 gpm @ 200 psi. An OA fluid depression utilizing nitrogen indicated a surface casing leak near the surface. The well was reclassified as "Not Operable". A Well Lock treatment was performed on the conductor in the summer of 2015 but the conductor was not topped off with the second stage of Well Lock that was originally planned due to ongoing investigations into the V-101 conductor Well Lock job. A post Well Lock MITOA failed with a slight leak to the conductor still present. Current Status The well is currently classified as "Non Operable" by BP due to the OA x Conductor leak. The well is therefore currently shut-in until the leak is fixed. Objective The objective of this job is to cement the OA (7" x 9-5/8") annulus and make this well operable. Cement will be pumped down the OA from surface in two stages (if needed). The goal is to have cement in the OA from the 9-5/8" casing shoe to surface. Any voidage in the OA left after the cement jobs will be filled/squeezed with well lock, squeezecrete, or similar product if needed. Procedural steps Fullbore 1. Establish injectivity rate and pressure with diesel down the OA and into formation. Cementers 1. RU to the OA. 2. Pump enough Class G cement to fill OA to surface displacing OA fluid into formation. SI and allow cement level to reach equilibrium. 3. WOC to build strength. 4. Pump a second cement job to refill OA to surface (if needed). Special Projects 1. WOC to build strength. 2. Strap the TOC in the OA. 3. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product if needed. I - TREE= 4-1/16"CM/ 9 • WELLHEAD= FMC GEN 5 l 4 -18A SAFE E CSG*: ***4-12"CHROME TBG&7" ACTUATOR= BAKER C KB.ELEV= 37.3' BE. F. EV= 8.8' I 1 KOP_. v 4491' H1 O _ _ -Mix—Ana-le= 48°@ 7540' 2227' —14-1/2"CAMCO BAL-O SVLN,ID=3.813" IDatum MD= 10164' / GAS LIFT MANDRS EL Datum 8800'SSJ /' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 4187 4177 7 KBG-2 DMY BK 0 08/05/11 /1---- 5 5300 5195 41 KBG-2 Dtv1Y BK 0 06/09/02 Minimum ID = 3.725" @ 9786' 1 ,/ 4 6797 6248 44 KBG-2 DMY BK 0 08/05/11 4-1/2" HES XN NIPPLE0 3 8210 7267 42 KBG 2 DMY BK 0 08105/11 0 2 9246 8045 33 KBG-2 DMY BK 0 01i06l10 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OF WHIPSTOCK I— 4491' MI 9-518" MILLOUT WINDOW 4491'-4507' 9-5/8"CSG.40#,L-80,ID=8.835" — 4610' it�4044-1.1.41.411....W.4 7"CSG,26#. L-80 BTC XO TO 13CR-80 — 9631' X X ' , I 9720' H4-1/2"HES X NIP,ID=3.813" I X x. 9741' 1—4-1/2"X 7"BKR S3 PKR,ID=3.875" 9765' H4-112"HES X NIP,ID=3.813" I IF • 9786' H4-1/2"HES XN NIP,D=3.725" 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,ID=3.958" — 9797' I / \ 9798' H4-1/2"WLEG, D=3.958" 9796' H ELMD LOGGED ON 05/04/04 PERFORATION SUMMARY 0.—I 9838' I—7"MARKER JOINT I REF LOG: ANGLE AT TOP Pff r: 31°@ 10071' Note:Refer to Production DB for historical pert data SIZE SPF tJTERVAL Opn/Sqz DATE 3-3/8" 4 10071 -10091 0 05/04/04 3-3/8" 4 10091 -10111 O 05/11/03 3-3/8" 6 10205-10220 O 05/20/02 2-7/8" 4 10241-10271 O 05/15/03 3-3/8" 6 10292-10418 O 05/20/02 3-3/8" 6 10428-10438 0 05/20/02 7"CSG,264,13CR-80 VAM TOP XO TO L-80 BTC —{ 10539' i-- .vvyttyvitir.• I STD H 10538' 000.00 7"CSG,26#,L-80 BTC,.0383 bpf,ID=6.276" —I 10623' 1.0,0AW•W DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 07/17/10 RLW/PJC ELK)LOGGED 05/04/04 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWING CORRECTION PERMIT No: 2020760 10/11/05 JDM/PAG ADPERF CORRECTION 08/15/11 MSS/PJC GLV GO(08/05/11) API No: 50-029-22953-01 10/25/07 JLJ/TLH GLV C/O(10/18/07) SEC 16,T12N,R14E, 1394'FSL&880'FEL 05/17/08 DTR/TLH GLV C/O(04/27/08) 02/03/10 JLJ/PJC GLV C/O/01/06/10) BP Exploration(Alaska) 2 RECEIV D E STATE OF ALASKA • "'ALASKA OIL AND GAS CONSERVATIONCOMMIAN SEP 3 0 2 ?;l REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed AO G c c: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Well Lock Iii 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-076 ' 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22953-01-00. 7. Property Designation(Lease Number): ADL 0028297 8. Well Name and Number: PTM P1-18A • 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 10641 feet Plugs measured feet true vertical 9236 feet Junk measured feet Effective Depth: measured 10539 feet Packer measured 9740 feet true vertical 9152 feet Packer true vertical 8470 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 4461 9-5/8"40#L-80 28-4490 28-4476 5750 3090 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth: Measured depth: 10070-10090 feet 10090-10110 feet 10205-10220 feet 10240-10270 feet 10292-10332 feet 10332-10398 10398-10418 feet 10428-10438 feet True vertical depth: 8757-8774 feet 8774-8791 feet 8872-8885 feet 8902-8927 feet 8945-8979 feet 8979-9034 9034-9051 feet 9060-9068 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 23-9797 23-8520 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Hydro Set Packer 9740 8470 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Surface of Conductor Treatment descriptions including volumes used and final pressure: � �1` 8 Gallons Well Lock,Atmospheric Pressure. SCAMP 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 458 2031 5177 2080 703 Subsequent to operation: Shut In 250 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Gd Exploratory 0 Development IJ Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 • WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-323 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 5,44VA ,4 7 Ce Phone +1 907 564 4424 Date 9/30/15 Form 10-404 Revised 5/2015 0 l n�/1� /�• 4o-IJ � RBDMS-15 V V t L iU 15 Submit Original Only • m • 0• CD O O O O Ctl h. 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(a II 1" 0 II o -0 -C L U O a) O II E !�N_ • H J m > H 0_ ° a) > E C > (DE oc � o ° a > H = > cu ea Q >, ° _ 2 a) 0 2 H U U N a) ' 2 H C CI Ci o u) H L O ° o u) O O a o 5.. ci 20 - o O -c N o Q u) ) o co 73 L0 a) ° II i0 ).-2 co O II N II 4- Or O° �� V to -O 11 N E p > N N (n-50 > c) 2 > CV •5 . C N to > -c O > N > co cn > ° ° cn N . 0 > � U 3 N CD v) N }. U U) > c 2 EE u) U D tocn > :C co ,O Q :� .0 (n > C .cU) U) U Y > (n O ` C C/) .- Y fn w II U _ II E ` (n ao II p U ca fn _ — c- — — — (,) o O II co O O ": ,. O o - a) O ° 00 -028 .c 0 o tO a) ° > m -5oo ° > > �aoa � > a > � *H 3 2 = ) H o o U) II: .5 U) � m e 3 8 E W H 3 u) H : w I- to to to to Un to O O O O CO O H to <v d' i 17)N N N N U to a) to co N- Q 0 . / / p / 2 e 2 S < g o / § / < 0 ° o o » c o 2 = .g g C = $ 2f ± a) -0 > US2o mg / � / d ��® \ ' o �1 m \ < ± C / / .,7_ 0 CO as 2 E 2 — % E iI / § \ H 0 < _122 sa 2 • \ 0 = ± 2 0 I I LI R '- < - / > 0.1 o_ C ® § CO M ¢ % o r 1— f & 0- / 0 0- 6 g2 b a . .g / \ Ce 2 II ) _1 > & /\ q .. CU . E o q \ E 9 » • B + = g o g % \ e 0 c 2 / a CD§ @2 .glmo .R \ / S « �� / 2 \ § a � u) 0 S / U / / ƒ II $ CD �i �� % $ 0 c Cl) $ / 2 t t — E S % f & Q 2 \ 3 $ 5 $ to (i) / ® / & CO 0 N- 1"---- w CO TREE= 4-1116"gVit • SA NOTES: "'4-12"CHROME TBG&7" WELLHEAD= FMCGEN 5 P -11 8A CHROME CSG*** ACTUATOR= BAKER C v KB.ELEV= 37.3' BF.ELEV= 8.8' I I KOP= 4491' Max Angie= 48°a 7540' 2227' -14-1/2"CAMCO BAL O SYLN,D=3.813" Datum MD- 14164' GAS LFT MANS Datum TVD= 8800'SS ST MD ND DEV TY PE VLV LATCH FORT DATE 6 4187 4177 7 KBG-2 DMV BK 0 08/05/11 Minimum ID =3.725" (9786' 5 5300 5195 41 KBG-2 DMV BK 0 06/09/02 4-1/2" HES XN NIPPLE I ' I 4 6797 6248 44 KBG-2 DMY BK 0 08/05/11 �y 3 8210 7267 42 KBG-2 DMY BK 0 08/05/11 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 1 9652 8393 30 KBG 2 DMY BK 0 01/06/10 TOP OF WHIPSTOCK - 4491" 9-5/8" MILLOUT WINDOW 4491'-4507' 441.4•144.44441 1�1��V�I� 9-5/8"CSG,40#,L-80,0=8.835" -{ 4610' 4.4.4.4.4.44.4.4.44.4.44.4. 7"CSG,26#,L-80 BTC XO TO 13CR-80}- 9631' X X I I 9720' -14-1/2"FES X NP,ID=3.813" X X 9741' H4-1/2"X 7"BKR S3 PIR,D=3,875" I I 9765' -{4-1/2"ISS X tom',D=3.813" I I 9786' -I4-11T I-ES XN MP,0=3.725" 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,D=3.958" }- 9797' I--- / \ 9798' H4-1/2"'LEG,D=3.958" 9796' I--ELMD LOGGED ON 35/04/04 PERFORATION SUMMARY REF LOG: 01. 9838" -17"MARKER JOINT ANGLE AT TOP PERE: 31°@ 10071' Note:Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 10070-10090 0 05/04/04 3-3/8" 4 10091-10111 0 05/11/03 3-3/8" 6 10205-10220 0 05/19/02 2-7/8" 4 10241-10271 0 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8' 6 10428-10438 0 05/17/02 7'CSG,26#,13CR-80 VAM TOP XO TO L-80 BTC H 10539' PBTD H 10538' 1111111111111111111111 1111111111111111111111 7"CSG,26#,L-80 BTC,.0383 bpf,D=6.276" H 10623' 0.1.1.1.1.1.1.1.1.1.., DATE REV BY COMMENTS DATE REV BY COMMENTS PRI IOE BAY UNIT 12/08199 ? ORIGINAL COMPLETION 07/17/10 RLW/PJC ELMD LOGGED 05/04/04 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWING CORRECTION PERMIT Nu: 2020760 10/11/05 JDMIPAG ADPEW CORRECTION 08/15/11 titSS/PJC GLV C/O(08/05/11) API No: 50-029-22953-01 10/25/07 JLJ/TLH GLV CYO(10/18/07) 05/20/15 PJC PERF CORRECTIONS SEC 16,112N,R14E, 1394'FSL&880'FS 05/17/08 DTR/TLH GLV CIO(04/27/08) ' 02/03/10 JLJ/PJC GLV C/O/01/06/10) BP Exploration(Alaska) • v•OF Ty •��w\ I y ,\ THE STATE Alaska Oil and Gas Conservation Commission iAsKAL _,_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 vrfOF .*.�' Main: 907 279 1433 ALAS Fax 907 276 7542 SCAptEDJUN 0 5 9L-1315 www aogcc.alaska gov Aras Worthington Well Intervention Engineer0 17Z BP Exploration(Alaska), Inc. O ✓ P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P1-18A Sundry Number: 315-323 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,X41 Cathy Pi Foerster Chair DATED this 2-'day of June, 2015 Encl. STATE OF ALASKA RECEIVED , ALA: -,-%OIL AND GAS CONSERVATION COMM,�SION RECEIVED • APPLICATION FOR SUNDRY APPROVAL MAY 2 2,2 015 20 AAC 25.280 O7S 612/45 G/45 1 Type of Request: AOGCC ❑Abandon 0 Plug for Redrdl 0 Perforate New Pool, ®Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ❑P Il Tubing 0 Time Extension vh)cv-oann✓/4l L^'C"i/'Gk ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate Alter Casing ,®Other Y 6 SC!'r4 1 2. Operator Name 4 Current Well Class 5 Permit To Drill Number BP Exploration (Alaska) Inc. ❑Exploratory 0 Stratigraphic 202-076 • 3. Address 6. API Number: e,Alaska 99519-6612 ®Development 0 Service P.O. Box 196612,Anchorage, 50.029-22953-01-00 7 If perforating' 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU P1-18A Will planned perforations require a Spacing Exception? 0Yes N 9. Property Designatior oreig 7 10. Field I Pool(s). ADL_9. 2g298^ A bs.-z4'6 Prudhoe Bay/Pt McIntyre • 11• PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured) 10641' • 9236' • 10539' • 9152' • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 29'- 104' 29'- 104' 1490 470 Surface 4462' 9-5/8" 29'-4491' 29'-4477' 5750 3090 Intermediate _ __ _ __ Production 10596' 7" 27'- 10623' 27'-9222' 7240 5410 Liner Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade Tubing MD(ft): 10070'- 10438' 8757'-9068' 4-1/2", 12.6# 13Cr80 9798' Packers and SSSV Type' 4-1/2"x 7" Baker S-3 Packer Packers and SSSV 9741 /8471' MD(ft)and ND(ft). 12. Attachments. 13.Well Class after proposed work: ® Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work. Commencing Operation June 7,2015 . ®Oil 0 WINJ 0 WDSPL 0 Plugged 16 Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: ❑WAG 0 SPLUG 0 Suspended 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthington,564-4102 Printed Name. Aras Worthington , Title. Well Intervention Engineer Email: Aras Worthington@bp.com Signature: / ' ' - 5/2)//'3-- Phone: 907-564-4102 Date Commission Use Only Conditions of approval' Notify Commission so that a representative may witness Sundry Number 31 5_ 3.2.: ❑Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance Other: Spacing Exception Required? 0 Yes 2/No Subsequent Form Required: IC — 4 c 4 Approved By' APPROVED BY C 2_ COMMISSIONER THE COMMISSION Date: "7S Form 10-403 Revise 10/2012 i id for 12 months from the date of approval Submit In Duplicate VII� /zr�//S OR1 '1NA RBDMS M JUN - 3 2015A 5,746/ l ' // s zG /S To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 05-21-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: P1-18 WellLock Conductor Treatment Objective This program is for treating surface casing response to pressure by external repair with WeIlLock. The well fails an MIT-OA. WellLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to place the WeIlLock between the conductor and surface casing to mitigate the leak. Approximately one week before treatment, put under evaluation and POP to warm well and aid in treatment/curing of resin. Well Detail Current Status: Not Operable — PAL Previous Test: 08-28-2012 MIT-OA Fail Integrity Issues: Surface casing leak Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg Diesel: 6.8 ppg Temperature: Maintain 750-80° F throughout the entire job, leave heater trunks in well during cure period (one week) Relevant History: > 08/18/12: MIT- IA Passed to 3000 pi. > 08/28/12: OA LLR = 0.2 gpm @ 200 psi, SC Leak @ — 10' 8" I of 3 Procedure 1 D Thoroughly clean the conductor by surface casing annulus to remove any deleterious material. This include steam washing the annulus and cleaning with detergent. 2 D Run open bleed on OA during the entire job. 3 D ***Pump WeIlLock into conductor by casing annulus. 4 D Allow WeIlLock to cure for one week. 5 D MIT-OA to 1200 psi with diesel *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 2 of 3 TREE= 4.116'OW --- ------- --------_----..._1 NAELLFEAU- MC;C;EN9 P1 -1 ESA SAFET MOTES .1 42"CHROME TBGd 7" ACTUATOR= BAKER Kai H FV= 373' BF ELEV= 8 8 I I I KOP= 4491' Max Angle= 48'@754Uo Z2 fi'— �1If"(.A RAl.O@AI 05VN,0^:3813`. Daum ACT- 10154' __._.._.__.._ GAS LFT M4K:NI5 Datum ND= 5807 55 ST AO 1 TVD IPI TYPE VLV LATCH PORT DATE 6 4187 4117 1 Kik.;-7 IAN tiK 0 7010=4'11 Minimum ID=3.726" r, 9786' 5 53m5195 41 K0(1 2 CAM BK 0 06t09'02 4-1/2"HES XN NIPPLE Ir 4 679716248 44 KLG-2 CMY ON 0 08/05/11 3 8710 1767 47 4i1G-7 1U' 13K 0 OOtDS/11 2 9246 3 8045 33 K06.2 CAM BK 0 01106110 1 9652.1.8393 30 K.DG-2 CAM DK 0 01106/10 __ - - - , I 0;18'11111 I001 WINDOW 4491'494}!• 1 nJPoFWIIPAtrxx---% 4491' 1911011 ,9-).,11-CSO,aart. -80 0 8839 + 4610 11.4.11.0.11.0.4.11.9.11.4.4.4.11.11. rr C9c.264.L•80 BIC 60 10 13C3E00 I-I 9831' j--,,,-, 1 1 [ 9720' H4-112'HES XNP.ny3.813'I X w< L 9711' 4 yr X r MR EZ RCR 11^1679' 1 1 L976 ' H4-1rr/+FSXMP,0=3013' I I I I 9766' H4-1/71-ES Xfl PIP,ID=3 125' I4-12'IfiG 12 6%,13CRa0 0192 b6r, 3898" H 979T I \—H 979B' 4 112.% I t3,ID 4 3068-"" i 9796' I--{aw LOGGED oN 35,64.,134 PERFOR.TION SLOAVARf t{X; ►--[ 9838' Hr PARKER JOIr1T I ANGLE AT TOP PERF: 31"1t 10071' Note:Refer to Production C8 for historical perf data SFE SPP P41BNAL Opra(Sgz SHOT SQZ 3-318' 4 10070-10090 0 05104:044 3-3(8' 4 10091-10111 0 05/11X13 3 mr 6 10005-10770 0 05119/02 2-718" 4 102N)41-10271 0 0`115103 3 318' 6 10(0 10418 0 0E420102 3-316' 8 10428 10438 0 05/17/02 IT'C_5(i 264 13CR-00 VAM TCW XO TO I 80 RTC I—I 10539' I-- p Tip* • EMT° 10538' 4 0i450 /'C:tit.23#Ll tiIC:..0J&(bp/-iy-8.2/0'I.....I 10623' "•""" DATE REV 8Y COMMIS - DATE REM Rv j;; - c33M 7r5 PR OF:I E RAY UNIT 12/08199 ' OfEMW L COMPLEIICXN 001 1110 13.N1PJU1.J.A1D LOGGED 05434104 3MH_L P1-1P.A 05(05!02 NAB l0 WTRACK(P1 10A0 09115111' MC 117' 043 CORRECTION PERMIT 14a, 2020760 10/11/05 J301.4PAt AI1444 C21184-C1K7N cmii'f11 WS/P,tCA V CIO(0&'05111) Ail No 50-029122953-01 'whin 7 JI.110 1 a V 00(10,13/00 _------ 0.500..15 PJC IRO-[X1463-Cl INC ski:16.I17I4,R2141-_1394'F.L.S B37 I-14 055/17;08_0TR11 It Cal V 00(04/07130) I 07/03(10 .1.SPJC GLV CIO(0146/10) L I3P6tpbra0on(Alas ta) 0 3 of 3 ImagE. )roject Well History File Cover ~ ~1e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ O~ - 0 7 !o 'Well History File Identifier Organizing (done) RESCAN 0 Two-Sided ~escan Needed 0 Color items: I" ~ Grayscale items: DI~TAL DATA ~ Diskettes, No. OVERSIZED (Scannable) I 0 Maps: Other items scannable by large scanner 0 Other, Norrype 0 0 Poor Quality Originals: Other: OVERSIZED (Non-Scannable) 0 0 Logs of various kinds NOTES: BEVERLY ROBIN VINCENT SHERYL Q - -INDY \.(V1ARI~ 0 I ~ DATE:r" J' ðLJ. Isl Other BY: w Project Proofing BEVERLY ROBIN VINCENT SHERYL ~INDY 1 I DATE: l' ó'f Isl , ' Jl ~}j BY: 111"0 + 10, = TOTAL PAGES 7 Lj DATE 7 ¡/bet/sl V}t° 5" CmJi.R.ÃJ 'f~ ouL<Lu1 7 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: VYES - NO DATE'ð'I'l7ftlf-'S/ YVl P ~ x 30 = Þn Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERY~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: BEVERLY ROBIN VINCENT SHER~ WINDY Stage 2 IF NO IN STAGE 1 PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REOUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (ilJ¡fi\~ido;;/ lUff: [."/~~~".i.ll i"fr~l11iol } 5,r;,\iJnilr¡J ::nmple/od) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (dl)ll(~\ 12/10f02Rev3NOTScanned,wpd '�' � L> Y•k;.- d: u:.'S rA.. e3" ).'.i. ,'til jr.�o J, ,,���\�1//7, ,a THE STATE A a , u - , a. 4r, 7\ ;r / ( i ;\ ,, /,.---&-„,-,,, ,,,--,„„,,,,,, - i�-.� r e�f�' II \ i 333 Vilest Seventh A\enue (;,,,,s,-, " 0 G0 LI:\GR SLA\ .'AIS\1I.I. Anchorage Alaska 9950 3572 �� situua F- �}}(r�it ,n n/ i ' 3 SII R_ �� LUt an i i ' Aaron Ramirez b Well Intervention Engineer as 0 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P1-18A Sundry Number: 314-038 Dear Mr. Ramirez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ID;4,Ic_.___ Cathy P Foerster Chair DATED thisZday of January, 2014. Encl. • 411( �� . . STATE OF ALASKA ,ti ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 yrs t� `� l 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool El Repair Well 0 . f �� gram❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development Q • 202-076-0 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22953-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PTM P1-18A Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028297 • PRUDHOE BAY, PT MCINTYRE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10641 • 9236 . 10539 9152 None None Casing Length Size MD TVD Burst Collapse 1 Structural Conductor 80 20"91.5#H-40 30-110 30-110 Surface 4462 9-5/8"40#L-80 29-4491 29-4477.32 5750 3090 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 25-9798 Packers and SSSV Type: 4-1/2"Baker S-3 Hydro Set Packer Packers and SSSV MD(ft)and TVD(It): 9741,ND Top No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑✓ '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑✓ . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aaron Ramirez Email Aaron.Ramirez©BP.Com Printed Name Aaron Ramirez Title Well Intervention Engineer Signature ---,5 Phone 564-5943 Date iiJao ( Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ,t O. %." Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / ✓ MAY U 9 .o DGv� e✓� f e RBDMS 2014 Spacing Exception Required? Yes ❑ No L Subsequent Form Required: /0 _401 /�n/ APPROVED BY Approved by: - // / ?c,?..__,..7(.4----- COMMISSIONER THE COMMISSION Date: /.. Z a— Form 10-403 Revised 10/201 A rov $ from the date of approval. Submit Form andiAttachments in Du to ,� `L r ///� // PP �1 tINrAntliths pp �+ l/�6�f `V, O Ooo °Oo02 � � Coco - Co - Ur 2 J J M J M r � 4) Q O 0 0 0 0 0 N f� CA 0 — 'V O Lf) p la in co co r- 0 vvco�) = N N N ti CO • ti r, co CO a) N OC N — N N- O CO O N 10 N- 0 `- 0)) MO d) co a O _ M 0) N N N CO CIS N. E rn N C %V N M 1- O r CO co m co 0) 0) 0) CO 20 D) J C 1.• 7.! n rn Co ' � O10tid) 0) 10 0 M O N N N O O O o o0,2° °9 M co Co0J � QJ * J J M 8 it • Ln * � (O .co • co co ,73-; N N N DO O - ' CV O 4 L O O c�D a0 (NC) N- o 00 CO LO rn °) v rn J ceZZz O 0 0 0 CAI- I H H LJj N D D D D UQ 0 v o 0 0 0 z Z O O O c m OCLCLCLDD O aCl_ acDI- 1 Perforation Attachment ADL0028297 Well Date Perf Code MD Top _ MD Base TVD Top TVD Base P1-18A 5/4/04 APF 10070 10090 8757 8774 P1-18A 5/11/03 APF 10090 10110 8774 8791 P1-18A 5/19/02 PER 10205 10220 8872 8885 P1-18A 5/15/03 APF 10241 10271 8902 8928 P1-18A 5/19/02 PER 10292 - 10332 8945 8979 P1-18A 5/18/02 PER 10332 _ 10398 8979 9034 P1-18A 5/17/02 PER 10398 10418 9034 9051 P1-18A 5/17/02 PER 10428 10438 9060 9068 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF TREE= 4-1/16"CM/ WELLHEAD= FMC GEN 5 P 1 -18A SAFETY. ._S*****4-12"CHROME TBG&7" . ACTUATOR= BAKER C CHROME CSG KB.ELEV= 37.3' BF.ELEV= 8.8' I I KOP= 4491' Max Angle= 48°@ 7540' - 2227' —14-1/2"CAMCO BAL-O SVLN, ID=3.813" Datum MD= 10164' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 4187 4177 7 KBG-2 DMY BK 0 08/05/11 5 5300 5195 41 KBG-2 DMY BK 0 06/09/02 Minimum ID = 3.725" @ 9786' I '1 4 6797 6248 44 KBG-2 DMY BK 0 08/05/11 4-112" HES XN NIPPLE 3 8210 7267 42 KBG-2 DMY BK 0 08/05/11 2 9246 8045 33 KBG-2 DMY BK 0 01/06/10 1 9652 8393 30 KBG-2 DMY BK 0 01/06/10 TOP OF WHIPSTOCK H 4491' 9-5/8" MILLOUT WINDOW 4491' -4507' .1414144V•I'ff CC 404000004 9-5/8"CSG,40#,L-80,ID=8.835" —I 4610' .............•..1.....1...1... 7"CSG,26#, L-80 BTC XO TO 13CR-80 — 9631' X X ' ' 9720' I4-1/2"HES X NIP,ID=3.813" X x 9741' —I4-112"X 7"BKR S3 PKR,ID=3.875" 9765' R4-1/2"HES X NIP,ID=3.813" ' ' 9786' —14-1/2"HES XN NIP,ID=3.725" 4-1/2"TBG, 12.6#,13CR-80, .0152 bpf,ID=3.958" —1 9797' I-- 7 \— I 9798' —14-1/2"WLEG,ID=3.958" 9796' --I ELMD LOGGED ON 05/04/04 PERFORATION SUMMARY 410I 9838' —7"MARKER JOINT REF LOG: ANGLE AT TOP PERF: 31°@ 10071' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10071 -10091 0 05/04/04 3-3/8" 4 10091 -10111 0 05/11/03 3-3/8" 6 10205-10220 0 05/20/02 2-7/8" 4 10241 -10271 0 05/15/03 3-3/8" 6 10292-10418 0 05/20/02 3-3/8" 6 10428-10438 0 05/20/02 7"CSG,26#,13CR-80 VAM TOP XO TO L-80 BTC —I 10539' I— ,•••••tir••r PBTD —I 10538' 0000.0 ............ .......i 7"CSG,26#,L-80 BTC, .0383 bpf,ID=6.276" —I 10623' .•.•.A.A.A.A.A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/99 ? ORIGINAL COMPLETION 07/17/10 RLW/PJC ELMD LOGGED 05/04/04 WELL: P1-18A 05/05/02 N2ES SIDETRACK(P1-18A) 08/15/11 PJC DRAWING CORRECTION PERMIT No: 2020760 10/11/05 JDM/PAG ADPERF CORRECTION 08/15/11 MSS/PJC GLV C/O(08/05/11) API No: 50-029-22953-01 10/25/07 JLJ/TLH GLV C/O(10/18/07) SEC 16,T12N,R14E, 1394'FSL&880'FEL 05/17/08 DTR/TLH GLV C/O(04/27/08) 02/03/10 JLJ/PJC GLV C/O/01/06/10) BP Exploration(Alaska) by 0 Date: January 2, 2014 To: AOGCC From: Aaron J. Ramirez, Well Intervention Engineer a'0 Subject: Sundry Notice 10-403 Approval Request BPXA Well Point Mac. Drill Site P1, Well 18 (P1-18) This application for Sundry approval for BPXA Well P1-18 is for the inspection and repair of surface casing. Currently, part of the surface casing on this well is exposed to atmosphere, most likely due to corrosion. Well P1-18 has been determined to have a surface casing leak at an estimated 11 feet from surface. BPXA requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will follow the general, outlined procedure below: 1. Secure the well from the reservoir with plug(s), kill weight fluid and BPV. 2. Remove the cellar, wellhouse, tree, flowline and other equipment necessary for repair. 3. Survey existing utilities and other critical infrastructure, including the wellhead. 4. Drive piles to support the wellhead and well support frame. Drive sheet piling for excavation around well. 5. Install wellhead and well support frame. 6. Excavate inside the parameters of the sheet piling, to an estimated bottom depth of 20 feet. 7. Install nitrogen purge equipment for conductor (and OA if needed) so that hot work may be conducted in a safe manner. 8. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC inspector for opportunity to inspect. 9. Install repair patch needed to return the casing to operational integrity. 10.Patch will be inspected for acceptance. 11. Perform MIT-OA. 12. Install external wrap on casing to safeguard against future, potential corrosion. 13. Backfill and compact around well and install cellar. 14.Demobilize wellhead and well support frame. 15.Reinstall tree, flowline and wellhouse. Remove plug(s), BPV and hand well over to well integrity for evaluation. 16.File 10-404 with AOGCC post repair, complete with pictures demonstrating repair. 1 • • /SEAN PARNELL, GOVERNOR siforl 0[F ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Bob Gerik Petroleum Engineer a BP Exploration (Alaska), Inc. a,� �Y ' P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, P1-18A Sundry Number: 311 -141 Dear Mr. Gerik: S :. ED APR 2 9 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this of April, 2011. Encl. . STATE OF ALASKA CEIVED ALASKA •AND GAS CONSERVATION COMMISSIO• APPLICATION FOR SUNDRY APPROVALS APR 2 f 2011 �°� 20 AAC 25.280 Q 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Make Repair Well ❑ e Otar ,ti<x d titelow04 Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ ,` .*r +, :"Pin1Q Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: BRINKER/CASING LEAK El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Ei Exploratory ❑ 202 -0760 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22953 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ P1 -18A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028297 PRUDHOE BAY Field / PT MCINTYRE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10641 - 9236.45 - 10539- 9151.75- NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 30 110 30 110 1490 470 Surface 4462' 9 -5/8" 40# N -80 29 4491 49 4477 5750 3090 Production 10595' 7" 26# L -80 27 10622 27 9221 7240 5410 Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - 4 -1/2" 12.6# 13Cr80 25 9798 Packers and SSSV Tvpe: 4 -1/2" Baker S -3 Perm Packer Packers and SSSV MD and TVD (ft): 9741 8471 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/10/2011 Oil 0- Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Gerik Printed Name Bob Gerik Title PE Signature /, ,/ wry(, Phone Date ���g ✓d 564 -4476 4/26/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3?J 1 ' 1 L/ 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /D _ gi O4, APPROVED BY 2 Approved by. COMMISSIONER THE COMMISSION Date: 4 i V". 1 RRDMS APR 2 Y.27" y Form 10-403 Revised 1/2010 `�, , 0 R I GI N A L // Submit in Duplicate P1 -18A 202 -076 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P1 -18A 5/17/02 PER 10,398. 10,418. 9,034.49 9,051.19 P1 -18A 5/17/02 PER 10,428. 10,438. 9,059.52 9,067.85 P1 -18A 5/18/02 PER 10,332. 10,398. 8,979.12 9,034.49 P1 -18A 5/19/02 PER 10,205. 10,220. 8,871.9 8,884.63 P1 -18A 5/19/02 PER 10,292. 10,332. 8,945.44 8,979.12 P1 -18A 5/11/03 APF 10,090. 10,110. 8,773.7 8,790.86 P1 -18A 5/15/03 APF 10,241. 10,271. 8,902.41 8,927.74 P1 -18A 5/4/04 APF 10,070. 10,090. 8,756.52 8,773.7 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • by Date: April 26, 2011 Subject: P1 -18A: Sundry Request Well Type: Producer, Gas lifted Current Status: This well is not operable due to a Surface Casing Leak. Request: Treat well with Brinker Platelets to repair the Surface Casing Leak. Well History: P1 -18A was side tracked during May, 2002 and has been a fairly strong producer since it was brought on line. The water cut was quite high, >50 %, since initial production. Also, this well has been a scaler in the past. The last cleanout was completed during February 2008. The reason for this cleanout was during late 2007 the gas lift valves were being changed and the catcher sub became stuck. It was necessary for coil to pull this sub. (2/18/08) After that operation a normal cleanout was made. Feb.18, 2008, the well was put on production. A production log was run 4/05/08 and then a new gas lift redesign was installed 4/24/08. During this operation scale was again encounter during the running and pulling. 7/29/08 a PDS caliper was run which showed restrictions in the 7" production casing. This well was shut in from April 1, 2006 to September 3, 2007 for the 24" common line re- placement. It was also shut in from 6/16/08 to 1/17/10 for voidage replacement. Scale inhibition jobs were pumped 2/24/10 and 12/17/10. Crude like fluid was noted in the cellar 3- 18 -10. The cellar box was removed with spill containment installed around conductor 3- 28 -10. UT inspection on well head /casing spool adapter on 3 -30 -10 looked good. The well passed an MIT -OA to 1000 psi w /diesel on 3 -31 -10 and the celler box was reinstalled 4- 18 -10. On 3 -22 -11 fluid was noted in the conductor. On 4 -09- 11 the well failed an MIT -0A with diesel to 1200 psi and with N2 to 200 psi. LLR- OA were established with diesel at an average of 1.3 to 1.4 GPM from 640 to 840 psi on 4- 23 -11. • Scope of Work: The surface casing leak depth is estimated to be near surface. Brinker platelets will be pumped down the outer annulus with returns to be vacuumed out of the cellar. The Brinker platelets form a seal by deforming the platelet, pushing it partly into the hole in the surface casing. The OA is then pressured up to 2000 psi to fully set the platelets. The OA will then be bled to approximately 200 psi to keep the platelets seated and the well will then be re- evaluated by the Well Integrity Group for re- classification. With a successful MIT -OA, the well will be re- classified as Operable and produced. Production Engineer: Bob Gerik (907) 564 -4476 Attachment: Current Well Schematic. 2 TREE= 4- 1/16" CM/ WELLHEAD = FMC GEN 5 1 18A CHROME SG * ** 4 -12" CHROME TBG & 7" ACTUATOR = BAKER C KB. ELEV = 37.3' BF. ELEV = 8.8' KOP = 4491' Max Angle = 48° @ 7540' 1 CAMCO BAL -O SVLN, ID = 3.813" 1 Datum MD = 10164' 11 GAS LIFT MANDRELS Datum TVD= 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 4187 4177 7 KBG -2 DOME BK 16 01/06/10 5 5300 5195 41 KBG -2 DMY BK 0 06/09/02 Minimum ID = 3.725" @ 9786' 4 6797 6248 44 KBG -2 DOME BK 16 01/06/10 -112" HES XN NIPPLE 3 8210 7267 42 KBG -2 SO BK 28 01/06/10 2 9246 8045 33 KBG -2 DMY BK 0 01/06/10 • 1 9652 8393 30 KBG -2 DMY BK 0 01/06/10 9 -5/8" MILLOUT WINDOW 4491' - 4507' TOP OF WHIPSTOCK I 4491' J tIVOIVOIVOIVVIV 41' I9 -5/8" CSG, 40 #, L -80, ID = 8.835" H 4610' 4.....1.1.....1.E..1.....t.1. I7" CSG, 26 #, L -80 BTC XO TO 13CR -80 H 9631' 1 X 17" CSG, 26#, 13CR -80 XO TO L -80 BTC H 9672' F—}G i 1 9720' 1- 14 - 1/2" HES X NIP, ID = 3.813" 1 X I A 9741' H4 -1/2" X 7" BKR S3 PKR, ID = 3.875" 1 1 1 9765' H4 -112" HES X NIP, ID = 3.813" 1 1 9786' H4 -1/2" HES XN NIP, ID = 3.725" 1 I4 -1/2" TBG, 12.6 #, 13CR -80, .0152 bpf, ID = 3.958" H 9797' PERFORATION SUMMARY / 9798' H4-1/2" WLEG, ID = 3.958" 1 REF LOG: 1 9796' H ELMD LOGGED ON 05/04/04 1 ANGLE AT TOP PERF: 31° @ 10071' ' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE I 3 -3/8" 4 10071 - 10091 0 05/04/04 3 -3/8" 4 10091 - 10111 0 05/11/03 I 3 -3/8" 6 10205 - 10220 0 05/20/02 2 -7/8" 4 10241 - 10271 0 05/15/03 3 -3/8" 6 10292 - 10418 0 05/20/02 I 3 -3/8" 6 10428 - 10438 0 05/20/02 •••••••••••■ PBTD H 10538' 1 • 00 ••• 000 ••••$ • 44 7" CSG, 26#, L -80 BTC, .0383 bpf, ID = 6.276"1-1 10622' L1.1MMAW.+ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 10/11/05 JDM/PAG ADPERF CORRECTION WELL: P1 -18A 05/05/02 DV /JM /KK RIG SIDETRACK (P1 -18A) 10/25/07 JLJ/TLH GLV C/O (10/18/07) PERMIT No: 2020760 05/11/03 BJM/TLH ADPERF 05/17/08 DTR/TLH GLV C/O (04/27/08) API No: 50 -029- 22953 -01 05/15/03 BJM/TLH ADPERF 02/03/10 JLJ /PJC GLV GO /01 /06/10) SEC 16, T12N, R14E, 1393.91' FSL & 879.94' FEL 06/13/03 JM/KAK GLV C/0 07/17/10 RLW /PJC ELMD LOGGED 05/04/04 01/23/04 AJP /KK REDRAW BP Exploration (Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~P Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, ads,- 0~6 p,-lgA Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA o NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 7/7/2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 05/08/08 ~~~~~~U~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inn s NO.4690 Company: State of Alaska ~~.. JYlt-~E ~ ~ 20~~ Alaska Oil & Gas Cons Comm t;;,r ` " lyl t~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ .... fln s:...- P1-18A GNI 12014006 PRODUCTION PROFILE 04/05/08 1~ 1y -04 12057606 RST/VVFL ~ } _ I / 04/24!08 1 1 MPL-15 12021153 MEM INJECTION PROFILE,~Z~~q~~~a !(s 1` 04/19/08 1 1 03-09 11999005 _ ~ PRODUCTION PROFILE W/FSI ~ 04/29/08 1 1 6-22A 11970825 USIT - ~ 'v 04/27/08 1 1 W-45 11978456 MEM TEMP & PRESS SURVEY O _ ! (- ac( 04/28/08 1 1 X-06 12071852 INJECTION PROFILE ~ t 04/30/08 1 1 L5-32 11975767 PRODUCTION PROFILE W/FSI ' ~~- 04/27!08 1 1 PI GACC Ar`I(IJAU/I Crl/~C oC n CIOT ov L~II>~~ ~wln w BP Exploration (Alaska) Inc. _- - - _.~.-'.-^ --.-- .._. _....,,... v•~ vv• ~^v~~ ~~. Petrotechnical Data Center l_R2-1 900 E. Benson Blvd. , - Anchorage, Alaska 99508 Date Delivered: 3 °~ ~~~`',~~ ¢'k ::q Alaska Data & Consulting S rvices 2525 Gambell Street, Sui 4 Anchorage, AK 99503-2 8 ATTN: Beth Received by: • e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiclte\CvrPgs _ Inserts\Microfilm _ Marker.doc }'=---' \ ( J *N'À~ DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020760 Well Name/No. POINT MCINTYRE P1-18A Operator BP EXPLORATION (ALASKA) INC 5!uJ- ~ j- ~ ).ðO)... API No. 50-029-22953-01-00 MD 10641-- TVD 9236./' Completion Date 5/17/2002--' Completion Status 1-01L Current Status 1-01L UIC N - -- ~-------------- --- ---- - ------- --- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~L1. ~- ----- ~._-- .-~-------- ---- ----- ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Logl Data Type ;;-Cog i ' i{:D C ! ~g :¿D Electr Digital Dataset Med/Fnnt Number Name -- --------------- Sonic 00961 GammaRay Log Log Run Scale Media No 5 Col 1 5 Blu 5 Blu 5 Blu 5 Blu 5 Blu Interval OH / Start Stop CH Received Comments 138 10490 Case 7/12/2002 LA J.?'f í~ (~ AQ-{j~ 138 10490 Case 7/12/2002 US tT t ~ (.~ .lò ~).I 10100 10498 Case 6/21/2002 ~ í c;..k"o g iqtc;g ~og ~ ;-:Rpt ED ~ -r<¡)t EÓ~ Spinner Directional Survey Temperature Pressure Production 4403 10461 Open 5/24/2002 10100 10498 Case 6/21/2002 10100 10498 Case 6/21/2002 10100 10498 Case 6/21/2002 ¡O100 10498 Case 6/21/2002 4403 10461 Open 5/24/2002 Gradiometer Directional Survey D V11506 C Tf 0'2140 C Pds Jf1'140 LIS Verification LIS Verification 4451 4451 10576 Case 1/31/2003 10576 Case 1/31/2003 10506 Case 9/20/2003 10506 Case 9/20/2003 --- !'.ED : Log ¡Íòg : LIS Verification Reservoir Saturätion RST Sigma RST Sigma 10506 Case 9/20/2003 RST Sigma 10409 Case 11/3/2003 Production Log w/DEFT - , PressfT emp/Gradio/Spinner I s/DEFT j 9950 10409 Case 11/3/2003 Production Log w/DEFT - . PressfTemp/Gradio/Spinner ¡ s/DEFT ¡ 9900 9950 ResefVoirSaturatiori Production 5 5 Blu 5 Blu 5 Blu 5 Blu 9900 9900 I I ú..log Pressure I . ~.. I Temperature 9950 10409 Case 11/3/2003 Production Log w/DEFT - ¡ PressfTemp/Gradio/Spin ner ¡ s/DEFT i i I i DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020760 Well Name/No. POINT MCINTYRE P1-18A Operator BP EXPLORATION (ALASKA) INC MD 10641 1VD 9236 tiog- ------------ Gradiometer Completion Date 5/17/2002 5 Blu JLOg Spinner u(ó C ---11751 Rate of Penetration I'ÉÓ C ) 1751 Induction/Resistivity ;~ C c/' 1751 LIS Verification L___- --------- Well Cores/Samples Information: Name ADDITIONAL INFORMATION y~ Well Cored? Chips Received? '-Y f N Analysis Received? '¥-'f"N"- - -------- ----- Comments: ---.----- J-o _r. ----- --------- --------- Compliance Reviewed By: Current Status 1-01L UIC N 9950 10409 Case 11/3/2003 Production Log w/DEFT - , PressfTemp/Gradio/Spinner! slDEFT i Production Log wlDEFT - , PressfTemp/Gradio/Spinner! slDEFT i ROP, DGR, EWR ROP, DGR, EWR Completion Status 1-01L 5 Blu 9950 10409 Case 11/3/2003 25 4491 10641 Open 25 4491 10641 Open 25 4491 10641 Open Sample IntelVal Set Start Stop Sent Received Number Comments Daily History Received? ~ cY)/N Formation Tops API No. 50-029-22953-01-00 .~ ~ Date: '3 c) ~J~ À-JJ~ ''{ , ) STATE OF ALASKA ) ALASKA 01 L AND GAS CONSERVATION COMMISSIO~ E C E ~ \/E D REPORT OF SUNDRY WELL OPERATlq~ 2 2004 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator 1 SuspendD Repair WellD Pull Tubing D Operation Shutdown D Plug PeriorationsD Periorate New Pool D 4. Current Well Class: Perforate oo..ska Oil ¡¥,)'~~'1{~ns. Commí~'a'ñD Stimulate rr Time Exte~~~,¡Qage Re-enter Suspended WellD 5. Permit to Drill Number: 202-0760 Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development Œ] Stratigraphic D 9. Well Name and Number: P1-18A 10. Field/Pool(s): Pt Mcintyre Oil Field I pt Mcintyre Oil Pool ExploratoryD Service D 6. API Number 50-029-22953-01-00 37.30 8. Property Designation: ADL-028297 11. Present Well Condition Summary: Total Depth measured 10641 feet true vertical 9236.5 feet Plugs (measured) Junk (measured) None Effective Depth measured 10539 feet true vertical 9151.8 feet None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 110 30.0 110.0 1490 470 Production 10595 7" 26# L-80 27 - 10622 27.0 - 9220.7 7240 5410 Surface 4462 9-5/8" 40# N-80 29 - 4491 29.0 - 4477.3 5750 3090 Perioration depth: Measured depth: 10070 -10090,10090 -10110,10205 -10220,10241 -10271,10292 -10332,10332 -10398,10428 -10438 True vertical depth: 8756.52 - 8773.7,8773.7 - 8790.86,8871.9 - 8884.63,8902.41 - 8927.74,8945.44 - 8979.12, 8979.12 - 9034.49 9034.49 - 9051.19,9059.52 - 9067.85 Tubing (size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 25 9798 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 4.5 953 1950 @ 9741 13 Prior to well operation: Subsequent to operation: Oil-Bbl 1103 762 4.4 712 2200 Tubing Pressure 799 762 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ] Service D Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown 0 OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: N/A Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ß~C~ Title Production Technical Assistant Signature Phone 564-4657 Date 6/21/04 nPIG\NAL _8Ft JjI¡a¡s8 Form 10-404 Revised 12/2003 ') ) P1-18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/28/04 ***WELL FLOWING ON ARRIVAL***. DRIFT WI 3.84 GUAGE RING TO 22011 SLM. PULL 4.5" WRDP-2 SSSV (S#HPS-376) @ 22011 SLM. LOC TTL @ 97511 + 471 = 9798 CORR. ELM DEPTH. TAG BTM @ 104231 CORR. DEPTH (TARGET DEPTH 10,0901). (PERFS FROM 100911 TO 104381) (15' OF FILL). NO SAMPLE RECOVERED. ***GIVE WELL BACK TO DSO TO POp*** 05/04/04 Perforate 10070'-10090' 4 SPF 05/12/04 ***WELL FLOWING ON ARRIVAL***. BRUSH SSSVN W/4.5 BLB. SET 4.5 WRDP-2 SSSV(SER.# HBS-773) IN SSSVN @ 22071SLM. PERFORMED CLOSURE TEST(GOOD TEST). ***WELL FLOWING ON DEPARTURE*** FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 ') TREE = CA MERON 4-1/16" 5K WELLHEA D = Frv'C GEN 5 ACT"liÄTOR-;;M....."""""'..'"-^^'^''' "Kš~MEi'ËV..;"""W"_MN""'''?fr3' 'BF'~"ä'EV';;'-^ '" '_.""""""""""""S-:ãì' KOP;'---"'" " ",., 4491' .. . . . Wax A~~le= 48 @ 7540' Datum MD = 10164' Datum TVD = 8800' SS P1-18A I) Minimum ID = 3.725" @ 9786' 4-1/2" H ES XN NIPPLE ITOPOFWHIPSTOO< 1-1 4491' 19-5/8" CSG, 40#, L-80, ID = 8.835" H 4610' ) SAFETY NOTES: 4-12" CHROME TUBING & 7" CHROME CASING. 2227' 1-14-1/2" CAMCO BAL-O SVLN, ID = 3.813" 1 L ST MJ 6 4187 5 5300 4 6797 3 8210 2 9246 GAS LIFT MANDRELS TYPE VL V LA TCH PORT KBG-2 OOME BK 16 KBG-2 DMY BK 0 KBG-2 OOrvE BK 16 KBG-2 SO BK 24 KBG-2 DMY BK 0 KBG-2 DMY BK 0 06/13/03 TVD DEV 4177 7 5195 41 6248 44 7267 42 8045 33 30 DATE 06/13/03 06/09/02 06/13/03 06/13/03 MILLOUT WINDOW 4491' - 4507' 17" CSG, 26#, L-80 BTC, ID = 6.276" 1-1 9631' r-- 17" CSG, 26#, 13-CR-80, ID = 6.276" 1-1 9672' r--- 14-1/2" TBG, 12.6#, 13-CR-80, ID = 3.958" 1-1 979T PERFORATION SUI'vfv1ARY REF LOG: ANGLEA TTOP PERF: 31° @ 10091' f\bte: Refer to Production DB for historical perf data SIZE SA= INTERVAL Opn/Sqz DA TE 3-3/8" 4 10091-10111 0 05/11/03 3-3/8" 6 10205 - 10220 0 OS/20/02 2-7/8" 4 10241 - 10271 0 05/15/03 3-3/8" 6 10292 - 10418 0 OS/20/02 3-3/8" 6 10428 - 10438 0 OS/20/02 17" CSG, 26#, L-80 BTC, ID = 6.276" H 10622' DATE REV BY COrvtv1ENTS ORIGINAL COM PLETION 05/05/02 [NIJM/KK RIGSIŒTRACK(P1-18A) OS/20/02 CWS/KK IPERFS & DEP1H CORRECT. 06/09/02 RUtlh GLV UFDATE 07/28/02 JBiKAK GLV C/O 05/11/03 BJrvvTLH ADÆRF I ¡g- I--i 9720' 1--14-1/2" HES X NIP, ID = 3.813" 1 Z i 9741' 1~4-1/2" X 7" BKR 8-3 A<R, ID = 3.875" 1 ~h ~ I ~ 9765' 1-14-1/2" HES X NIP, ID = 3.813" 1 9786' 1--14-1/2" HES XN NIP, ID = 3.725" 1 9798' 1--14-1/2" WLffi, ID = 3.958" 1 ~ 1 PBTD H 10538' I DA TE REV BY COrvtv1ß>.JTS 05/15iU3 BJM/lLH A [PERF 06/13iU3 JM'KAK GLV 00 01/23/04 AJP/KK REDRAW PRUŒJOE SA Y UNIT WB...L: P1-18A PERMT f\b: 2020760 API f\b: 50-029-22953-01 SEC 16, T12N, R14E. 1393.91' FSL & 879.94' FB... BP Exploration (Alaska) SChlumberger NO. 3017 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 ATTN: Beth Company: 10/31/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Prints H-19B J t.¡ '?I ~ MEM PPROF & IPROF LOG 09/29/03 1 H-27A é)c}~ '<J. MEM PPROF & IPROF LOG 10/01/07 1 D.S. 1-10 ~.r::s--~ PSP LDL 10/25/03 1 D.S. 15-23 ~ I - I ~ <:::, RST GRAVEL PACK LOG 07/10/03 1 JX-02A f \ '7~ LDL 07/18/03 1 D.S. 14-23 ~ ,ocr; PSP LDL 10/24/03 1 P1-17 { ~ ~(')~ ~ PROD PROFILE WIDEFT/GHOST 10/26/03 1 D.S. 4-42 c¡ 'I ~ ~ LDL 10/22/03 1 GNI-02 \~.J - ~ TEMP PROFILElSBHP SURVEY 10/08/03 1 D.S.6-16 ~n~-:2; LDL 10/12/07 1 P1-18A ¡; -n (0 PROD PROFILE W/DEFT 10/15/07 1 D.S. 5-28A ! '-l~' LDL 10/14/03 1 D.S. 12-20 \ -\ LDL 10/21/03 1 2-321SN-03 (q9o~ LDL 10/25/07 1 Z-39 ~- 10563105 RST-SIGMA 09/22/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. . Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 CD -' 1 Jm~~ ~~- -~(;:::(~FIVt:O Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Date Delivered: ~''''l! 0 -- -~ --- , '. Î .. e-, I : ; ~;". ". t~;.....; "-¡ oJ!.. \j ~_: -u." Received b~ ~ IV\~" C C"f ~ Cf\ /V'"\ ;':'.~-¡~-~~:~~8 -<.¡~: (~ ,-. .- .. ¡~~Cfg3s :~~JfnITHS510n f\.nchoff1ge ~~V\'-~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# D.S.15-21A j~,-l{ 'O¡-- 23318 D-03A ¡g-, '-~ 23404 W-34A ~ -(c'")~ 23347 F-10B I~-C) 23401 F-45A '-() { 23308 F-26B - ( () 23399 D.S. 7-30A ~..);~(";., 23420 W-16A In.3 -Irx:-) 23426 P1-18A lJ3. ~T (p 23276 09/16/03 NO. 2959 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 05/15/03 1 1 Jš11 ~ f 06/26/03 1 1 OS/22/03 1 1 .If&J t/~ ~ 06/12/03 1 1 05/03/03 1 1 06/23/03 1 1 p~ 08/08/03 1 1 J' .,- 07/19/03 1 1 }¡J¡~U) 04/04/03 1 1 MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL RST c- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. PetrotectnicaJ Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ?!"'= ?- ~ F' i\- llt:- D ?-~~=!.~ G-I ~ "\.~.x= "~<;Ø -,,-- ~ .. - C¡:o r"i '\ ?-'"If'."'Z, 0L_; Z ~.) ~\)VV Received b~~ Q Iý\~ \. 0 ~ ~C'/V\ ;,~";,;k"~ ;'Y-' ;J, :"::;;¡~ f;OB3. c.'ommî~oo ¡-",...sZh..JUv. V;5 " "'W'.,.ô~ ~ ;t~ncl1oi~ge ') ') ~JDt .~v dvC) J. -/ b Þ .~~ ~ .I WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 09, 2003 RE:MWD Formation Evaluation Logs: PI-18A, AK-MW-22063 Pl-18A: Digital Log Images 50-029-22953-01 1 CD Rom , )'15 } PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: bftD.03 Signed~ ~r RECE\VED MAY 13 2.003 A\a~a OH & Gas Cons. Comm_n Anchorage ) ') J aOd-D1 (p f /50to WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska January 27, 2003 RE: MWD Fonnation Evaluation Logs PI-18A, AK-MW-22063 1 LDWG fonnatted Disc with verification listing. i\PI#: 50-029-22953-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~~ RECEIVED JAN 3 1 2003 Alaska Oii & Gas Cons. Commiseion Andmge Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Job # P1-02A ~l)d....oø6 P1-18A ð.~-{)Î{'" 22273 SCMT (PDC) 22275 USIT (PDC) BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: log Description RECEIVED JUL 1 2 2002 Alaska Oil & Gas Cons. ComrnIsfon Anchorage Date 05/08/02 05/16/02 Blueline 07 III /02 NO. 2218 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD ~/ 2 2 ¡Oq~1 ..~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATIN: Sherrie Received bd~ - úJ) 00 r--J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 'i,.'ê(~~jiPij:,-í,:ië¡\:"'I.," rlœJ:&I', ,: 1394' NSL, 880' WEL, Sec. 16, T12N, R14E, UM ~ J Ð~',f:'~:' l, ~.~ . .," At top of produ?tive interval 1~ sJJ.Z~L ¡; ,i ';' 4509 NSL, 190 WEL, SEC. 16, T12N, R14E, UM ~. ~~::P'T:I' I.' ,~~Ñ 10. Well Number . At t~tal depth 'I" j; L ): ,llJ?J5.lf' bJ ¡' ~ 1.11. " ",þ. '"_. ~ >rr\ 4572 NSL, 5088'~, SEC. 15, T12N, R14E, UM f~~~:,:;::,;:J !'''"~\''.,.".n~~~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Point Mcintyre KBE = 37.3' ADL 028297 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4/25/2002 4/30/2002 5/17/2002 17. Total Depth (MO+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10641 9236 FT 10539 9152 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, NEU, DEN, USIT, CCl 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 2011 91.5# H-40 Surface 110' 3011 260 sx Arctic Set (Approx.) 9-5/811 40#' L-80 29' 4491' 12-1/411 638 sx Arcticset, 316 sx Class 'G' 711 26# L-80/13Cr80 27' 10623' 8-3/411 190 sx Econolite, 205 sx Class 'G' Classification of Service Well 7. Permit Number 202-076 8. API Number 50- 029-22953-01 9. Unit or Lease Name Point Mcintyre P1-18A 15. Water depth, if offshore, 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2227' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/811 ~un Diameter, 6 spf MD TVD 10205' - 10220' 8872' - 8885' 10292' - 10332' 8945' - 8979' 10332' - 10398' 8979' - 9034' 10398' - 10418' 9034' - 9051' 10428' - 10438' 9059' - 9068' 25. SIZE 4-1/2'" 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 9798' PACKER SET (MD) 9741' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 70 Bbls Crude 27. Date First Production May 25, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. ~fii~~ 't~f F D No core samples were taken. 28. .JU¡\J 2 8 2002 Form 10-407 Rev. 07-01-80 Alaska OB & GéiS Güfi~. uI.JI:I,,,,,,"'íO~ Anchorage n r~, ~ ;~ ~~ ~.! /,~ 1 R B D M 5 B F l JUL 2 ~mit In DUPlicatt ç ) 29. Geologic Markers Marker Name Measured Depth Ugnu 50091 West Sak 73761 Coleville 75821 HRZ 96811 Kalubik 98861 Kuparuk 99141 Miluveach 105841 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4960' 66561 6795' 84181 8597' 8621' 9189' ~!F(qFI\rr 'J" i r. 0 lìOfì2 "..1 u t,~ t. 0 t.. i~} , AJasl<a Oi! & aà;:> I..,OH::" v0!/II.i¡,iSIOP Anchorage Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Te"ie Hubbie --1.flVtiR, ~ Title Technical Assistant P1-18A 202-076 Well Number Permit No. / Approval No. Date (j(ð" A 7.0::t Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 t---: -;-''''''\ 1 :' 1 Legal Name: P1-18 Common Name: P1-18A Test Date 4/25/2002 Test Type FIT Test Depth (TMD) 4,491.0 (ft) BP EXPLORATION Leak-OffTestSuml11ary Test Depth(TVD) 4,477.0 (ft) AMW 9.40 (ppg) Surface Pressure Leak Off Pressure (BHP) 2,908 (psi) EMW 12.50 (ppg) 722 (psi) '----- ---" Printed: 5/6/2002 11 :46:44 AM ) ) BPEXPI..ORATION Opf!.ratiorl$....~l.Imrrla.ty......Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-18 P 1-18A REENTER+COMPLETE NABORS NABORS 2ES Fronl...To Hours Task Code NPT Phase 4/21/2002 18:00 - 00:00 6.00 MOB P PRE 4/22/2002 00:00 - 01 :00 01 :00 - 01 :30 1.00 MOB P 0.50 RIGU P PRE PRE 01 :30 - 03:00 1.50 RIGU P PRE 03:00 - 05:00 2.00 RIGU P PRE 05:00 - 08:00 3.00 RIGU P PRE 08:00 - 13:30 5.50 RIGU P PRE 13:30 - 14:00 0.50 RIGU P PRE 14:00 - 15:00 1.00 WHSUR P DECOMP 15:00 - 16:00 1.00 PULL P DECOMP 16:00 - 17:30 1.50 PULL P DECOMP 17:30 - 18:00 0.50 PULL P DECOMP 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 22:00 3.50 PULL P DECOMP 22:00 - 23:00 1.00 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 4/23/2002 00:00 - 01 :30 1.50 CLEAN P DECOMP 01 :30 - 04:00 04:00 - 07:30 2.50 CLEAN P 3.50 CLEAN P DECOMP DECOMP 07:30 - 10:00 2.50 CLEAN P DECOMP 10:00 - 10:30 0.50 CLEAN P DECOMP 10:30 - 12:30 2.00 CLEAN P DECOMP 12:30 - 14:00 1.50 CLEAN P DECOMP Start: 4/8/2002 Rig Release: 5/5/2002 Rig Number: Spud Date: 4/25/2002 End: 5/5/2002 Description of Operations MOVE RIG. SHUT-IN ADJACENT WELLS, SPOT RIG OVER P1-18A WELL. RE-OPEN PRODUCING WELLS. INSTALL SECONDARY ANNULAR VALVE. CHECK FOR PRESSURE. BERM AROUND CUTTINGS TANK AND CELLAR. INSPECT RIG. HELD PRE-SPUD MTG. ACCEPT RIG AT 0100 HRS, 4/22/2002. BLED ANNULAR PRESSURE TO ZERO, AND TESTED TWC FROM BELOW TO 1,000 PSI- OKAY. ND TREE AND ADAPTOR. NU DOUBLE STUDDED ADAPTOR, BOPE AND FLOW LINE. PRESSURE TEST PIPE AND BLIND RAMS, CHOKE MANIFOLD, KILL LINE, HCR VALVES, FLOOR VALVES, TD TO 25014,000 PSI FOR 5/5 MIN. TEST ANNULAR T0250/3,500 PSI FOR 5/5. TEST WITNESSED BY CHUCK SCHEVE OF AOGCC. CHANGE OUT SAVER SUB OF TD TO 4-1/2" IF. RU LUBRICATOR, PULL TWC. SCREW INTO AND PULL TBG HNGR TO FLOOR. PJSM. DISPLACE 160 BBL OF DIESEL FROM WELL. MONITOR WELL - STATIC. BLOW DOWN SURF EQUIP. RD CIRC LINES, RD HANGER AND CLEAR RIG FLOOR. RU TUBING HANDLING EQUIP. POOH AND LD 70 JTS FOR 3-1/2" 9.3 LBIFT, L-80 TBG FROM 2,192'. RD TBG HANDLING EQUIPMENT. CLEAR RIG FLOOR. SET TEST PLUG AND TEST BOTTOM RAMS. BLOW DOWN SURFACE EQUIP. RU CONTROL LINES FOR P1-17 WELL, REMOTE SHUT-IN STATION. RD TEST PLUG, INSTALL WB. CONNECT CONTROL LINES FROM REMOTE SHUT-IN STATION ON RIG FLOOR, TO P1-17 TREE, WITH BP PAD OPERATOR. CHARGE AND TEST LINE TO 5,000 PSI-OKAY. PU BIT AND MILLS, FOR CLEANOUT I GAUGE RUN. PU 5" DP, RIH TO 4,489' AND TAG STRINGERS. INSTALLED BLOWER HOSE TO TD, TO WASH TO BOTTOM. (WHILE INSTALLING THE BLOWER HOSE, A .5"X3" BOLT FROM THE BLOWER HOSE CLAMP, FELL DOWN THE WELLBORE). WASHED FROM 4,489' TO 4,492'. OBSERVED WELL WAS FLOWING, SHUT DOWN PUMPS AND SHUT WELL IN. ZERO PRESSURE ON ANNULUS AND 175 PSI ON DP. PUMPED GAS CUT MUD OUT OF HOLE AT 40 SPM AND 100 PSI BACKPRESSURE. MONITOR WELL - STATIC. CIRCULATE ONE HOLE VOLUME, MONITOR OKAY. CONTINUE WASHING TO 4,512'. SET DOWN 25K ON CEMENT PLUG-OKAY. CIRCULATE AT 5.3 BPM AND 20 RPM WHILE RECIPROCATING. CONDITION AERATED MUD. DISPLACE HOLE TO 9.4 PPG, MILLING FLUID AT 12 BPM AND 800 PSI. MONITOR WELL - STATIC. BLOW DOWN Printed: 5/6/2002 11 :47:22 AM ) ) IBP EXPLORATION Qpéréitiøns.....SU.rnrl1ary ....Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-18 P 1-18A REENTER+COMPLETE NABORS NABORS 2ES Start: 4/8/2002 Rig Release: 5/5/2002 Rig Number: Spud Date: 4/25/2002 End: 5/5/2002 Date From-To l-foÜrsTask Code NPT Phase Description of Operé3tions 4/23/2002 12:30 - 14:00 1.50 CLEAN P DECOMP SURFACE EQUIPMENT. 14:00 - 16:30 2.50 CLEAN P DECOMP POOH TO BHA. 16:30-18:30 2.00 CLEAN P DECOMP LD BHA. 18:30 - 19:00 0.50 CLEAN P DECOMP PRESSURE TEST 9-5/8', 40#/FT CASING, FOR 30 MINUTES - OKAY. 19:00 - 21 :00 2.00 CLEAN P DECOMP PUlMU WHIPSTOCK BHA. UPLOAD DATA TO MWD. 21 :00 - 00:00 3.00 CLEAN N DECOMP TROUBLE SHOOT RIG LOSS OF POWER. 4/24/2002 00:00 - 05:00 5.00 CLEAN N DECOMP TROUBLE SHOOT SCR BAYS AND REPLACE #1 MOTOR SHUT DOWN SWITCH AND POWER LIMIT CONTROLLER. 05:00 - 06:00 1.00 STWHIP N WEXIT UPLOAD MWD AND TEST. REPLACE FAULTY CABLES DUE TO POOR SIGNAL DURING UPLOAD. 06:00 - 07:30 1.50 STWHIP P WEXIT UPLOAD MWD, TEST- OKAY 07:30 - 08:30 1.00 STWHIP N WEXIT THAW MUDLlNE AND MUD MANIFOLD. 08:30 - 11 :30 3.00 STWHIP P WEXIT PU WHIPSTOCK AND MWD. ORIENT. 11 :30 - 14:30 3.00 STWHIP P WEXIT RIH TO 4,461'. 14:30 - 15:30 1.00 STWHIP P WEXIT ORIENT WHIPSTOCK 36 DEG RHS. UWT =155K, DWT = 145K. CONTINUE RIH AND TAG CEMENT AT 4,512'. SET DOWN 30 K, SHEAR AND SET WHIPSTOCK. 15:30 - 00:00 8.50 STWHIP P WEXIT MILL WINDOW FROM 4,491' TO 4,507'. UWT=155K, DWT=145K, ROT=150K, TORQUE=5-9 FT-LB. WORK THROUGH WINDOW AND POLISH SAME - TORQUE = 5.1-5.3 FT-LB. 4/25/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT PUMP SWEEP AND CONTINUE TO WORK MILLS THROUGH THE WINDOW. UWT = 155K, DWT = 140K. 01 :00 - 01 :30 0.50 STWHIP P WEXIT PERFORM FIT TEST AT 4,477' TVD, WI 9.4 PPG MUD AND 722 PSI SURFACE PRESSURE, FOR AN EMW = 12.5 PPG. 01 :30 - 02:00 0.50 STWHIP P WEXIT PUMP SLUG AND BLOW DOWN SURFACE EQUIP. 02:00 - 04:00 2.00 STWHIP P WEXIT POOH TO BHA. 04:00 - 06:00 2.00 STWHIP P WEXIT LD WINDOW MILLING BHA. MILLS IN GAUGE 06:00 - 07:30 1.50 STWHIP P WEXIT PULL WB, FLUSH AND CLEAN STACK AND SURFACE EQUIPMENT. 07:30 - 10:00 2.50 DRILL P PROD1 PU BUILD SECTION BHA AND ORIENT MWD. 10:00-11:00 1.00 DRILL P PROD1 UPLOAD MWD DATA. 11 :00 - 12:30 1.50 DRILL P PROD1 RIH WI BHA, SHALLOW TEST MWD-OKA Y. 12:30 -15:30 3.00 DRILL P PROD1 CONTINUE RIH PICKING UP 5" DP 1X1. FILL DP AT 2,808' AND 4,404' AND FUNCTION TEST MWD - OKAY. 15:30 -16:30 1.00 DRILL P PROD1 CUT AND SLIP 100' OF DL. 16:30 - 17:30 1.00 DRILL P PROD1 INSPECT AND SERVICE TD. 17:30 - 18:00 0.50 DRILL P PROD1 ORIENT TOOLFACE TO 36 DEG RHS. SLIDE THROUGH THE WINDOW WIO PUMPS TO 4,510'. 18:00 - 00:00 6.00 DRILL P PROD1 REAM UNDERGUAGE HOLE TO 4,523'. DRILL TO 4925' 8-3/4" HOLE WITH 1.22 DEG BENT MOTOR. ART = 1.2 HRS, AST = 2.3 HRS. 4/26/2002 00:00 - 08:00 8.00 DRILL P PROD1 CONTINUE DRILLING TO 5,623' WI 1.22 DEG MOTOR. 08:00 - 09:00 1.00 DRILL P PROD1 SWEEP HOLE CLEAN WI 550 GPM, AT 1,600 PSI. 09:00 - 10:00 1.00 DRILL P PROD1 SHORT TRIP TO WINDOW. OVER PULL OF 20K AT 5,383', 5,162',4,975',4,794', 4,610',-MONITOR WELL -STATIC. 10:00 - 10:30 0.50 DRILL P PROD1 RIH TO 5,623' WITHOUT PROBLEMS. 10:30 - 00:00 13.50 DRILL P PROD1 DRILL AHEAD TO 6,939'. DAILY AST = 2.41, ART = 12.46. 4/27/2002 00:00 - 08:30 8.50 DRILL P PROD1 DRILL 8-3/4" HOLE WI 1.22 DEG MOTOR TO 7,261'. TORQUE WAS ERRATIC AT 9-15,000 FT-LB. ROP DECREASED FROM 50-10 FT/HR OVER THE LAST 100' Printed: 5/6/2002 11 :47:22 AM ') ') BPEXPLORATION ()perafior1$.....§LlrJ1FllCl.r1j.. .Repg rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-18 P 1-18A REENTER+COMPLETE NABORS NABORS 2ES Start: 4/8/2002 Rig Release: 5/5/2002 Rig Number: Spud Date: 4/25/2002 End: 5/5/2002 Date From-To Hours Task Code NPT Description of Operations 4/27/2002 00:00 - 08:30 08:30 - 09:30 09:30 - 12:30 8.50 DRILL P 1.00 DRILL P 3.00 DRILL P PROD1 PROD1 PROD1 12:30 - 14:00 1.50 DRILL P PROD1 14:00 - 14:30 14:30-18:30 0.50 DRILL P 4.00 DRILL P PROD1 PROD1 18:30 - 19:00 0.50 DRILL P PROD1 19:00 - 20:30 1.50 DRILL P PROD1 20:30 - 21 :00 0.50 DRILL P PROD1 21 :00 - 00:00 3.00 DRILL P PROD1 4/28/2002 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 01 :30 0.50 DRILL P PROD1 01 :30 - 02:00 0.50 DRILL P PROD1 02:00 - 03:30 1.50 DRILL P PROD1 03:30 - 04:00 0.50 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 00:00 18.00 DRILL P PROD1 4/29/2002 00:00 - 07:00 7.00 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 11 :00 3.00 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL P PROD1 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 16:00 2.50 DRILL P PROD1 16:00 - 17:30 1.50 DRILL P PROD1 17:30 - 00:00 6.50 DRILL P PROD1 DRILLED. AST= .23, ART = 4.17 HR. SWEEP HOLE CLEAN, PUMP SLUG. POOH TO BHA. MINIMAL OVERPULL IN OPEN HOLE, NO O/P IN OPEN HOLE THAT HAD BEEN SHORT TRIPPED THROUGH. NO PROBLEMS PASSING THROUGH THE WINDOW. TEST CHOKE MANIFOLD TO 250/4,000 PSI WHILE TRIPPING. BREAK BIT AND DOWNLOAD MWD. BIT 3/4" UNDERGAGED. PULL WB. PRESSURE TEST PIPE AND BLIND RAMS, CHOKELlNE & KILL LINE VALVES, HCR VALVES, FLOOR VALVES, TD TO 250/4,000 PSI FOR 5/5 MIN. TEST ANNULAR T0250/3,500 PSI FOR 5/5. TEST WITNESSING WAIVED BY JOHN SPAULDING OF THE AOGCC. PULL TEST PLUG. INSTALL WB. MU HOLD SECTION BHA WI PDC BIT. UPLOAD MWD. SURFACE TEST - OKAY. LOAD RA SOURCES. RIH TO 2,550' PICKING UP 5" DP (ENOUGH TO TO WELL). CONTINUE RIH TO 2,550' PICKING UP 5" DP 1X1. RIH TO 4,431'. SERVICE TD. FILL PIPE. ORIENT TOOLFACE TO 36 DEG RHS. BLOW DOWN SURFACE EQUIP. UWT = 145K, DWT = 135K. PASS THROUGH WINDOW OKAY. RIH TO 6,090' WIO ANY DRAG. CHECK SHOT SURVEY AT 6,090'. CONTINUE RIH TO 6,670' WITH A SLOW INCREASE IN DRAG (5-10K). SET DOWN 20K AT 6,670. RU TOP DRIVE TO WASH AND REAM. WASH AND REAM UNDERGAUGE HOLE TO 7,261', AT 65 RPM, 3-8K WOB, 9,200-11,200 FT-LB OF TORQUE, 550 GPM. UWT=210K, DWT=160K. DRILL 8-3/4" HOLE WI 1.22 DEG MOTOR TO 8,843'. TQ=14-16 FT-LB. PUMP SWEEPS EVERY 200', ADD LUBRICANT AS NEEDED. UWT=220K, DWT=145K, ROT=185K. DAILY AST= 4.78, ART = 7.28 HR. DRILL 8-3/4" HOLE WI 1.22 DEG MOTOR TO 9,313'. PUMP SWEEPS APPROX. EVERY 200', ADD LUBRICANT AS NEEDED. PUMP HI-VIS SWEEP AT 570 GPM AND 2,780 PSI. MONITOR WELL - STATIC. POOH TO INSIDE 9-5/8" CSG AT 4,431'. PULLED 20-30K O/P AT 8,378',7,612'-7,640',7,360',5,302'. PUMP SLUG, MONITOR WELL - STATIC. CUT AND SLIP DL. SERVICE TD, FLUSH AND CLEAN MUD PITS FOR DISPLACEMENT. RIH SMOOTHLY TO 9,313'. DISPLACE WELL TO 10.2 PPG, 4% KCL 15% GEM DRILLING FLUID ROTATE AND SLIDE DRILL TO 9,613'. UWT=230K, Printed: 5/6/2002 11 :47:22 AM ) ) BPEXPLORATION OperationsSllnlrnäryR~port Page4of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-18 P 1-18A REENTER+COMPLETE NABORS NABORS 2ES Start: 4/8/2002 Rig Release: 5/5/2002 Rig Number: Spud Date: 4/25/2002 End: 5/5/2002 Date From ...~..T 0 Hours Task Code NPT Phase pescri ptionof Opèrations 4/29/2002 17:30 - 00:00 6.50 DRILL P PROD1 DWT=175K, ROT=200K. DAILY AST=4.56, ART = 5.09 HR. 4/30/2002 00:00 - 00:00 24.00 DRILL P PROD1 DRILL 8 3/4" DIRECTIONAL HOLE. ROTATE AND SLIDE FROM 9613' TO 10554'. AST=6.3 HRS ART = 11.1 HRS. 5/1/2002 00:00 - 03:00 3.00 DRILL P PROD1 DRILL 83/4" DIRECTIONAL HOLE FROM 10554' to 10641'. FINAL TD. ART = 2.1 HRS. 03:00 - 04:30 1.50 DRILL P PROD1 CIRCULATE AND CONDITION MUD. PUMP AROUND HIGH VIS SWEEP. MONITOR WELL, STATIC. 04:30 - 07:30 3.00 DRILL P PROD1 POH TO 9 5/8" WINDOW. NO PROBLEMS. 07:30 - 08:30 1.00 DRILL P PROD1 SLIP AND CUT DRILLING LINE. 08:30 - 15:00 6.50 DRILL N WAIT PROD1 PHASE 3 WEATHER CONDITION. ALL OPERATIONS STOPPED. 15:00 - 17:00 2.00 DRILL N WAIT PROD1 WEATHER CONDITION REDUCED TO PHASE 1 ON PRIMARY ROADS. CALLED OUT WATER, FUEL AND VAC TRUCKS TO SERVICE RIG. HELD PJSM WITH ALL RIG PERSONEL. 17:00 - 18:00 1.00 DRILL P PROD1 SERVICE TOP DRIVE. 18:00 - 19:00 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 9 5/8" WINDOW. 19:00 - 21 :30 2.50 DRILL P PROD1 RIH TO 10628'. FILL PIPE AT 6764' WHEN RIH. 21 :30 - 00:00 2.50 DRILL P PROD1 CIRCULATE AND CONDITION MUD. WORK PIPE. RECIPROCATE AND ROTATE. 5/2/2002 00:00 - 01 :00 1.00 DRILL P PROD1 CIRCULATE AND CONDITION MUD. WORK PIPE. RECIPROCATE AND ROTATE. MONITOR WELL, STATIC. 01 :00 - 02:00 1.00 DRILL P PROD1 MAKE MAD PASS LOG FROM 10610' TO 10545'. 100 FPH AT 55 RPM. 02:00 - 02:30 0.50 DRILL P PROD1 POH TO 1 0159' LAY DOWN 5" DRILL PIPE. 02:30 - 03:00 0.50 DRILL P PROD1 MONITOR WELL, STATIC. PUMP DRY JOB. BLOW DOWN TOP DRIVE. 03:00 - 09:30 6.50 DRILL P PROD1 POH TO BHA. LAY DOWN 5" DRILL PIPE. NO PROBLEMS. 09:30 - 10:30 1.00 DRILL P PROD1 POH. LAY DOWN BHA. 10:30 - 11 :30 1.00 DRILL P PROD1 PJSM. REMOVE RADIO ACTIVE SOURCE. DOWN LOAD MWD. 11 :30 - 14:00 2.50 DRILL P PROD1 POH. LAY DOWN BHA. 14:00 - 14:30 0.50 CASE P COMP PULL WEAR BUSHING. INSTALL TEST PLUG. 14:30 - 16:00 1.50 CASE P COMP CHANGE OUT TOP RAMS TO 7" AND TEST BONNET SEALS TO 250 PSI AND 3500 PSI. PULL TEST PLUG. 16:00 - 18:00 2.00 CASE P COMP CONFIRM LANDING JOINT SPACE OUT. PJSM WITH CREWS. RIG UP TO RUN 7" CASING. 18:00 - 00:00 6.00 CASE P COMP PICK UP 7" SHOE AND COLLAR. CHECK FLOATS. RUN 23 JTS 7" 26# 13CR80 VAM TOP CASING, CROSS OVER TO 7" 26# L-80 BTC-MOD CASING. 5/3/2002 00:00 - 00:30 0.50 CASE P COMP RUN 7" 26# 13CR80 VAM TOP CASING, CROSS OVER TO 7" 26# L-80 BTC-MOD CASING AND RUN IN TO 4454' 00:30 - 01 :00 0.50 CASE P COMP CIRCULATE CASING VOLUME AT 9 5/8" CASING WINDOW. 01 :00 - 07:30 6.50 CASE P COMP RUN 7" CASING TO 9000'. TIGHT SPOT. WASH THROUGH TIGHT SPOT. RIH TO 10622, LANDING CSG HGR 07:30 - 09:30 2.00 CASE P COMP CIRC AT 10622', 8 BPM, 1395 PSI, AFTER PUMPING 1100 BBLS PRESSURE INCREASED SEVERAL TIMES TO 3600 PSI. STOP PUMPING. 09:30 - 11 :30 2.00 CASE N SFAL COMP TROUBLE SHOOT PUMP PRESSURE SURGES. DISCOVERED THAT HALLIBURTON HAND HELD RADIO Printed: 5/6/2002 11 :47:22 AM ) ) BREXPL..ORATICDN Operati()ns<ßu rrll11aryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-18 P 1-18A REENTER+COMPLETE NABORS NABORS 2ES Start: 4/8/2002 Rig Release: 5/5/2002 Rig Number: Spud Date: 4/25/2002 End: 5/5/2002 Date From>- To Hours Task Code NPT Phase Description. of Ope rations 5/3/2002 09:30 - 11 :30 2.00 CASE N SFAL COMP TRANSMISSION CAUSING EPOCH "RIG WATCH" SYSTEM TO MALFUNCTION. ALSO TRIGGERED H2S ALARM AND THE RIG WAS EVACUATED AS A PRECAUTION. 11 :30 - 12:00 0.50 CASE P COMP CIRCULATE. HELD PJSM WITH RIG CREW, CEMENTERS AND TRUCK DRIVERS. 12:00 - 13:30 1.50 CEMT P COMP PUMP 5 BBL FRESH WATER AND TEST LINES. PUMP 50 BBL 11.2 PPG ALPHA SPACER. MIX AND PUMP 110 BBL PREMIUM CEMENT LEAD SLURRY AT 11.2 PPG FOLLOWED WITH 42 BBL PREMIUM CEMENT TAIL SLURRY AT 15.8 PPG. DISPLACE USING RIG PUMPS WITH 25 BBL PERF PILL AND 378 BBL SEA WATER. BUMP PLUG WI 3500 PSI, HELD FOR 5 MIN. LAND CASING ON CASING HANGER. CIP AT 13:30 HOURS 13:30 - 15:00 1.50 CEMT P COMP RIG DOWN CEMENT HEAD AND LINES. CLEAR FLOOR. 15:00 - 16:00 1.00 WHSUR P COMP INSTALL 7" X 10" PACK OFF ON CASING HANGER. RUN IN LOCK DOWN SCREWS. TEST TO 5000 PSI. OK. 16:00 - 17:30 1.50 BOPSURP COMP CHANGE TOP RAMS TO 31/2" X 6" VBR. TEST BONNET SEALS TO 250 PSI AND 3500 PSI. 17:30 - 18:00 0.50 BOPSUR P COMP CHANGE SAVER SUB ON TOP DRIVE. 18:00 - 20:00 2.00 RUNCOIVP COMP RIG UP TO RUN 13CR TUBING. RIG UP COMPENSATOR. PJSM WITH RIG CREW, CASING CREW AND BAKER REP. 20:00 - 00:00 4.00 RUNCOIVP COMP RUN 4 1/2" TAIL PIPE AND COMPLETION ASSEMBLY. PICK UP 41/2" 12.6# 13CR80 VAM ACE TUBING. 5/4/2002 00:00 - 06:00 6.00 RUNCOIVP COMP RIH WITH COMPLETION 41/2" 12.6# 13CR80 VAM ACE TUBING TO 7570' 06:00 - 07:00 1.00 RUNCOIVP COMP RIG UP HALLIBURTON CONTROL LINE SPOOLING UNIT. 07:00 - 10:30 3.50 RUNCOIVP COMP RIH WITH COMPLETION. RUN 1/4" CONTROL LINES. INSTALL 56 SS BANDS ON CONTROL LINES. 10:30 - 11 :00 0.50 RUNCOIVP COMP MAKE UP TUBING HANGER. TEST CONTROL LINES TO 5000 PSI. 11 :00 - 12:30 1.50 RUNCOIVP COMP LAND TUBING ON HANGER. RUN IN LOCK DOWN SCREWS. 12:30 - 13:00 0.50 RUNCOIVP COMP RIG UP LINES TO CIRCULATE. 13:00 - 15:00 2.00 RUNCOIVP COMP REVERSE CIRCULATE CLEAN SEA WATER AND SPOT INHIBITED SEA WATER IN ANNULUS. 15:00 - 17:00 2.00 RUNCOIVP COMP DROP BALL AND ROD. SET PACKER. TEST TO 3500 PSI FOR 30 MINUTES. TEST ANNULUS TO 3500 PSI FOR 30 MINUTES. BLEED PRESSURE OFF AND SHEAR RP VALVE. 17:00 - 17:30 0.50 RUNCOIVP COMP INSTALL TWO WAY CHECK AND TEST TO 1000 PSI FROM BELOW. 17:30 - 18:00 0.50 RUNCOIVP COMP LAY DOWN LANDING JOINT. RIG DOWN CIRCULATING LINES. 18:00 - 19:30 1.50 BOPSUR P COMP NIPPLE DOWN BOP. 19:30 - 22:00 2.50 WHSUR P COMP NIPPLE UP TREE AND TEST TO 5000 PSI. 22:00 - 23:00 1.00 WHSUR P COMP REMOVE TWO WAY CHECK VALVE WITH DRILL SITE MAINTENANCE LUBRICATOR. 23:00 - 23:30 0.50 WHSUR P COMP RIG UP LINES TO CIRCULATE. 23:30 - 00:00 0.50 WHSUR P COMP FREEZE PROTECT TUBING AND ANNULUS WITH 74 BBL DIESEL TO 2200'. 5/5/2002 00:00 - 02:00 2.00 WHSUR P COMP "U" TUBE DIESEL FREEZE PROTECT FROM 7" ANNULUS TO 4 1/2" TUBING 02:00 - 03:00 1.00 WHSUR P COMP INSTALL AND TEST BPV TO 1000 PSI, RID SECONDARY Printed: 5/6/2002 11 :47:22 AM ) ) BP EXPLORATION QpE!rätions.. .Sl.ImrnarYJ....Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P1-18 P 1-18A REENTER+COMPLETE NABORS NABORS 2ES Start: 4/8/2002 Rig Release: 5/5/2002 Rig Number: Spud Date: 4/25/2002 End: 5/5/2002 Date From- To Hours Task Code NPT Phase 5/5/2002 02:00 - 03:00 1.00 WHSUR P CaMP ANNULAR VALVE, SECURE WELL, RELEASE RIG AT 03:00 HOURS ON 5/5/02 Printed: 5/6/2002 11 :47:22 AM ') ) Well: Field: API: Permi t: P1-18A Poi nt Mcintyre 50-029-22953-01 202-076 Rig Accept: Rig Spud: Ri g Rei ease: Drilling RiQ: 04/22/02 04/25/02 05/05/02 Nabors 2ES POST RIG WORK 05/13/02 PULLED DUMMY SSSV, PULLED BALL & ROD AND RHC PLUG, SET CATCHER SUB, PULLED DGLV (BK) FROM GLM #2 AND RP SHEAR (BK) FROM GLM #1 - SET 16/64" PORT - 1500 TRO LGL V (BK) IN GLM #1. 05/14/02 SET 20/64" PORT OGLV (BK) IN GLM #2, PULLED CATCHER SUB. GENERICS SET IN TOP TWO GLM'S. DRIFTED TUBING TO 10539' SLM WITH A 3 3/8" DUMMY GUN. 05/16/02 RUN USIT -GAMMA RAY CCL LOG FOR CEMENT EVALUATION PRIOR TO PERF.- CORRELATED TO SPERRY MWD DUAL GAMM RAY LOG FINISHED 2 MAY 02-- TAGGED TO @ 10520- LOGGED UP PAST 4.5 TUBING TAIL WI USIT- RAN GAMMA RAY CCL TO 150 FT. 05/17/02 INITIAL PERFORATING IN PROGRESS. COMPLETED TWO OF EIGHT GUN RUNS WITH 3-3/8 POWERJETS @ 6 SPF. PERF'D INTERVALS ARE (10428' TO 10438') & (10398' TO 10418'). 05/18/02 INITIAL PERFORATION IN PROGRESS. COMPLETED THREE OF SIX REMAINING GUN RUNS. SHOT A TOTAL INTERVAL OF 66' WITH 33/8" 3406 POWERJETS @ 6 SPF. PERF'D INTERVAL: (10332 TO 10398). LEFT WELL SHUT-IN. 05/19/02 RUN 3318 POWERJETS @ 6 SPF--DAY THREE PERFS TOTAL OF 55 FT-- PERF INTERVALS 10292 TO 10332 & 10205 TO 10220---- TOTAL OF 55 FT - 332 SHOTS. THIS COMPLETES PERFORATING. PAD OPERATOR NOTIFIED OF WELL STATUS. WELL LEFT SHUT IN. OS/21/02 PUMP 1800 F DIESEL DOWN THE LA. TO ATTEMPT TUBING THAW. REACHED MAXIMUM PRESSURE OF 2500 PSI AFTER PUMPING 33 BBLS AND SHUT DOWN THE PUMP TO GIVE THE WELL TIME TO ABSORB THE HEAT. THE IA LOST 100 PSI IN ONE HOUR. BLEED THE IA TO THE SLOP TRAILER; ALL LIQUID RETURNS. PUMP THE IA FROM 2200 PSI BACK UP TO 2700 PSI WITH 7 MORE BBLS OF HOT DIESEL AND MONITOR THE WELL FOR 30 MINUTES. IT LOST 75 PSI. THE DSO PRESSURED THE TUBING TO 1550 PSI FROM THE SKID. RDMO. OS/22/02 RETRIEVE SAMPLE OF ICE IN TUBING @ 930' SLM WI 2.50 PUMP BAILER. WELL LEFT SI. OS/25/02 RIH WI 3" DJN. HIT ICE PLUG @ 962' CTM. BEGIN JETTING WI 50/50 METHANOL & NEET METHANOL SWEEPS. HIT NUMEROUS PLUGS DOWN TO APPROX. 2900' CTM. DRIFTED TO 5400' CTM. ALL CLEAR. POOH. RDMO. RELEASE WELL TO DSO. READY TO BOL. 05/30/02 DRIFT TBG WI 2.75 CENT TO 10,623' WLMD. RUN SBHPS WI PETRODAT, GOOD DATA. 06/09/02 RUN NEW GL DESIGN. REPLACE VALVES @ STATIONS 6,5,4 & 1 WI NEW GL DESIGN. P1-18A, Rotary Sidetrack Page 2 ) ) 06/10/02 PULL 4-1/2" CATCHER SUB FROM 4-1/2" XN NIPPLE @ 9760' SLM. RD. SECURED WELL. 06/11/02 PPROF WI DEFT FIELD ESTIMATED RESULTS: 10205' - 10220' = 8%,10292' -10418': 92%,10428' -10438': 0% (SMALL HC ENTRY FROM THESE PERFS INDICATED BY DEFT). GAS ENTRY THRU UPPERMOST PERFS.TEST RESULTS WHILE LOGGING: 2637 BOPD, 2347 BWPD, 5760 MSCF, CHOKE = 176. NOTIFY PAD OPERATOR OF WELL STATUS: LEFT SHUT IN. 06/15/02 SET AND TESTED A 4.5" WRDP-2 SSSV (# HKS-48) AT 2210' SLM. WELL POP. ) ) aOd-O-¡~ 22-May-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well P1-18A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 4,403.82' MD Window / Kickoff Survey 4,491 .00' MD (if applicable) PrQjected Survey: 10,461.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED f) /. \ ,~ . , : -.;: 1'")" '1002 . " \. L' " t.. AlaaksOil & Gas Cons. Commisst Anchorage on DEF NITIVE North Slope Alaska BPXA - Point Mcintyre Pad 1, Slot NV-18 NV-18 - P1-18A Job No. AKMW22063, Surveyed: 1 May, 2002 -' SURVEY REPORT 22 May, 2002 Your Ref: API 500292295301 Surface Coordinates: 5994520.66 H, 674177.67 E (70° 23' 26.5922" H, 148034' 58.7442" W) Kelly Bushing: 37.30ft above Mean Sea Level ~I' ..~ Ii.. IY-C' JI1 QA.-ILLING sÊFtVIc:es A Halliburton Company Survey Ref: svy11190 Sperry-Sun Drilling Servicë~'e:. . Survey Report for NV..18 - P1-18A Déf\N\1\~é Your Ref: AP/5Ø0292295301 Job No. AKMW22063~ Survéyed: 1 May~ 2002 BPXA North Slope Alaska Point Mcintyre Pad 1 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs E..tlnge Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 4403.82 8.800 356.430 4353.90 4391.20 99.56 S 29.03 E 5994421.80 N 674209.01 E -85.42 Tie On Point 4491.00 9.090 0.900 4440.02 4477.32 86.02 S 28.73 E 5994435.34 N 674208.39 E 0.864 -72.66 Window Point ~ 4503.33 10.370 3.240 4452.17 4489.47 83.94 S 28.80 E 5994437.42 N 674208.42 E 10.863 -70.66 4599.63 16.740 15.120 4545.76 4583.06 61.87 S 32.92 E 5994459.58 N 674212.02 E 7.186 -48.41 4692.31 18.860 20.970 4634.00 4671.30 34.99 S 41.76 E 5994486.65 N 674220.23 E 2.990 -20.12 4758.41 20.470 22.180 4696.25 4733.55 14.31 S 49.95 E 5994507.52 N 674227.94 E 2.512 2.09 4776.31 21 . 120 22.060 4712.98 4750.28 8.42 S 52.34 E 5994513.46 N 674230.19 E 3.639 8.43 4880.26 23.860 11.330 4809.06 4846.36 29.57 N 63.51 E 5994551.71 N 674240.48 E 4.738 48.01 4975.50 28.920 8.180 4894.35 4931.65 71.28 N 70.58 E 5994593.57 N 674246.57 E 5.511 89.83 5069.36 32.760 6.790 4974.92 5012.22 118.98 N 76.81 E 5994641.40 N 674251.69 E 4.161 137.08 5162.69 36.750 5.520 5051.59 5088.89 171.87 N 82.49 E 5994694.41 N 674256.13 E 4.345 189.07 5257.58 39.910 5.490 5126.01 5163.31 230.44 N 88.13 E 5994753.09 N 674260.41 E 3.330 246.46 5350.75 43.320 4.440 5195.66 5232.96 292.08 N 93.47 E 5994814.83 N 674264.31 E 3.736 306.65 5443.13 45.820 3.230 5261.4 7 5298.77 356.76 N 97.79 E 5994879.60 N 674267.12 E 2.858 369.42 5539.05 45.970 2.590 5328.23 5365.53 425.54 N 101.28 E 5994948.45 N 674269.01 E 0.504 435.83 5631.55 46.000 2.890 5392.50 5429.80 491.99 N 104.46 E 5995014.95 N 674270.64 E 0.235 499.92 5725.24 45.930 2.030 5457.62 5494.92 559.28 N 107.35 E 5995082.29 N 674271.97 E 0.664 564.72 5818.86 46.090 2.360 5522.65 5559.95 626.59 N 109.93 E 5995149.64 N 674272.98 E 0.306 629.43 5914.39 45.590 2.800 5589.20 5626.50 695.05 N 113.02 E 5995218.15 N 674274.46 E 0.619 695.40 6008.21 45.500 2.310 5654.91 5692.21 761.95 N 116.00 E 5995285.11 N 674275.89 E 0.385 759.86 --' 6102.01 45.870 2.400 5720.43 5757.73 829.01 N 118.76 E 5995352.21 N 674277.09 E 0.400 824.40 6196.81 46.260 2.290 5786.21 5823.51 897.22 N 121.55 E 5995420.47 N 674278.29 E 0.420 890.04 6290.10 46.500 2.940 5850.57 5887.87 964.68 N 124.64 E 5995487.99 N 674279.80 E 0.566 955_06 6385.07 46.060 2.380 5916.21 5953.51 1033.25 N 127.82 E 5995556.60 N 674281.39 E 0.629 1021.16 6479.29 44.260 4.580 5982.64 6019.94 1099.92 N 131.86 E 5995623.36 N 674283.87 E 2.528 1085.74 6572.69 44.370 3.430 6049.47 6086.77 1165.01 N 136.41 E 5995688.53 N 674286.91 E 0.868 1148.97 6666.27 44. 100 5.390 6116.53 6153.83 1230.09 N 141.43 E 5995753.71 N 674290.41 E 1 .489 1212.33 6760.48 43.940 6.390 6184.27 6221.57 1295.21 N 148.15 E 5995818.97 N 674295.60 E 0.757 1276.27 6854.80 44.070 5.240 6252.12 6289.42 1360.40 N 154.79 E 5995884.30 N 674300.72 E 0.858 1340.25 6948.17 44.270 4.120 6319.09 6356.39 1425.24 N 160.09 E 5995949.24 N 674304.52 E 0.863 1403.48 -~---- -- ~-- --- - 22 May, 2002 . 13:05 Page 2 of 5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for NV-18 - P1-18A Your Ref: API 500292295301 Job No. AKMW22063, Surveyed: 1 May, 2002 BPXA North Slope Alaska Point Mcintyre Pad 1 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7041.98 44.860 2.970 6385.93 6423.23 1490.94 N 164.16 E 5996015.02 N 674307.05 E 1.066 1467.14 7136.30 45.270 1.780 6452.55 6489.85 1557.65 N 166.92 E 5996081.78 N 674308.26 E 0.993 1531.34 7257.61 46.200 4.790 6537.23 6574.53 1644.36 N 171.92 E 5996168.58 N 674311.23 E 1.935 1615.24 _J 7352.23 46.570 4.920 6602.50 6639.80 1712.62 N 177.72 E 5996236.95 N 674315.44 E 0.403 1681.87 7446.10 47.690 6.090 6666.36 6703.66 1781.09 N 184.32 E 5996305.56 N 674320.45 E 1.503 1748.96 7539.55 48.340 5.410 6728.87 6766.17 1850.21 N 191.28 E 5996374.82 N 674325.80 E 0.881 1816.76 7633.67 44.310 6.620 6793.86 6831.16 1917.89 N 198.39 E 5996442.65 N 674331.32 E 4.381 1883.26 7726.92 42.950 7.160 6861.35 6898.65 1981.77 N 206.10 E 5996506.69 N 674337.55 E 1.512 1946.33 7819.84 40.700 8.480 6930.59 6967.89 2043.15 N 214.52 E 5996568.25 N 674344.53 E 2.600 2007.25 7914.24 40.180 8.400 7002.44 7039.74 2103.72 N 223.50 E 5996629.02 N 674352.11 E 0.554 2067.58 8008.69 39.450 8.150 7074.98 7112.28 2163.57 N 232.21 E 5996689.05 N 674359.41 E 0.791 2127.14 8102.23 38.760 8.000 7147.57 7184.87 2221.98 N 240.50 E 5996747.64 N 674366.34 E 0.745 2185.20 8194.75 42.140 9.360 7217.97 7255.27 2281.30 N 249.58 E 5996807.16 N 674374.04 E 3.776 2244.38 8288.48 41.340 8.960 7287.90 7325.20 2342.91 N 259.51 E 5996868.98 N 674382.53 E 0.900 2305.99 8382.51 45.490 8.320 7356.19 7393.49 2406.79 N 269.21 E 5996933.07 N 674390.74 E 4.438 2369.68 8475.91 45.130 7.580 7421.88 7459.18 2472.55 N 278.39 E 5996999.02 N 674398.39 E 0.683 2435.00 8569.25 44.560 7.170 7488.06 7525.36 2537.83 N 286.84 E 5997064.48 N 674405.31 E 0.685 2499.63 8663.61 43.850 6.600 7555.70 7593.00 2603.14 N 294.73 E 5997129.96 N 674411.68 E 0.862 2564.12 8756.04 43.270 8.490 7622.68 7659.98 2666.28 N 303.09 E 5997193.27 N 674418.56 E 1.542 2626.69 8851.17 42.270 14.140 7692.54 7729.84 2729.57 N 315.72 E 5997256.85 N 674429.72 E 4.167 2690.76 8945.56 39.730 17.870 7763.78 7801.08 2789.08 N 332.74 E 5997316.74 N 674445.34 E 3.736 2752.60 9039.14 36.970 21.830 7837.18 7874.48 2843.69 N 352.39 E 5997371.79 N 674463.71 E 3.948 2810.61 9134.91 34.700 24.950 7914.82 7952.12 2895.15 N 374.60 E 5997423.75 N 674484.72 E 3.042 2866.45 9228.24 32.730 29.650 7992.46 8029.76 2941.17 N 398.29 E 5997470.32 N 674507.34 E 3.501 2917.58 9323.75 31.610 39.320 8073.36 8110.66 2983.01 N 426.95 E 5997512.80 N 674535.01 E 5.512 2966.29 9417.42 31.080 47.010 8153.39 8190.69 3018.50 N 460.20 E 5997549.06 N 674567.43 E 4.305 3010.43 9511.13 30.080 55.200 8234.10 8271.40 3048.41 N 497.19 E 5997579.82 N 674603.71 E 4.569 3050.44 9604.74 30. 150 62.000 8315.10 8352.40 3072.84 N 537.23 E 5997605.18 N 674643.17 E 3.644 3086.20 9698.95 29.410 68.110 8396.89 8434.19 3092.58 N 579.59 E 5997625.90 N 674685.06 E 3.314 3118.23 9793.32 29.540 76.830 8479.08 8516.38 3106.52 N 623.76 E 5997640.87 N 674728.89 E 4.545 3145.33 - -...--..---- --~------ 22 May, 2002 - 13:05 Page 30'5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for NV-18. P1-18A Your Ref: API 500292295301 Job No. AKMW22063, Surveyed: 1 May, 2002 . BPXA North Slope Alaska Point Mcintyre Pad 1 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9886.47 29.710 84.650 8560.09 8597.39 3113.91 N 669.12 E 5997649.31 N 674774.07 E 4.151 3166.58 9980.76 29.590 84.010 8642.03 8679.33 3118.52 N 715.54 E 5997655.00 N 674820.37 E 0.359 3185.53 10074.79 30.720 82.630 8723.33 8760.63 3124.02 N 762.45 E 5997661.60 N 674867.13 E 1.410 3205.4 7 ..........~ 10168.48 31.530 81.530 8803.54 8840.84 3130.70 N 810.41 E 5997669.39 N 674914.93 E 1.056 3226.87 10261.74 32.460 81.330 8882.63 8919.93 3138.06 N 859.27 E 5997677.89 N 674963.61 E 1.004 3249.19 10354.86 32.840 80.540 8961.04 8998.34 3145.98 N 908.88 E 5997686.96 N 675013.02 E 0.613 3272.28 10449.04 33.820 78.460 9039.73 9077.03 3155.42 N 959.75 E 5997697.58 N 675063.66 E 1.598 3297.21 10542.95 33.860 77.580 9117.73 9155.03 3166.28 N 1010.91 E 5997709.63 N 675114.55 E 0.524 3323.57 10641.00 33.860 77.580 9199.15 9236.45 3178.03 N 1064,26 E 5997722.62 N 675167.61 E 0.000 3351.47 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.473° (22-Apr-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 18.290° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10641.000. The Bottom Hole Displacement is 3351.49ft., in the Direction of 18.515° (True). '~~/. - --"---- -~- - --------- 22 May, 2002 - 13:05 Page 4 0'5 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for NV.18 . P1-18A Your Ref: AP/500292295301 Job No. AKMW22063, Surveyed: 1 May, 2002 . North Slope Alaska BPXA Point Mcintyre Pad 1 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment -' 4403.82 4491.00 10641.00 4391.20 4477.32 9236.45 99.56 S 86.02 S 3178.03 N 29.03 E 28.73 E 1064.26 E Tie On Point Window Point Projected Survey Survey tool program for NV-18 - P1-18A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 10641.00 9236.45 MWD Magnetic (NV-18) '-' -- - ----- ---- 22 May, 2002 - 13:05 Page 5 of 5 Dril/Quest 2.00.08.005 ScbluJllbePleP Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth - Well -- P1-18A ..-if);) "'Oïlø H-06 1 1 ï - 0 () à D.S. 9-13 / Î 7 - {)()?j D.S. 11-24A I q ~ --H.ot./ F-12 I 7q -lOt D.S. 4-31 1 ~5 - 07l/ D.S.16-28 J 'Jd -()~~ C-11 lì9-()c.J£D D.S.4-35 J 91-{) 3q D.S.17-05 J ){O-Q 9f.c, D-5 '10- On C; X-29 J L} 3 - J 3 q D.S.6-19 I ~d.- Jl '-/ D.S.16-17 J?{5 -dõ\O D.S.16-15 J ~5-~ lDt./ F-10A dDO-OIo 7 D.S. 9-11 J ì 1.0 - 0 r.:¡t.j F-31 J ~lø-J 5 I D.S.9-41 , q D '" () í4 D.S.9-21 / 5r~ ... J feo D.S. 3-21 I <6'.3" J Jd D.S.6-11 J Î '1- JI a BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson BJvd. Anchorage, Alaska 99508 Date Delivered: 06/20/02 NO. 2183 Company: State of Alaska Alaska 011 & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Job # Color Date Blueline Sepia Prints CD 06/11/02 1 06/08/02 1 06/05/02 1 06/11/02 1 06/10/02 1 06/05/02 1 06/07/02 1 06/07/02 1 06/06/02 1 06/08/02 1 06/07/02 1 06/06/02 1 06/05/02 1 06/04/02 1 06/04/02 1 06/03/02 1 06/03/02 1 06/03/02 1 06/02102 1 06/02102 1 06/04/02 1 06/03/02 1 Log Description PROD PROFILElDEFT PROD PROFILE/DEFT/GHOST PROD PROFILElDEFT PROD PROFILE/GHOST PROD PROFILE STATIC PRESSURE SURVEY STATIC PRESSITEMP SURVEY STATIC PRESSITEMP SURVEY SBHP SURVEY STATIC PRESSITEMP SURVEY STATIC PRESSITEMP SURVEY INJECTION PROFILE STATIC PRESSITEMP SURVEY STATIC PRESSURE SURVEY STATIC PRESSURE SURVEY STATIC PRESSURE SURVEY STATIC PRESSITEMP SURVEY STATIC PRESSURE SURVEY STATIC PRESSITEMP SURVEY STATIC PRESSITEMP SURVEY STATIC BHPIT SURVEY STATIC PRESSITEMP SURVEY RECEIVELJ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie J! 1 !\.~ 2 1 ",-' 002 VI. I Alaska Oil & Gas Cons. Commission AnooOf8'JÐ Received ~vik.r'" J @C?""c-:Jl: ~ - Å. - .b ') : F !Æ~!Æ ~~~!Æ ) ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Point McIntyre P 1-18A BP Exploration (Alaska) Inc. Permit No: 202-076 Sur Loc: 1394' NSL, 880' WEL, SEC. 16, TI2N, RI4E, UM Btmhole Loc: 4540' NSL, 223' EWL, SEC. 16, T12N, R14E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. . Annular disposal has not been requested as part of the Permit to Drill application for Point McIntyre P 1-18A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~ ~¿1: ~/~ Camm~chsli TaylorÓV- . Chair BY ORDER OF THE COMMISSION DATED this :l7-H- day of March, 2002 jjcÆnc10sures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 8-3/4" -) STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISL )N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 38.801 Point Mcintyre 6. Property Designation ADL 028297 7. Unit or Property Name Point Mcintyre 8. Well Number P1-18A 9. Approximate spud date 04/15/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10655' MD / 9253' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 45 Maximum surface 3420 psig, At total depth (TVD) 8800' / 4300 psig Setting Depth T OD Bottom Quantitv of Cement Length MD TVD MD TVD (include stage data) 106551 Surface Surface 10655' 9253' 191 sx Econolite, 193 sx Class 'G' V:-iGA-' -S/27{D L 4r-~ {d- "" -ð ~ 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1394' NSL, 880' WEL, Sec. 16, T12N, R14E, UM At top of productive interval 4504' NSL, 192' WEL, SEC. 16, T12N, R14E, UM At total depth 4540' NSL, 2231 EWL, SEC. 16, T12N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 384405,223' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 4494' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weight Grade CouDlina 7" 26# L-80 /13Cr80 BTCM / Vam Top 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11187 feet 1 0061 feet 4512 feet 4498 feet Length Plugs (measured) Abandonment Plug Junk (measured) Size Cemented MD TVD 110' 4581' 20" 9-5/8" 260 sx Arcticset (Approx.) 638 sx Arctic Set, 316 sx Class 'GI 110' 4610' 110' 4595' ~.'/¡¡~~: ll I':.Q¡~ 1'~':"~'tJ {;"..~::-.;' :,~i, ':"I~' . J /,~;. ~.".., är. ~;, I\! '\ '" I ~,~,.,- \",Jì 1:1...... \1 \"I'~ (,) ..... '-', (\~ eel"'" {,J 1 {Ul.:L. Perforation depth: measured None Alaska Oit ~,G~s Cons. Cornmiss!on true vertical None 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dave Wesley, 564-5773 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th~ for oing is true;d<,;orrect to the best of my ~nOwl~~ge . Signed Lowell Cran. ~" ~ - Title Senior Dnlllng Engineer Date 3 .-,;ll- ~ 2. Commission Use Only Approval Date See cover letter -~/ rl ì IDd.- for other requirements Mud Log Required 0 Yes ~ No Directional Survey Required l:8fYes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU Permit Number API Number Zc; Z. - cJ ? 6 50- 029-22953-01 Conditions of Approval: Samples Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: Lt~ ç>~\ ~a>2~\-~Wflf Approved By Or;§~~rsì_~ $~\ \ l',' Commissioner Form 10-401 Rev. 12-01-85 OammtOethSli ! ,~, .~ ~-- by order of the commission Date 3/ d 1/ () J.. S~brrlit In Triplicate ") } ') IWell Name: Ip1-18A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Conventional Sidetrack Producer Surface Location: As-Built Target Location: Kuparuk Bottom Hole Location: x = 674,177.67 Y = 5,994,520.66 1393' FSL (3886' FNL), 879' FEL (4399' FWL) Sec. 16, T12N, R14E Umiat X = 674,785.00 Y = 5,997,646.00 TVDss = 8551' 4504' FSL (775' FNL), 192' FEL (5086' FWL) Sec. 16, T12N, R14E Umiat X = 675,200.00 Y = 5,997,692.00 TVDss = 9214' 4540' FSL (739' FNL), 5056' FEL (223' FWL) Sec. 15, T12N, R14E Umiat I AFE Number: 15L 1023 I Estimated Start Date: I 04/15/2002 1./ 1 MD: 110,655' 1 I RiQ: 1 Nabors 2ES ,/ I OperatinQ days to complete: 116.83 1 TVD: 19,253' 1 I BF/MS: 18.80' I 1 I RKB: 138.80' I I 1 I Well DesiQn (conventional, slim hole, etc.): 1 Conventional Sidetrack I Objective: I Kuparuk CasinQrrubinQ ProQram Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 8 3/4" 7" 26.0# L-80 STCM 9,735' Surface 9,735' / 8,460' 7" 26.0# 13Cr-80 Vam Top -1,000' 9,735' 10,655' / 9,253' Tubing 4 Y2" 12.6# 13Cr-80 Vam Ace -9,735' GL 9,785"/8,500' Directional KOP: 14,494 MD Maximum Hole Angle: Close Approach Well: Survey Program: P1-18A Sidetrack -51.0° in original well bore from -6300' MD to -6700' MD. (Plugged back) -45.0° through intermediate section of planned sidetrack from 5355' MD to 8681' MD, dropping back to 33° through production interval. There are no close approach issues. All wells pass Major Risk Criteria. The ,/ closest well to the P1-18A is P1-13 with a center-to-center distance of 199' and allowable deviation of 156' at the planned depth of 4,526' MD. There is a surface close proximity issue with P1-17. These are on 15' center. P1-17 will require being secured for rig MIRU. Standard MWD Surveys from kick-off to TD. Page 1 I ) Mud Program Window Milling Mud Properties: LSND Density (ppg) Viscosity PV 9.4 45 - 55 9 -15 Intermediate Mud Properties: LSND Density (pp~ Viscosity PV 9.4 - 9.6 45 - 55 9 - 15 Production Mud Properties: 30/0 KCI / GEM Density (ppg) Viscosity PV 10.2 - 10.4 / 45 - 60 10 - 15 \. l I Whip Stock Window 9 5/8" I YP ~uO MBT 25 - 35 5 - 8 18 %" Intermediate/Production I YP ~uO MBT 20 - 25 4 - 7 I 8 %" Production tauO 5-8 I MBT YP 15 - 25 Logging Program 8 3/4" Intermediate: Sample Catchers - None Drilling: MWD Dir/GR/Res- Real time GR/Res to top of HRZ Open Hole: None Cased Hole: None pH API FI 8.5 - 9.5 6-8 pH API FI 8.5- 9.5 6-8 pH API FI 8.5 - 9.0 3-6 83/4" Production: Sample Catchers - Two, at Company man call out Drilling: MWD Dir/GR/Res/ + Neu/Den - Real time GR/Res; Recorded Neu/Den through Kuparuk Open Hole: None Cased Hole: None Cement Proç ram Casing Size 7" Long-string Casing I Basis: Lead: Based upon 2925' of 8 3/4" open hole with 40% excess. Lead TOG: -6800' MD (-6260'TVD). Tail: Based on 80' of 7" shoe track, -1000' of 83/4" open hole with 40% excess. Tail TOG: -9655' MD (-8420'TVD. Fluid Sequence & Volumes: Pre 10 bbls Water Flush Spacer Lead Tail P1-18A Sidetrack 50 bbls Alpha Spacer at 11.4 ppg 110 bbl I 618 ft;j I 191.1sks of Halliburton Econolite at 11.2 ppg and 3.24 cf/sk.~ 41 bbl I 200 fe I 193""sks of Halliburton 'G' at 15.8 ppg and 1.15 --- . cf/sk, BHST 1850 Page 2 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential sujface pressures. Based upon calculations below, BOP equipment will be tested to 4000 psi. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: l300 psi @ 8800' TVDss - Kuparuk . Maximum surface pressure: 3420 psi @ surface (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 4000 psi J 8.6 ppg seawater / 7.2 ppg Diesel . . No annular injection in this well. /' Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . Formation Markers Formation Tops (Wp#6) T8 T5 T3 K-15/ Ugnu K-13 / West Sak K-12 / Colville K-10 Top HRZ Kuparuk OWC OOWC Miluveach TD MD TVDss 3523 3888 4490 4920 6615 6743 8265 8463 8551 9030 9069 9133 9194 Comments Estimated Pore Pressure 2320 psi (-9.1ppg EMW) Estimated Pore Pressure 3075 psi (-9.0ppg EMW) Est. Pore Pro 4300 psi (+50/-200) (-9.2 - 9.8ppg) TD Criteria: 150' MD below OOWC(9069' TVDss) to allow for minimum of 50' rat hole from final PBTD. P1-18A Sidetrack Page 3 ) ') Sidetrack and Complete Procedure Summary Riq Operations: 1. Secure P1-17. Shut in at SSSV and Wing valve. 2. MIRU Nabors 2ES. 3. Rig up drillers console for remote access to P1-17 SSSV panel. 4. Bring P1-17 backon line. 5. RU and circulate out freeze protectionlnd displace surface casing to seawater. 6. Nipple up BOPE and test to 4000psi. ' 7. Pull 3 %" "kill string" tubing from well and UD. 8. P/U 5" drill pipe and milling assembly. .// 9. RIH, drift 9 5/8" surface casing to TOC plug at approximately 4512' MD. POOH and stand back milling assembly. / 10. Test 9 5/8" surface casing to 3500 psi for 30 minutes. ,-1. RU and RIH with 95/8" Baker Whip Stock assemb}y. Orient whip stock as desired and set on cement plug. Mill window in 9 5/8" casing at -4494' MD. Mill Idrill -20 feet of new formation. Pull up into 9 \J 5/8" casing and conduct FIT to 12.5ppg EMW. POOH. \ ~ 2. MU 8 3/4" directional assembly with MWD/GR/Res and RIH. Kick-off and drill the 8 3/4" intermediate I ~"':.K production interval. Density and Neutron sensors are required from HRZ to TD. Plan BHA change ,~<7 accordingly. Drill ahead to an estimated total depth of 10,653' MD (9253;rVD). ~ 13. Run and cement 7", 26#, L-80 X 13Cr-80 (below packer) casing to TD. 14. Test the 7" casing to 3500 psi for 30 mir1Jtes. 15. Run 4%", 12.6# 13Cr-80 completion. 16. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. >' S ~ Post-Riq Work: 1. MIRU slick line. Pull the ball and rod I RHC plug from 'X' nipple below the production packer and install gas lift valves. Estimated Start Date: April 15, 2002 P1-18A Sidetrack Page 4 ') ) Job 1: MIRU Hazards and Contingencies ~ One well, P1-17, will require shut-in for the rig move onto P1-18A. P1-17' is 15' to the East of the P1-18 surface location. P1-17 may be irreparably damaged if shut-in for extended periods of time. For this reason, it is imperative to minimize shut-in time during the rig MIRU. The SSSV control panel will be plumbed to the driller's console, once the rig has been spotted on the P1-18 slot. This will allow for the P1-17 to be returned to flowing condition as soon as the rig move is complete. ~ Pt. Mac 1 is not designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: P1-17 15 ppm P1-09 20 ppm P1-20 10 ppm P1-17 15 ppm The maximum level recorded of H2S on the pad was 60 ppm, in 10/1998. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP's .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" SOP ~,,;,~,:.;,:,I,I,I¡JJ'Þ,c,:mm.m,¡mm,lm.l, ~~im,I.I.I,I ,I,~IAAm,r..C,:m'm¡,r'¡,:A~¡~,I,~»,I,I.I,:,I,I>~ .I,: .,~,1.4,1¡.',I,~'m~I"':I",',;~;;,~:,:,:':':':n:':':;:':,~,U:,I),\:,I,-,-¡.:,:,:;.lm,I.I.I,:,l,Ih':I:D:Cmm.l,lm~>ÞAI,IÞ,I',:,lm,:Þ", ,'I~-¡,:,I<:,: m,-,!,I,IJ',I.l.I!,I;.I,I,I,!,IJ,I,:!,!mmml,I,IIm,I.D,I,I'!!.l.I,IAAI.I),lþ.I,:,I,~:mmm.l,~',I,:,I;,)!,:,I,I,I,-:,~!,I'-.',-,:mm,"',;.I¡,W¡'¡~h,;~-,-,\\:,I.-¡mm.~ Job 2: De-complete Well Hazards and Contingencies ~ The lower section of this well, below the surface shoe at 4609' MD, was P&A'd by 4 separate 15.8 ppg cement plugs. There is no casing below the 9 5/8",40# surface pipe. An EZSV cement retainer is set in the 9 5/8" casing at 4543' MD. There is 2192 feet of 3 Y2", 9.3#, EUE 8rnd tubing (kill string) in the well. This will require pulling. ~ There is no complete wellhead or tree on the P1-18. A single tubing spool, valve, and cap are all that is present, currently. Take care to determine whether or not there is any trapped pressure below the well cap. Reference RP's .:. "De-completions" RP 11IIII1.-r -I. .T -IT _LLlL_ILn:mUIU--U I.. I_ml:lUm"'ln_lnlln_I":mllll_IIIII~ __mlllll!ll,.:mmllm:IIIIIIIII\ ~I:n"I!IIU:I; -:IIIn;II-I"C- - mlll!!m:_II- _III 1.11. -I. :In::IT--1 III:IUI"lm!ml!nmlllllnl..~lmllumlmlllll_I_I. _1- _1- --11-- --II"-III;;:lIInll Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP's .:. "Whip stock Sidetracks" RP P1-18A Sidetrack Page 5 ) ) Job 5: Drill 8 3/4" Intermediate / Production Hole Hazards and Contingencies ~ The well will exit the 9 5/8" 40# L-80 surface casing and kick-off in the T -5 (8V3) sand. Previous Pt. Mac 1 wells drilled the intermediate section, down through the HRZ with 9.4 to 10.2 ppg mud weights. Follow all shale drilling practices to minimize potential problems. ~ The lower section of this well will be drilled with 1 0.2ppg to 10.4ppg mud weight. ~ Nearby well P1-17 experienced stuck pipe while running 7 5/8" casing. The casing became stuck at -4468' TVDss, while pumping and rotating through a tight section. Due to insufficient hole- cleaning, the well bore packed off. ~ KICK TOLERANCE: In the worst-case scenario of a 9.6ppg pore pressure at the Kuparuk depth, a fracture gradient of 12.0ppg at the 9 5/8" casing window, and 10.4ppg mud in the hole, the kick tolerance is 68.1 bbls. Reference RP's .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP TD Criteria: The onsite geologist will be needed throughout the intermediate hole section for correlation of formation markers and selection of interval TD. Jr):..::,~~JMI,~m.~ ~...rl<.;';";;"¡¡"~~~<I#¡I¡Ji.,~~/iIAA;';';~~~;';":,;;¡';"¡':':'¡';';';':w,~.";';"¡;""~~~ Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Kuparuk or exacerbate shale instability problems. Reference RP's .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP 1~'mffl'iimr--m'lmm'/'iff'/fI'i''''I'/'f'~-'lØ.'!''k'''''''-:""':.'':''''''':"'''~'.'"'-'''~::''' '-..' - """'¡';'¡';' '-,:":,""'1'(,. '",/¥;.¡.m;.;..~;; \. '-.\'f'im<'t(Yr/'ftM'I"I~'ff:"_'fff_'I'!-.\\W~~'' ' \,'\t,;rrrr:'IOO~'tff'i~,il'1.'~'_>r-Y_'.;J;.iIí J(l1>ij'I'f~~III.'-''-'-.--'r'1'Þ'~'I~'_'~f'i'~¡.)AItIJAA Job 12: Run 4 Y2" Chrome Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP's .:. "Completion Design and Running" RP .:. "Tubing connections" RP "¡' 11- '.,' "j '; '\.,. ';--~-II"UI;,'- . ~ -, '1\.. - .... P1-18A Sidetrack Page 6 ') ) Job 13: ND/NU/Release RiQ Hazards and Contingencies >- There is one close proximity surface issue, P1-17. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. Reference RP's .:. "Freeze Protecting an Inner Annulus" RP P1-18A Sidetrack Page 7 'KB:"Ë[ÐT';""''''''''''''''''''''37'~92i' ,~~.,:~,,~ç~~~~=::~~::~~!~,,~f~,,:~,9~, . KOP = -4500' ~~~~~,~!~"~,,,..,?2~:~~:~:~~~":~ DatumMD= 11117' MD '5ã'tüm'ñTj);'''''''''''-'999'1'ì''T\75 1 3 1/2",9.3#, L-80 IBT Mod Kill String I 95/8",40#, L-80, BTC ID = 8.835" DA TE REV SY 02/04/02 DEW Þ1-18 Current ] l----i 2192' 1 ~ ;":.' 'Ø; .:~;c [ - 12045' 14512' I )well P&A'd below the surface shoe. l----i 9 5/8" HES Stage Cementing Collar l----i TOC; 15.8 ppg Cement plug l----i 4610' 1- ~ --- ----"'" -14543' ,'C} ,.. l----i EZSV Cement Retainer .:'.-'" '~!'¡:, *, :.-=t .~-:W ~ :} t.~ €b i..... {w§~ COMMENTS Reconstruct current condition diagram '.~~ : . :.:; ~ ',: 14709' 19320' 19913' l----i BOC; 15.8 ppg Cement plug l----i TOC; 15.8 ppg Cement plug; 48 bbls I l----i soc; 15.8 ppg Cement plug; 48 bbls 1 110877' l----i TOC; 15.8 ppg Cement plug; 26 bbls I w,.) 111187' l----i 8 3/4" Hole TD PRUDHOE SA Y UNIT WELL: P1-18 ÆRMIT No: API No: 50-029-22953-00 Sec.16, T12N, R14E, 1391' FSL, 881' FEL BP Exploration (Alaska) Œ{lÆlID\lE V'OOJ "RS:"'ÉGèJ";"-"""--""'''''^' ''''''3'ãjjì :9~::~~~~~~~~::~..~,~.!.:,"~~~~~~ . KOP = 4500' "MãXA'ñgle -;^"45;;-@~53"ŠŠ'" ^5atUm"MO",;;"",,,,,,,w''''''"gSSS;"bkb' 'õätüñ1"i\l5;'--"""'''''''"ã's5fì'SS' ') P~I-18A Propose",) 0 [ -120451 122001 1---1 9 5/8" HES Stage Cementing Collar 1---1 41/2" CAMCO BAL-O SSSV Nip. 10=3.813" I ] ~, ,," ,~.. "r.~},c ~_145431 ..' .~} " 146091 1---1 9 5/8" Baker Whip Stock I 1---1 TOC; 15.8 ppg cement plug 1---1 EZSV Cement Retainer 1---1 9 5/8" , 40#, L-80, BTC, 1.0.= 8.835" I :~~ .:~; l l < ST MO 6 4210 5 5365 4 6825 3 8195 2 9240 1 9680 GAS LIFT MANDRELS. TVD DEV TYÆ SIZE 4200 8° 41/2" X 1" 5200 45° 41/2" X 1" 6250 45° 4 1/2" X 1" 7250 45° 41/2" X 1" 8050 31 ° 4 1/2" X 1" 1 JAA<r 32° 4 1/2" X 1" COMMENTS z I 1- 197101 < Z -197351 < ~-197551 1- 197751 - 197851 41/2" 'X' Landing Nipple; I.D. = 3.813" 1 7" 26# L-80 Csg. (above packer) I 1 7" X 4 1/2" Baker S-3 Packer I 7" 26# 13Cr-80 Csg. (below packer) 1 41/2" 'X' Landing Nipple; I.D. = 3.813" 1 97351 I 4 1/2" 'XN' Landing Nipple; I.D. = 3.725" 1 97351 I I I I 41/2" Tubing Tail WLEG 1 Top Kuparuk prognosed @ 9885' MD. I PBTD @t , { ~^ . ,,~~ I 7" 26# 13 Cr-80 Casing I 105731 I I 106551 1 DA TE REV BY COMMENTS 02104/02 DEW Reconstruct current condition diagram. 03/15/02 DEW A"oposed P1-18A Wp7 Cof11Jletion (Sidetrack Option) PRUDHOE BA Y UNIT WELL: P1-18A ÆRMIT No: API No: 50-029-22953-01 Sec.16, T12N, R14E, 1391' FSL, 881' FEL BP Exploration (Alaska) rn\tAq ~lF rnrnfP '. North Slope Alaska BPXA Point McIntyre Pad 1, Slot P1-18 P1(NV)-18 WPs - NV-18A Wp 07 Revised: 18 March, 2002 ~ PROPOSAL REPORT 18 March, 2002 Surface Coordinates: 5994520.66 N, 674177.67 E (70023' 26.5922H N, 148034' 58.7442" W) Surface Coordinates relative to Project H Reference: 994520.66 N, 174177.67 E (Grid) Surface Coordinates relative to Structure Reference: 146.44 S, 174.31 E (True) Kelly Bushing: 38.80ft above Mean Sea Level ~ SpE!""""Y-~U'" DR ILL IN G' -- 5 e R v I c::e 5 A Halliburton Company Proposal Ref: pr011137 North Slope Alaska BPXA Point Mcintyre Pad 1 P1(NV)-18 WP07 Eastings Total Depth: 10653.52ftMD,9194.78ftTVD 0 800 I End Dir, Start Sail @ 33.019°: 9885.74ftMD,8551.0OftTVD I ;~~;~i;! N~:/.~A l\UJ1Ql1It . ~9233'5R / .~S89.8n TVV, 1//0.14 N, (,71.971, --------- ---- ~ - 3200 NV-18A w oy 'j.- / 1. // ~ / Scale: 1 inch = 800ft \ L Sidetrack Highside @ 10.00°/1 oaft: 4494.00ft MD, 4480.28ft TVD 4500 - , ..... Decrease in Dir Rate @ 4.ooo/1ooft: 4514.00ft MD, 4499.97ft TVD 5500 - 6500 - End Dir, Start Sail @ 44.697° : 5355.05ftMD,5193.92ftTVD .c ã. a.> ::) (ij 0 e ~ 7~iñDir @ 4.0000/100ft: 8679.18ft MD, 7556.83ft 8500 - ~ 0 0 0 ..... II .c 0 .!: 9500- Q) (ij 0 Cf) Eld Dir, Start Sail @ 33.019° : 9885.74ftMD,8551.0Oft .VD PI.l-'H KllJ>amlc -----.w------.-- .--- .~_Ç-W8f1 n¡o, 3/111.3-1 N, (,79.97 J-: . 1-' /. /.'to, '\/i{¡,".:arh ------------- -----.---- ----.- -- .------- <¡1n..WITH), JJ42.57 N, ltJ_if)./iJ I, ~ Total Depth: 10653.52ftMD,9194.78ftTVD ~ I 0 1000 Scale: 1 inch = 1000ft Begin Dir @ 4.0000/100ft: 8679.18ft MD, 7556.83" TV~ It NV-I!>'" Mjluv~".:/¡ 917/.1>!J 'fI'J>. 31-1:1-S; N. WSliX1 ¡; (. - 2400 .~ . (' (fJ 0> c: - 1600 :.ë: t 0 Z 5per"r"V-SUI1 DRIL.L.INCS SE~vj'ces /I, Hallibur'l~ C_IIy - 800 7" Ca.çing 10653.52 9233.58 End Dir, Start Sail @ 44.697° : .- 5355.05ftMD,5193.92ftTVD ---- Decrease in Dir Rate @ 4.000/1OOft: 4514.00ft MD, 4499.97ft TVD ~ Sidetrack Highside @ 10.00°11 oOtt: ~ 4494.00ft MD, 4480.28ft TVD ~ 0 0 co 11 .c ü .!: -- 0 Q) (ij 0 Cf) 0 I 800 Reference is True North Eastings Scale: 1 inch = 800ft I I 2000 3000 Section Azimuth: 18.290° (True North) Vertical Section North Slope Alaska BPXA Point Mcintyre Pad 1 P1 (NV)-18 WPs Measurement Units: Single Well Target Data for P1 (NV)-18 WPs ft Target Name Coordinate Point Type TVDRT Northings . Eastings TVDSS ASP4 Y ASP4 X Target Shape NV-18A Kuparuk Entry Point 8589.80 31] 0.34 N 679.97 E 8551.00 5997646.00 N 674785.00 E 1056.83 E 9133.00 5997687.00 N 675]61.00 E Circle NV-18A Miluveach Entry Point 9171.80 3]4~,57 N Point "~ Proposal Data for NV-18A Wp 07 Vertical Origin: P1-18 Horizontal Origin: P1-18 Measurement Unitsft North Reference: True North Dogleg severity : Degrees per 100 feet (US) Vertical Section Azimuth: 18.290° Vertical Section Description: P1-18 Current Well Properties Vertical Section Origin: 0,00 N,O.OO E .~ .1easured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Well: P1(NV)-18 WPs Depth Depth Section Rate Horizontal Coordinates: Ref. Global Coordinates: 5994520.66 N, 674177.67 E 4494.00 9.099 0.974 4480.28 85.58 S 28.79 E -72.22 Ref. Structure Reference: 146.44 S. 174.31 E 45 J 4.00 J J.l 00 J.OOO 4499.97 82,07 S 28.85 E -68.87 10.004 Ref. Geographical Coordinates: 70023' 26.5922" N, 148034' 58.7442" W 5355.05 44.697 5.588 5232.73 304.42 N 59.96 E 307.86 4.000 RKB Elevation : 38.800 above Mean Sea Level 8679.18 44.697 5.588 7595.63 2631.36 N 287.63 E 2588.69 0.000 38.8Oft above Structure Reference 9885.74 33.019 85.112 8589.80 3110.34 N 679.97 E 3166.60 4.000 10579.85 33.019 85.112 9171.80 3142.57 N 1056.83 E 3315.47 0.000 North Reference: True North 10653.52 33.0J 9 85.112 9233.58 3 J45.99 N 1096.83 E 3331.27 0.000 Units: Feet (US) DrillQuest 2.00.09.001 Sperry-Sun Drilling Services . Proposal Report for P1(NV)-18 WPs . NV.18A Wp 07 Revised: 18 March, 2002 BPXA North Slope Alaska Point Mcintyre Pad 1 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 4494.00 9.099 0.974 4441 .48 4480.28 85.58 S 28.79 E 5994435.77 N 674208.45 E -72.22 Sidetrack Highside @10.000/1OOft: 4494.000 MD, 4480.28ft TVD 4500.00 9.699 0.983 4447.40 4486.20 84.60 S 28.81 E 5994436.75 N 674208.44 E 10.004 -71 .29 4514.00 11.100 1.000 4461.17 4499.97 82.07 S 28.85 E 5994439.28 N 674208.43 E 10.004 -68.87 Decrease in Dir Rate @ 4.000/10Oft: 4514.00ft MD, 4499.97ft TVD 4543.44 12.272 1.563 4490,00 4528.80 76.11 S 28.99 E 5994445.24 N 674208.42 E 4.000 -63.17 T3 4600.00 14.526 2.392 4545.01 4583.81 63.01 S 29.45 E 5994458.35 N 674208.58 E 4.000 -50.59 '--- 4700.00 18.517 3.373 4640.87 4679.67 34.62 S 30.90 E 5994486.77 N 674209.37 E 4.000 -23.17 4800.00 22.510 4.016 4734.51 4773.31 0.34N 33.18 E 5994521.77 N 674210.83 E 4.000 10.74 4900.00 26.506 4.473 4825.48 4864.28 41.70 N 36.26 E 5994563.19 N 674212.95 E 4.000 50.97 5000.00 30.503 4.818 4913.34 4952.14 89.26 N 40.14 E 5994610.83 N 674215.72 E 4.000 97.34 5007.74 30.812 4.841 4920.00 4958.80 93.19 N 40.47 E 5994614.77 N 674215.96 E 4.000 101.18 K-15/UGNU 5100.00 34.500 5.090 4997.66 5036.46 142.77 N 44,78 E 5994664.44 N 674219.11 E 4.000 149.62 5200.00 38.498 5.312 5078.03 5116.83 202.00 N 50.18 E 5994723.77 N 674223.13 E 4.000 207.54 5300.00 42.496 5.497 5154.06 5192.86 266.64 N 56.30 E 5994788.54 N 674227.74 E 4.000 270.83 5355.05 44.697 5.588 5193.93 5232.73 304.42 N 59.96 E 5994826.39 N 674230.53 E 4.000 307.86 End Dir, Start Sail @ 44.697° : 5355.05ftMD,5193.92ftTVD 5400.00 44.697 5.588 5225.88 5264.68 335.88 N 63.04 E 5994857.92 N 674232.87 E 0.000 338.70 5500.00 44.697 5.588 5296.96 5335.76 405,89 N 69.89 E 5994928.06 N 674238.09 E 0.000 407.31 5600.00 44.697 5.588 5368.04 5406.84 475.89 N 76.74 E 5994998.21 N 674243.30 E 0.000 475.93 5700.00 44.697 5.588 5439.13 5477.93 545.89 N 83.59 E 5995068.35 N 674248.52 E 0.000 544.54 5800.00 44.697 5.588 5510.21 5549.01 615.89 N 90.44 E 5995138.49 N 674253.74 E 0.000 613.16 5900.00 44.697 5,588 5581.29 5620.09 685.89 N 97.29 E 5995208.63 N 674258.95 E 0.000 681.77 6000.00 44.697 5.588 5652.38 5691.18 755,89 N 104.14 E 5995278.77 N 674264.17 E 0.000 750.39 ~' 6100.00 44.697 5.588 5723.46 5762.26 825.90 N 110.99 E 5995348.92 N 674269.39 E 0.000 819.00 6200.00 44.697 5.588 5794.54 5833.34 895.90 N 117.84 E 5995419.06 N 674274.60 E 0.000 887.62 6300.00 44.697 5.588 5865.63 5904.43 965.90 N 124.68 E 5995489.20 N 674279.82 E 0.000 956.23 6400.00 44.697 5.588 5936.71 5975.51 1035.90 N 131.53 E 5995559.34 N 674285.04 E 0.000 1 024.85 6500.00 44.697 5.588 6007.79 6046.59 1105.90 N 138.38 E 5995629.49 N 674290.25 E 0.000 1093.46 6600.00 44.697 5,588 6078.88 6117.68 1175.90 N 145.23 E 5995699.63 N 674295.47 E 0.000 1162.07 6700.00 44.697 5.588 6149.96 6188,76 1245.91 N 152.08 E 5995769.77 N 674300.68 E 0.000 1230.69 6800.00 44.697 5.588 6221.05 6259.85 1315.91 N 158.93 E 5995839.91 N 674305.90 E 0.000 1299.30 6900.00 44.697 5.588 6292.13 6330.93 1385.91 N 165.78 E 5995910.05 N 674311.12 E 0.000 1367.92 18 March, 2002 - 16:40 Page2of6 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services .- Proposal Report for P1(NV}.18 WPs . NV.18A Wp 07 ~ Revised: 18 March, 2002 BPXA North Slope Alaska Point Mcintyre Pad 1 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 7000.00 44.697 5.588 6363.21 6402.01 1455.91 N 172,63 E 5995980.20 N 674316.33 E 0.000 1436.53 7100.00 44.697 5.588 6434.30 6473.10 1525.91 N 179.48 E 5996050.34 N 674321 .55 E 0.000 1505.15 7200.00 44.697 5.588 6505,38 6544.18 1595.91 N 186.33 E 5996120.48 N 674326.77 E 0.000 1573.76 7300.00 44.697 5.588 6576.46 6615.26 1665.92 N 193.17 E 5996190.62 N 674331.98 E 0.000 1642.38 7354.21 44.697 5.588 6615.00 6653.80 1703.87 N 196.89 E 5996228.65 N 674334,81 E 0.000 1679.58 K13/West Sak 7400.00 44.697 5.588 6647.55 6686.35 1735.92 N 200.02 E 5996260.77 N 674337.20 E 0.000 1710.99 ~ 7500.00 44.697 5.588 6718.63 6757.43 1805.92 N 206.87 E 5996330.91 N 674342.42 E 0.000 1779.61 7534.28 44.697 5.588 6743.00 '6781.80 1829.92 N 209.22 E 5996354.95 N 674344.20 E 0.000 1803.13 K-121 Colville 7600.00 44.697 5.588 6789.71 6828.51 1875.92 N 213.72 E 5996401.05 N 674347.63 E 0.000 1848.22 7700.00 44.697 5.588 6860.80 6899.60 1945.92 N 220.57 E 5996471.19 N 674352.85 E 0.000 1916.84 7800.00 44.697 5.588 6931.88 6970.68 2015.92 N 227.42 E 5996541.33 N 674358.06 E 0.000 1985.45 7900.00 44.697 5.588 7002.96 7041.76 2085.93 N 234.27 E 5996611.48 N 674363.28 E 0.000 2054.06 8000.00 44.697 5.588 7074.05 7112.85 2155.93 N 241.12 E 5996681.62 N 674368.50 E 0.000 2122.68 8100.00 44.697 5.588 7145,13 7183.93 2225.93 N 247.97 E 5996751.76 N 674373.71 E 0.000 2191 .29 8200.00 44.697 5.588 7216.21 7255.01 2295.93 N 254.81 E 5996821.90 N 674378.93 E 0.000 2259.91 8300.00 44.697 5.588 7287.30 7326.10 2365.93 N 261 .66 E 5996892.05 N 674384.15 E 0.000 2328.52 8400.00 44.697 5,588 7358.38 7397.18 2435.93 N 268.51 E 5996962.19 N 674389.36 E 0.000 2397.14 8500.00 44.697 5.588 7429.46 7468.26 2505.94 N 275.36 E 5997032.33 N 674394.58 E 0.000 2465.75 8600.00 44.697 5.588 7500.55 7539.35 2575.94 N 282.21 E 5997102.47 N 674399.80 E 0.000 2534.37 8679.18 44.697 5.588 7556.83 7595.63 2631.36 N 287.63 E 5997158.01 N 674403.93 E 0.000 2588.69 Begin Dir @ 4.000°/1000: 8679.18ft MD, 7556.83ft TVD 8700.00 44.121 6.447 7571,70 7610.50 2645.85 N 289.16 E 5997172.53 N 674405.12 E 4.000 2602.93 8800.00 41 .449 10.832 7645.11 7683.91 2712.98 N 299.29 E 5997239.87 N 674413.68 E 4,000 2669.84 8900.00 38.961 15.687 7721.49 7760.29 2775.78 N 314.02 E 5997303.00 N 674426.94 E 4.000 2734.09 - / 9000.00 36.697 21.068 7800.49 7839.29 2833.95 N 333.27 E 5997361.61 N 674444.83 E 4.000 2795.37 9100.00 34.701 27.012 7881.72 7920.52 2887.22 N 356.95 E 5997415.41 N 674467.26 E 4.000 2853.37 9200.00 33.023 33.532 7964.79 8003.59 2935.31 N 384.94 E 5997464.14 N 674494.13 E 4.000 2907.82 9300.00 31 .713 40.597 8049.28 8088.08 2978.00 N 417.11 E 5997507.57 N 674525.29 E 4.000 2958.45 9400.00 30.820 48.113 8134.79 8173.59 3015.07 N 453.30 E 5997545.47 N 674560.61 E 4.000 3005.01 9500,00 30.380 55.928 8220.89 8259.69 3046.36 N 493.33 E 5997577.68 N 674599.90 E 4.000 3047.27 9551.11 30.337 59.973 8265.00 8303.80 3060.06 N 515.21 E 5997591.89 N 674621.46 E 4.000 3067.15 K10 18 March, 2002 - 16:40 Page30f6 DriflQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for P1(NV)-18 WPs - NV-18A Wp 07 Revised: 18 March, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9600.00 30.413 63.838 8307.18 8345.98 3071.69 N 537.01 E 5997604.03 N 674642.98 E 4.000 9700.00 30.918 71.623 8393.23 8432.03 3090.96 N 584.13 E 5997624.39 N 674689.64 E 4.000 9781.62 31 .665 77.745 8463.00 8501.80 3102.12 N 624.98 E 5997636.50 N 674730.21 E 4.000 9800.00 31,872 79.084 8478.63 8517.43 3104.06 N 634.46 E 5997638.66 N 674739.64 E 4.000 9885.74 33.019 85.112 8551.00 8589.80 3110.34 N 679.97 E 5997646.00 N 674785.00 E 4.000 9900.00 33.019 85.112 8562.96 8601.76 3111.01 N 687.71 E 5997646.84 N 674792.72 E 0.000 10000.00 33,019 85.112 8646.81 8685.61 3115.65 N 742.01 E 5997652.75 N 674846.89 E 0.000 10100.00 33,019 85.112 8730.65 8769.45 3120.29 N 796.30 E 5997658.66 N 674901.07 E 0.000 10200.00 33.019 85.112 8814.50 8853.30 3124.94 N 850.59 E 5997664.56 N 674955.24 E 0.000 10300.00 33.019 85.112 8898.35 8937.15 3129.58 N 904.89 E 5997670.47 N 675009.41 E 0.000 10400.00 33.019 85.112 8982.20 9021.00 3134.22 N 959.18 E 5997676.38 N 675063.58 E 0.000 10457.01 33.019 85.112 9030.00 9068.80 3136.87 N 990.13 E 5997679.74 N 675094.46 E 0.000 10500.00 33.019 85.112 9066.05 9104.85 3138.87 N 1013.47 E 5997682.28 N 675117.75 E 0.000 10503.52 33.019 85.112 9069.00 9107.80 3139.03 N 1015.38 E 5997682.49 N 675119.65 E 0.000 10579.85 33.019 85.112 9133.00 9171 .80 3142.57 N 1056.83 E 5997687.00 N 675161 .00 E 0.000 10600.00 33,019 85.112 9149.90 9188.70 3143.51 N 1067.77 E 5997688.19 N 675171 .92 E 0.000 10653.52 33,019 85.112 9194.78 9233.58 3145.99 N 1096.83 E 5997691.35 N 675200.91 E 0.000 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to P1-1 8. Northings and Eastings are relative to P1-18. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from P1-18 and calculated along an Azimuth of 18.290° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 0653.52ft., The Bottom Hole Displacement is 3331.71 ft., in the Direction of 19.221° (True). 18 March, 2002 -16:40 Page 40f6 . BPXA Point Mcintyre Pad 1 Vertical Section Comment 3085.04 3118.12 3141.54 Top HRZ 3146.36 3166.60 End Dir, Start Sail @ 33.019° : 9885.74ftM 0,8551 .0OftTVD Kuparuk '-' Target - NV-18A Kuparuk, 200.00 Radius. 3169.66 3191.11 3212.56 3234.00 3255.45 3276.90 3289.13 OWC 3298.35 3299.10 OOWC 3315.47 Miluveach Target - NV-18A Miluveach 3319.79 3331.27 Total Depth: 10653.52ftMD,9194.78ftTVD 7" Casing --/ Drit/Quest 2.00.09.001 North Slope Alaska Comments Measured Depth (ft) 4494.00 4514.00 5355.05 8679,18 9885.74 10653.52 Sperry-Sun Drilling Services Proposal Report for P1(NV}-18 WPs. NV.18A Wp 07 Revised: 18 March, 2002 . BPXA Point Mcintyre Pad 1 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 4480.28 4499.97 5232.72 7595.63 8589.80 85.58 S 82.07 S 304.42 N 2631.36 N 3110.34N Sidetrack Highside @10.000/10Qft: 4494.000 MD, 4480.28ftTVD Decrease in Dir Rate @ 4.000/100ft: 4514.000 MD, 4499.97ft TVD End Dir, Start Sail @ 44.697° : 5355.05ftMD,5193.92ftTVD Begin Dir @ 4.000o/100ft: 8679.18ft MD, 7556.83ft TVD End Dir, Start Sail @ 33.019° : 9885.74ftMD,8551.00ftTVD ~ 28.79 E 28.85 E 59.96 E 287.63 E 679.97 E 9233.58 3145.99 N Total Depth: 10653.52ftMD,9194.78ftTVD 1096.83 E Formation Tops Formation Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name (ft) Deg. Deg. (ft) (ft) (ft) (ft) (ft) 4490.00 0.000 359.998 4543.44 4528.80 4490.00 76.11 S 28.99 E T3 4920.00 0.000 1.335 5007.74 4958.80 4920.00 93.19 N 40.47 E K-15/UGNU 6615.00 0.000 1.335 7354.21 6653,80 6615.00 1703.87 N 196.89 E K13JWest Sa!< 6743.00 0.000 359.998 7534.28 6781.80 6743.00 1829.92 N 209.22 E K-121 Colville 8265.00 0.000 1.335 9551.11 8303.80 8265.00 3060.06 N 515.21 E K10 8463.00 0.000 359.998 9781.62 8501.80 8463.00 3102.12 N 624.98 E Top HRZ 8551 .00 0.000 359.998 9885.74 8589.80 8551.00 3110.34N 679.97 E Kuparuk 9030.00 0.000 1.335 10457.01 9068.80 9030.00 3136.87 N 990.13 E OWC ~ 9069.00 0.000 1.335 10503.52 9107.80 9069.00 3139.03 N 1015.38 E OOWC 9133.00 0.000 359.998 10579.85 9171.80 9133.00 3142.57 N 1056.83 E Miluveach 18 March, 2002 - 16:40 Page 50f6 DrillQuest 2.00.09.001 North Slope Alaska Casing details From Measured Vertical Depth Depth (ft) (ft) 4494.00 To Measured Vertical Depth Depth (ft) (ft) 4480,28 10653.52 9233.58 Targets associated with this well path Target Name NV-18A Kuparuk NV-18A Miluveach 18 March, 2002 - 16:40 Sperry-Sun Drilling Services Proposal Report for P1 (NV)-18 WPs - NV-18A Wp 07 Revised: 18 March 2002 Casing Detail 7" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 8589.80 3110.34 N 679.97 E . Circle Mean Sea LeveVGlobal Coordinates: 8551.00 5997646.00 N 674785.00 E Geographical Coordinates: 70° 23' 57.1836" N 148° 34' 38.8233" W 9171.80 3142.57 N 1056.83 E Point Mean Sea LeveVGlobal Coordinates: 9133.00 5997687.00 N 675161.00 E Geographical Coordinates: 70° 23' 57.5002" N 148034' 27.7827" W Page 6 of 6 . BPXA Point Mcintyre Pad 1 Target Target Shape Type .-' .~ DrillQuest 2.00.09.001 P 1-18A Kick Tolerance ) Page 1 of 2 ) b KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Well : Version 6.0, December 2000 Kick Zone Parameters: 1 Open hole Size? 2 Measured Depth? 3 Vertical Depth? 4 Horizontal Length (>87 deg) ? 5 Tangent Angle Above Horizontal? 6 Min Pore Pressure Gradient? 7 Max Pore Pressure Gradient? 8 Kick Zone Temperature? Weak Point Parameters: 9 Measured Depth? 10 Vertical Depth? 11 Section Angle «87 deg) ? 12 Min Fracture Gradient 1 EMW ? 13 Max Fracture Gradient 1 EMW 14 Weak Point Temperature? Other Parameters: 15 Drill Collar 00 ? 16 Drill Collar Length? 17 Drillpipe 00 ? 18 Surface Pressure Safety Factor? 19 Mud Weight in Hole? (inch) (H) (ft) (H) ( deg) (ppg) (ppg) (deg.F) (H) (H) (deg) (ppg) (ppg) (deg.F) (inch) (H) (inch) (psi) (ppg) (bbl/ft) (bbl/ft) Annular Capacity Around BHA: Annular Capacity Around DP: At Min Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/H) (H) (bbl) (H) (bbl) At Max Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/H) (ft) (bbl) (ft) (bbl) 9885 8590 .4500 ..4482 . 12:000 13.500 . 45 .200 150 tŒ400 0.03011 0.05008 222 0.0761 2209 131.3 1248 68.1 571 0.0835 3010 196.3 2033 121.6 Units (UK/US): 3/14/2002 2:41 PM Input Error Messages: Non-Horizontal Comments: P1-18A Kick Tolerance 250 200 - :ã .D - 8 150 s:::: co - G) ~ 100 ~ Co) ~ 50 0 8.40 APPENDIX: ) Page 2 of 2 ) 3/14/2002 2:41 PM I-Ö-Min Fracture Grad -o-Max Fracture Grad I 0.-. -~'II- t ~ 8.60 8.80 9.00 Pore Pressure Gradient .0 ~ 9.20 9.40 9.80 9.60 Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Surface Pressure? (psi) Near Surface Casing 10 ? (inch) Near Surface Annular Temperature? (deg.F) Gas Gradient at Max Surface Pres: (psi/ft) Near Surface Annular Capacity: (bbl/ft) At Minimum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) At Maximum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) - 2850- ! 2800 ~ 2750 .2 2700 0 :: 2650 ~ 2600 ~ 2550 co 3: 2500 0 ;¡ 2450 ~ 2400 :E 2350 8.40 ò.... ' .","'. ,,'w. 8.60 8.80 9.00 Pore Pressure Gradient 9.20 9.40 9.80 5000. 12.347 32 0.113 0.12379 Comments: 13224 Extends to hole TO infinite 12181 Extends to hole TO infinite ti I I I -0 9.60 PU)T THIS NOTICE IN THE DOGHOUSE ) P1-18A Rig site Summary of Drilling Hazards ../ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is on P1-13 @ 60 ppm, (October 1998). ../ NORM test all retrieved well head and completion equipment. ../ All wells pass major risk criteria. P1-13 is the closest approach, with a center- center distance of 199' at the planned depth of 4,526'. ../ P1-17 is on 15' center separation, at surface. This well will require temporary shut-in during rig MIRU. Due to difficult re-start, following lengthy shut-in, this well will be brought back on line as soon as 2ES is nippled up on the P1-18 slot. ../ This well is a long string design. There will be approximately 6200' of open hole at TO. Diligence will be required in monitoring hole cleaning and condition. ../ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ../ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 psia at 100° F. CONSULT THE Pt. Mac. 1 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. Pl-18A H 205544 DATE 02/15/02 CHECK NO. 00205544 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS iOO. 00 VENDOR DISCOUNT ALASKAOILA NET 00 >~.." 02i302 CK02i302M PYJ'r1T '~OMMEt'.JTS: HANDLING INST: 100. 00 Permit to Drill =ee S/H - Sandra Stellman X4750 RE(~Ei -- MAH ~:, làt~'O/ ~\- \ 9f\- Alaska OH ¡~ (3as (~ons. (~orrJli¡SZ~t:,~¡: - - I . THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100. 00 100. 00 , . BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 205544 CONSOLIDATED COMMERCIAL ACCOUNT 56.389 ---;m-- 00205544 >t PAY ONE HUNDRED & OOíiOO************************************* US DOLLAR DATE 02/15/02 AMOUNT $100.00 To Th E' ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 r-'\ -._-..,- - \ (~6/,V1_'l.~ II' 20 5 5 ~ ~ III I: 0 ~ ~ 2 0 :l a g 5 I: 0 0 a ~ ~ ~ g II' ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BEINCLUDEDINTRANSNUTTALLETTER WELLNAMEß"" ß~dr- PI-Ie-/! CHECK 1 ST ANDARD LEITER DEVELOPMENT ~ ~~7 EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) . ANNUL~ DI~. I SAL (j¿JNO ANNULAR DISPOSAL <-.J YES ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a Dew wellbore segment of existing weD ~ Permit No, . API No. . ' Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(t), all records, data and logs acquired for' the pilot hole mu'st be clearly , differentiated in both name (name on permit plus PH) and API number (SO -70/80) from . records, data and logs acquired for wel~(n»:me on permit). Annular disposal has ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved... DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS <-.J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .súbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a cOBservatlon order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY 11 f X WELL NAMEff /te ~~ FIELD & POOL h he / ~ d INIT CLASS ~ 4!;V /-~() ï ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is we II bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . ~R .,Dj-TE 12. Permit can be issued without administrative approval.. . . . . IJI~' ;r -?~~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . , 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . , 26. BOPE press rating appropriate; test to - 4000 psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones, . , . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . APPR oo/'TE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~ :;/~7. 34. Contact name/phone for weekly progress reports [exploratory ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGIN~~~NG: UIC/Annular: COMMISSION: RI~/' TEM~~ COT, J IF;;= WGA W<k' ~~:~? j' 0 ~ ~~ f~t~2 ~ 36-~-o~ GEOLOGY APPR DATE G: \geology\templates \checklist. doc fJ¡-/fiA PROGRAM: Exp - Dev,k' Redrl~serv - Well bore seg - Ann. disposal para req- /\ GEOLAREA ý?~ UNIT# /1£ S ~ ON/OFF SHORE o;() f,!JN Y'N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N l)N Œ lAJ!A- i! ¡ÚD<bo, \. lG'>, N ~pY\!Jt¿..fll ;/'l-&>lo'l:... .. N C l O~! t C( 1'" F'Y<'''-£k d 9") f. ** t"J/.\ ~N @N @ N m<;P:: ? cf'"¿O f r..-; . f~ " ~" Y N Y N /I~111 Y N Iy] Y N ( Y N Y N ~ cw/v<Aviv d{s~<;~ ( ('<It-<Q~f¡-¡' ~">~~ G,~-+=, Comments/Instructions: ) ) Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding infonnation. information of this nature is accumulated at the end of the file under APPEN.DIX. No special "effort has been made to chronologically: . organize this category of information. ) ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 27 14:20:53 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/01/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS dC8-ðl ~ 1150 lp Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/01/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Point McIntyre MWD 1 MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22063 R. MCNEILL R. BORDES 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 3 AK-MW-22063 R. MCNEILL R. BORDES 1 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) Pl-18A 500292295301 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 27-JAN-03 MWDRUN 2 AK-MW-22063 R. MCNEILL R. BORDES 1 MWDRUN 3 AK-MW-22063 R. MCNEILL R. BORDES 1 16 12N 14E 1394 880 37.30 8.80 ) ) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 4491.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF A WHIPSTOCK - THE TOP WAS AT 4491/MD/4478/TVD AND THE BOTTOM WAS AT 4507/MD/4494ITVD. MWD RUN 1 WAS TO POSITION THE WHIPSTOCK - ONLY ROP DATA ARE PRESENTED. GAMMA RAY DATA OVER THIS INTERVAL WERE ACQUIRED DURING RUN 2. 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; PRESSURE WHILE DRILLING (PWD); AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO-DENSITY (SLD). MAD PASS DATA (POROSITY ONLY) WERE ACQUIRED OVER THE INTERVAL 10610/MD - 10545/MD (BIT DEPTHS) WHILST POOH AFTER REACHING FINAL TD. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN Pl-18A ON 16 MAY 2002. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 19 JULY 2002. 6. MWD RUNS 1 - 3 REPRESENT WELL Pl-18A WITH API#: 50-029-22953-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10641/MD/9237/TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX I FIXED HOLE SIZE) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR1S COUNT RATE. ) ) SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. AN M SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" MUD WEIGHT: 9.6 - 10.2 PPG MUD SALINITY: 1500 - 19,000 PPM CHLORIDES FORMATION WATER SALINITY: 20,000 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPX RPM FET RPS ROP NPHI NCNT PCNT PEF RHOB DRHO $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 4451.5 4476.5 4476.5 4476.5 4476.5 4476.5 4487.0 7149.5 7149.5 7149.5 7160.5 7160.5 7160.5 STOP DEPTH 10576.5 10586.5 10586.5 10586.5 10586.5 10586.5 10643.0 10535.5 10535.5 10535.5 10546.5 10546.5 10546.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 4451.5 4466.5 4475.0 4516.0 4530.0 DEPTH GR 4456.0 4471.0 4478.5 4520.5 4533.5 ) ) 4539.5 4545.0 4581.5 4587.0 4605.0 4611.0 4609.5 4616.5 4632.5 4640.5 4639.5 4649.5 4654.0 4663.5 4689.5 4699.0 4706.0 4714.0 4727.0 4733.0 4753.5 4760.5 4772.0 4779.0 4778.5 4785.0 4786.5 4792.5 4795.0 4801.0 4802.0 4807.0 4806.5 4811.0 4810.5 4817.0 4821.0 4828.5 4828.5 4835.5 4833.0 4839.5 4840.0 4845.5 4870.0 4875.5 4891.5 4897.0 4896.0 4902.0 4899.0 4904.5 4904.5 4909.5 4908.0 4913.0 4928.5 4934.0 4937.5 4943.0 4942.5 4948.0 4951.0 4956.0 4962.5 4968.0 4964.0 4969.5 4970.0 4975.0 4981.0 4985.0 4992.0 4997.5 4998.5 5004.0 5013.5 5018.5 5031.5 5035.5 5046.5 5050.5 5050.5 5055.0 5062.5 5067.0 5068.0 5072.5 5075.0 5079.0 5081.0 5085.0 5085.5 5090.0 5093.0 5100.0 5165.5 5170.5 5172.5 5178.0 5179.5 5183.5 5200.5 5206.0 5209.5 5214.5 5223.5 5228.0 5263.5 5269.5 5277.5 5282.5 5307.0 5312.0 5314.5 5319.5 5339.0 5343.5 5345.0 5349.5 5354.0 5357.5 5361.5 5365.0 5367.0 5371.0 5376.5 5380.5 5379.0 5383.0 ',- ) ) 5381.5 5385.5 5392.0 5397.5 5403.5 5409.0 5413.0 5418.5 5417.5 5422.0 5427.0 5431.5 5441.5 5446.5 5465.5 5471.5 5483.0 5489.5 5514.0 5519.5 5523.5 5529.0 5540.0 5545.5 5549.5 5553.5 5561.0 5565.0 5562.5 5567.0 5581.5 5586.5 5588.0 5592.0 5596.5 5600.0 5600.0 5604.0 5605.0 5609.0 5622.0 5625.0 5624.0 5627.5 5641.0 5646.0 5663.5 5668.5 5684.5 5690.0 5710.5 5717.0 5715.0 5721.0 5729.0 5734.0 5732.5 5737.5 5741.5 5747.0 5744.5 5750.0 5756.0 5760.5 5769.5 5774.0 5807.0 5812.0 5814.0 5817.5 5828.5 5834.0 5848.5 5853.5 5871.0 5877.0 5887.0 5893.5 5896.5 5903.5 5905.0 5909.5 5909.0 5916.0 5919.5 5925.0 5933.0 5938.0 5940.5 5945.5 5952.0 5955.5 5959.0 5964.0 5984.0 5989.0 5985.5 5990.5 6006.5 6011.5 6010.5 6015.0 6023.5 6028.0 6026.5 6031.0 6032.0 6037.0 6063.5 6070.5 6078.0 6082.5 6087.5 6091.0 6102.0 6105.5 6107.5 6112.0 6119.0 6121.5 6145.5 6150.0 6154.0 6157.5 6160.5 6164.5 6177.0 6181.5 6228.5 6233.0 ) ') 6240.0 6245.5 6245.5 6252.0 6267.5 6274.0 6331.5 6338.5 6346.5 6352.0 6354.0 6359.0 6370.5 6375.0 6375.5 6381.0 6379.5 6384.5 6398.0 6403.5 6403.5 6408.5 6418.5 6422.5 6422.5 6427.0 6430.5 6435.5 6442.0 6446.0 6477.0 6480.5 6507.0 6512.5 6521.0 6527.0 6527.0 6531.5 6536.5 6542.5 6563.0 6569.0 6577.5 6583.5 6594.0 6599.0 6617.5 6622.5 6633.5 6639.0 6672.0 6678.5 6679.0 6685.5 6699.5 6706.5 6715.5 6721.5 6744.0 6749.5 6755.5 6761.0 6778.5 6781.5 6790.0 6792.5 6829.0 6834.0 6858.5 6862.0 6873.0 6877.5 6882.5 6886.5 6888.5 6892.5 6893.0 6897.5 6916.0 6920.5 6925.5 6930.0 6946.0 6951.0 6968.0 6974.5 6976.0 6981.5 6999.5 7006.5 7004.5 7010.5 7011.0 7015.5 7028.5 7033.0 7038.5 7044.5 7057.0 7060.5 7088.0 7090.5 7111.5 7116.5 7139.0 7144.0 7184.5 7189.0 7198.5 7204.0 7212.0 7217.5 7217.5 7222.5 7245.0 7252.0 7275.0 7278.5 7290.5 7295.0 7310.5 7315.0 7330.0 7334.0 7342.0 7347.5 7364.0 7369.5 7381.5 7385.0 ) ) 7401.0 7404.5 7418.5 7423.0 7432.0 7435.0 7444.0 7447.5 7509.0 7511.0 7522.0 7525.5 7530.5 7534.5 7536.5 7541.5 7549.0 7552.5 7560.5 7564.0 7574.0 7577.5 7587.0 7591.0 7623.0 7626.0 7627.5 7631.0 7656.0 7660.0 7712.5 7715.5 7738.0 7741.0 7748.0 7752.0 7780.0 7782.5 7782.0 7785.5 7814.5 7815.5 7845.5 7848.0 7866.5 7869.5 7883.0 7885.5 7908.5 7912.0 7922.0 7926.5 7941.0 7941.5 7984.5 7984.0 8069.0 8067.0 8089.0 8088.0 8108.5 8108.0 8137.5 8137.0 8170.5 8170.0 8241.0 8240.0 8388.0 8382.0 8423.0 8419.0 8434.5 8431.5 8448.0 8447.0 8508.5 8509.0 8517.0 8516.0 8535.0 8534.5 8645.0 8643.0 8651.0 8647.5 8657.5 8654.0 8669.0 8667.5 8850.0 8851.5 8874.5 8873.5 8943.0 8943.0 9023.5 9022.0 9029.0 9026.0 9090.5 9086.5 9119.0 9116.0 9124.5 9123.5 9133.5 9133.5 9152.0 9152.5 9156.0 9155.5 9404.0 9406.0 9431.0 9432.0 9743.5 9746.0 9752.0 9754.0 9755.0 9756.5 9772.5 9773.0 9783.5 9784.0 9788.5 9788.5 9795.0 9796.0 ) ) 9797.5 9798.0 9800.0 9800.5 9801.5 9802.0 9803.0 9803.0 9815.5 9815.5 9817.0 9817.0 9820.0 9819.5 9823.0 9823.0 9826.5 9826.5 9831.0 9831.5 9834.0 9834.5 9835.5 9836.0 9839.0 9839.5 9844.0 9844.0 9858.5 9858.5 9861.5 9861.5 9866.0 9866.5 9871.0 9870.0 9882.5 9882.5 9890.0 9890.0 9892.0 9892.5 9898.0 9897.5 9902.0 9902.0 9910.5 9910.5 9916.0 9916.0 9919.5 9920.0 9926.5 9927.0 9928.5 9929.0 9932.5 9933.0 9936.5 9937.0 9938.0 9938.5 9949.0 9949.5 9954.5 9954.0 9971.0 9970.5 9977.0 9976.5 9986.5 9986.0 9990.0 9989.5 9998.0 9998.0 10007.5 10007.5 10021.5 10020.5 10025.5 10025.0 10032.0 10031.5 10042.0 10041.5 10047.0 10046.5 10052.5 10053.5 10056.5 10056.5 10068.5 10068.5 10082.5 10083.0 10095.0 10093.5 10105.5 10104.5 10135.0 10134.0 10149.5 10148.0 10168.5 10167.5 10178.0 10176.0 10206.0 10205.0 10228.5 10227.5 10244.0 10243.0 10309.0 10309.0 10317.5 10316.5 10329.0 10327.5 10333.5 10331.0 10354.5 10354.0 10366.5 10365.0 10414.5 10411.5 10418.0 10415.5 ) ) 10430.5 10460.5 10465.5 10477.0 10488.5 10643.0 $ 10428.5 10458.5 10463.5 10475.0 10486.5 10641.0 # MERGED DATA PBU TOOL MWD MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 1 4491.0 2 4521.5 3 7261.0 MERGE BASE 4521.5 7261.0 10641.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4451.5 10643 7547.25 12384 4451.5 10643 ROP MWD FT/H 0.03 416.54 146.886 12313 4487 10643 GR MWD API 7.96 382.84 85.9673 12251 4451.5 10576.5 RPX MWD OHMM 0.4 1853.05 3.8018 12221 4476.5 10586.5 RPS MWD OHMM 0.4 1853.38 4.00337 12221 4476.5 10586.5 RPM MWD OHMM 0.51 2000 4.97507 12221 4476.5 10586.5 RPD MWD OHMM 0.66 2000 6.86387 12221 4476.5 10586.5 FET MWD HOUR 0.1909 25.9248 1.18101 12221 4476.5 10586.5 NPHI MWD PU-S 13.47 80.82 37.1077 6773 7149.5 10535.5 FCNT MWD CNTS 470 982 603.428 6773 7149.5 10535.5 NCNT MWD CNTS 2290 3917 2823.06 6773 7149.5 10535.5 RHOB MWD G/CM 2.152 3.14 2.451 6773 7160.5 10546.5 DRHO MWD G/CM -0.116 0.549 0.0505724 6773 7160.5 10546.5 PEF MWD BARN 1.81 9.9 3.71236 6773 7160.5 10546.5 ) ) First Reading For Entire File......... .4451.5 Last Reading For Entire File.......... .10643 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR RAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10437.0 10437.0 10437.0 10448.5 10448.5 10448.5 10478.5 10545.0 STOP DEPTH 10502.5 10502.5 10502.5 10513.0 10513.0 10513.0 10544.0 10611.0 # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 7154.5 MERGE BASE 10641.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 NPHI MAD PU-S 4 1 68 12 4 FCNT MAD CNTS 4 1 68 16 5 NCNT MAD CNTS 4 1 68 20 6 RHOB MAD G/CM 4 1 68 24 7 DRHO MAD G/CM 4 1 68 28 8 PEF MAD BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10437 10611 10524 349 10437 10611 RAT MAD FT/H 51.38 130.72 109.932 133 10545 10611 GR MAD API 19.95 98.24 41.2845 132 10478.5 10544 NPHI MAD PU-S 20.62 27.86 23.8323 132 10437 10502.5 FCNT MAD CNTS 641.11 815.53 733.184 132 10437 10502.5 NCNT MAD CNTS 3024 3376 3185.17 132 10437 10502.5 RHOB MAD G/CM 2.23 2.58 2.35669 130 10448.5 10513 DRHO MAD G/CM -0.02 0.11 0.0569231 130 10448.5 10513 PEF MAD BARN 2.19 5.78 3.65285 130 10448.5 10513 First Reading For Entire File......... .10437 Last Reading For Entire File.......... .10611 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 4491.0 STOP DEPTH 4521.5 ') # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absen t value. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 25-APR-02 Insite 66.37 Memory 4522.0 4491.0 4522.0 .0 .0 TOOL NUMBER 155789 8.750 4491.0 LSND 9.40 60.0 9.4 1500 5.0 .000 .000 .000 .000 .0 75.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 ) Name Service Unit DEPT FT ROP MWDOI0 FT/H Min 4491 0.03 Max 4521.5 7.92 Mean Nsam 4506.25 62 4.34306 62 First Reading For Entire File......... .4491 Last Reading For Entire File.......... .4521.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 4 ) First Reading 4491 4491 Last Reading 4521.5 4521.5 header data for each bit run in separate files. 2 .5000 START DEPTH 4456.0 4480.0 4480.0 4480.0 4480.0 4480.0 4522.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7195.0 7205.0 7205.0 7205.0 7205.0 7205.0 7261.0 27-APR-02 Insite 66.37 Memory 7261.0 4522.0 7261.0 10.4 46.5 ) # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER 155789 134760 8.750 4491.0 LSND 9.60 55.0 9.2 1800 5.4 2.000 1.560 2.400 3.500 90.0 117.0 77.0 77.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4456 7261 5858.5 5611 4456 7261 ROP MWD020 FT/H 0.1 416.54 171.456 5479 4522 7261 GR MWD020 API 7.96 138.34 69.2838 5479 4456 7195 RPX MWD020 OHMM 0.4 1853.05 2.98382 5451 4480 7205 ) ') RPS MWD020 OHMM 0.4 1853.38 2.99279 5451 4480 7205 RPM MWD020 OHMM 0.51 2000 5.19044 5451 4480 7205 RPD MWD020 OHMM 0.66 2000 8.77025 5451 4480 7205 FET MWD020 HOUR 0.2031 3.7 0.741659 5451 4480 7205 First Reading For Entire File......... .4456 Last Reading For Entire File.......... .7261 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR RPX FET RPD RPS RPM ROP $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 7154.5 7154.5 7154.5 7165.5 7165.5 7165.5 7195.5 7205.5 7205.5 7205.5 7205.5 7205.5 7261.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): STOP DEPTH 10533.5 10533.5 10533.5 10544.5 10544.5 10544.5 10574.5 10584.5 10584.5 10584.5 10584.5 10584.5 10641.0 01-MAY-02 Insite 66.37 Memory 10641.0 7261.0 ') BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 10641.0 29.4 48.3 TOOL NUMBER 155789 134760 119007 151842 8.750 4491.0 GEM 10.20 47.0 8.9 17000 2.5 .725 .360 .220 .380 80.0 169.0 80.0 80.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 ) ) NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7154.5 10641 8897.75 6974 7154.5 10641 ROP MWD030 FT/H 0.26 389.23 128.173 6760 7261.5 10641 GR MWD030 API 26.2 382.84 99.4544 6759 7195.5 10574.5 RPX MWD030 OHMM 0.87 71.17 4.49889 6759 7205.5 10584.5 RPS MWD030 OHMM 0.87 115.35 4.84903 6759 7205.5 10584.5 RPM MWD030 OHMM 0.85 74.21 4.83658 6759 7205.5 10584.5 RPD MWD030 OHMM 0.88 77.11 5.30499 6759 7205.5 10584.5 FET MWD030 HOUR 0.1909 25.9248 1.53843 6759 7205.5 10584.5 NPHI MWD030 PU-S 13.47 80.82 37.1099 6759 7154.5 10533.5 FCNT MWD030 CNTS 470 982 603.417 6759 7154.5 10533.5 NCNT MWD030 CNTS 2290 3917 2822.79 6759 7154.5 10533.5 RHOB MWD030 G/CM 2.152 3.14 2.45136 6759 7165.5 10544.5 DRHO MWD030 G/CM -0.116 0.549 0.0506062 6759 7165.5 10544.5 PEF MWD030 BARN 1.81 9.9 3.71395 6759 7165.5 10544.5 First Reading For Entire File......... .7154.5 Last Reading For Entire File.......... .10641 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI 6 header data for each pass of each run in separate files. .5000 3 1 START DEPTH 10435.0 10435.0 10435.0 STOP DEPTH 10500.5 10500.5 10500.5 ) ) PEF 10446.5 10511.0 DRHO 10446.5 10511.0 RHOB 10446.5 10511.0 GR 10476.5 10542.0 RAT 10543.0 10609.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined 02-MAY-02 Insite 66.37 Memory 10610.0 10545.0 10610.0 29.4 48.3 TOOL NUMBER 155789 134760 119007 151842 8.750 4491.0 GEM 10.20 47.0 8.9 17000 2.5 .725 .360 .220 .380 80.0 169.0 80.0 80.0 ) ) Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . .. Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD031 FT/H 4 1 68 4 2 GR MAD031 API 4 1 68 8 3 NPHI MAD031 PU-S 4 1 68 12 4 FCNT MAD031 CNTS 4 1 68 16 5 NCNT MAD031 CNTS 4 1 68 20 6 RHOB MAD031 G/CM 4 1 68 24 7 DRHO MAD031 G/CM 4 1 68 28 8 PEF MAD031 BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10435 10609 10522 349 10435 10609 RAT MAD031 FT/H 51.38 130.72 109.932 133 10543 10609 GR MAD031 API 19.95 98.24 41.2845 132 10476.5 10542 NPHI MAD031 PU-S 20.62 27.86 23.8323 132 10435 10500.5 FCNT MAD031 CNTS 641.11 815.53 733.184 132 10435 10500.5 NCNT MAD031 CNTS 3024 3376 3185.17 132 10435 10500.5 RHOB MAD031 G/CM 2.23 2.58 2.35669 130 10446.5 10511 DRHO MAD031 G/CM -0.02 0.11 0.0569231 130 10446.5 10511 PEF MAD031 BARN 2.19 5.78 3.65285 130 10446.5 10511 First Reading For Entire File......... .10435 Last Reading For Entire File.......... .10609 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/01/27 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03 101/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/01/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services ) ") Physical EOF Physical EOF End Of LIS File
