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202-030
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250602 (IGB 25-001) Well API #PTD #Log Date Log Company Log Type Format AOGCC E-Set# KTU 43-6XRD2 50133203280200 205117 07/14/2014 POLLARD CBL PDF MPU C-15A 50029213580100 216070 07/06/2016 HALLIBURTON RCBL PDF LAS PPTX PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR PDF TIF PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT PCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL PDF TIF Please include current contact information if different from above. T40515 T40516 T40517 T40518 T40519 T40520 T40521 T40522 PDFPBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR TIF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.03 08:26:36 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-111 Conductor Top Job Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-030 50-029-23069-00-00 7605 Conductor Surface Intermediate Production Liner 7198 77 2894 7565 7505 20" 9-5/8" 7" 7100 30 - 107 28 - 2922 24 - 7589 30 - 107 28 - 2631 24 - 7183 None 470 3090 5410 None 1490 5750 7240 4546 - 7078 4-1/2" 12.6# x 3-1/2" 9.2# L80 22 - 6838 4240 - 6680 Structural 4-1/2" Baker Premier Packer 6780, 6388 4319, 6780 4015, 6388 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Borealis Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239 22 - 6445 Conductor x Surface Casing annulus at Surface Mix & Pour 63-gallons of 13-ppg FineCem into Conductor. 3632 2279 350 150 2028 996 324-467 13b. Pools active after work:Borealis Oil Pool 4-1/2" Baker S3 Packer 4319, 4015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 3:17 pm, Oct 14, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.10.14 15:07:36 - 08'00' Torin Roschinger (4662) RBDMS JSB 101724 DSR-10/14/24WCB 2-10-2025 ACTIVITY DATE SUMMARY 9/11/2024 T/I/O = SSV/0/0. Temp = SI. Prep conductor for cement top job (SC Leak). Cleaned Blue Goo (RG2401) from conductor with hot water and steam. Wash and vac fluid to ~ 84" from top of conductor. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:00 9/14/2024 T/I/O = SSV/0/0. Temp = SI°. Top off conductor with cement (SC leak). Mixed and poured ~63 gal of 13 ppg FineCem cement into conductor. Cement top at flutes. SV WV, SSV = C, MV = O. IA, OA = OTG. 12:00 9/15/2024 T/I/O = SI/10/0+. Temp = SI. Evaluate Cement in Conductor ( SC Leak). Non Op. No bubbling detected. Cement curing good, hardened up. Cement ~ .5" from bottom of flutes & 4.5" from top of flutes @ 2:00, 4:00, 6:00, 8:00 positions & ~ 1" from bottom of flutes & 5" from top of flutes @ 10:00 & 12:00 positions. Door propped open and heater installed. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 9/26/2024 T/I/O = SSV/10/0+. Temp = SI. WHPs (eval SC leak). Non Op. 6" of rain water in cellar 360° around conductor. No fluid in conductor. Cement cured. Cement is ~ .5" from bottom of flutes & 4.5" from top of flutes @ 2:00, 4:00, 6:00, 8:00 positions & ~ 1" from bottom of flutes & 5" from top of flutes @ 10:00 & 12:00 positions. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 9/27/2024 T/I/O = SSV/10/0+. Temp = SI. WHPs (eval SC leak). Non Op. 6" of rain water in cellar 360° around conductor. No fluid present in conductor. Cement cured. Cement is ~4" from top of conductor all the way around. No bubbling observed inside or outside of conductor. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:30 9/30/2024 T/I/O = SSV/10/0+. Temp = SI. WHPs (eval SC leak). Non Op. Water in cellar 360° around conductor, deepest at 8:00 position 5" deep, appears to be receding.. No fluid present in conductor. Cement cured. Cement is ~4" from top of conductor all the way around. No bubbling observed inside or outside of conductor. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 10/1/2024 T/I/O = SSV/10/0+. Temp = SI. WHPs (Eval SC leak). Non Op. No fluid present in conductor, 0% LELs 1" & 1' above flutes. Cement cured. No bubbling observed in cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:45 10/4/2024 L-111i POI PWI Post conducted top job - Under Eval to monitor well house cellar fluids 10/5/2024 Well is SI due to surface casing leak. Notified DHD. Spill into cellar has been called in. 10/5/2024 UWP - SRT (H2336) Vac'd Out Well House Cellar Post Surface Casing Leak. Daily Report of Well Operations PBU L-111 No bubbling observed in cellar. () No fluid in conductor. Cement cured. Prep conductor for cement top job (SC Leak). Top off conductor with cement (SC leak) Evaluate Cement in Conductor ( SC Leak). Non Op. No bubbling detected. Cement curing good, hardened up CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Surface casing leak Date:Tuesday, October 8, 2024 8:13:43 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 8, 2024 8:12 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Surface casing leak Mr. Wallace, Injector L-111 (PTD #2020300) was put on produced water injection on 10/04. Liquid was observed in the conductor on 10/05 and the well was shut in. The well is now classified as NOT OPERABLE and will remain shut in until casing integrity is resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, September 23, 2024 10:59 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-111 (PTD #2020300) Cemented Surface Casing Leak / Evaluate TxIA Mr. Wallace, Injector L-111 (PTD #2020300) surface casing leak was cemented with a conductor top job on 09/14. Additionally, an online AOGCC witnessed MIT-IA passed on 05/21/24. The well is now classified as UNDER EVALUATION and can be put on water injection only for up to 60 days to evaluate possible TxIA with the tubing patch out of the hole and to determine if the surface casing leak has been resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, June 25, 2024 9:44 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Surface Casing Leak Mr. Wallace, Injector L-111 (PTD #2020300) is currently Under Evaluation to monitor for TxIA communication with a tubing patch out of hole. The well was placed on Produced Water Injection on 05/19/24. On 06/25/24 a surface casing leak was identified, and the well was shut-in and freeze protected. It will now be classified as NOT OPERABLE until the surface casing leak is repaired. Attached is a TIO plot from the Under Evaluation period. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, May 17, 2024 12:38 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-111 (PTD #2020300) AOGCC approved 60-days of Injection Mr. Wallace, I could not find records that I notified you when L-111 (PTD #2020300) was made Not Operable in April of 2023. The well is not due for its scheduled 4-year MIT-IA until 09/02/24. To keep you in the loop, the well is now classified as UNDER EVALUATION for up to 60-days of water only injection per your approval in the attached email. A MIT-T passed to 2,423 psi on 05/14 and an AOGCC witnessed MIT-IA will be performed when the well is thermally stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, April 12, 2023 4:03 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Patch out of Hole All, WAG Injector L-111 (PTD #2020300) requires a tubing patch to be on miscible gas injection. The patch was pulled on 04/03/23 during water flood regulator work. The well will now be classified as NOT OPERABLE until the patch is reinstalled. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: AK, D&C Well Integrity Coordinator Sent: Friday, March 8, 2013 9:18 PM To: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL@BP.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, D&C Wireline Operations Team Lead <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Oshiro, Joleen <JOLEEN.OSHIRO@bp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; Weiss, Troy D <Troy.Weiss@bp.com> Cc: AK, D&C DHD Well Integrity Engineer (AKD&CDHDWellIntegri@bp.com) <AKD&CDHDWellIntegri@bp.com>; 'Ryan P Holt (Ryan.Holt@bp.com)' <Ryan.Holt@bp.com>; Arend, Jon <Jon.Arend@bp.com>; Oxner, Gary <Gary.Oxner@bp.com> Subject: UNDER EVALUATION: Injector L-111 (PTD #2020300) Ready for Miscible Gas Injection All, Injector L-111 (PTD #2020300) is currently operating under Administrative Approval AIO 24B.002 for TxIA communication when the well was on miscible gas injection. A tubing patch was set and a subsequent MIT-IA to 4070 psi passed on 07/08/2012. We have permission from the AOGCC to place the well on miscible gas injection for 30 days in order to evaluate the TxIA repair. The well is reclassified as Under Evaluation, and will be placed on a 28-day clock. Miscible gas injection can begin. Plan forward: Well Integrity: Monitor pressure response while well is on miscible gas injection Well Integrity Coordinator: Apply to cancel Administrative Approval AIO 24B.002 if pressure response during 30 day monitoring period is acceptable Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Office: 907.659.5738 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector L-111 (PTD #2020300) Cemented Surface Casing Leak / Evaluate TxIA Date:Monday, September 23, 2024 11:05:37 AM Attachments:image001.png EXTERNAL RE L-111 (PTD# 202-030) Return to Produced Water Injection and Evaluate for TxIA Communication.msg From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 23, 2024 10:59 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-111 (PTD #2020300) Cemented Surface Casing Leak / Evaluate TxIA Mr. Wallace, Injector L-111 (PTD #2020300) surface casing leak was cemented with a conductor top job on 09/14. Additionally, an online AOGCC witnessed MIT-IA passed on 05/21/24. The well is now classified as UNDER EVALUATION and can be put on water injection only for up to 60 days to evaluate possible TxIA with the tubing patch out of the hole and to determine if the surface casing leak has been resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, June 25, 2024 9:44 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Surface Casing Leak Mr. Wallace, Injector L-111 (PTD #2020300) is currently Under Evaluation to monitor for TxIA communication with a tubing patch out of hole. The well was placed on Produced Water Injection on 05/19/24. On 06/25/24 a surface casing leak was identified, and the well was shut-in and freeze protected. It will now be classified as NOT OPERABLE until the surface casing leak is repaired. Attached is a TIO plot from the Under Evaluation period. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, May 17, 2024 12:38 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-111 (PTD #2020300) AOGCC approved 60-days of Injection Mr. Wallace, I could not find records that I notified you when L-111 (PTD #2020300) was made Not Operable in April of 2023. The well is not due for its scheduled 4-year MIT-IA until 09/02/24. To keep you in the loop, the well is now classified as UNDER EVALUATION for up to 60-days of water only injection per your approval in the attached email. A MIT-T passed to 2,423 psi on 05/14 and an AOGCC witnessed MIT-IA will be performed when the well is thermally stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, April 12, 2023 4:03 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Patch out of Hole All, WAG Injector L-111 (PTD #2020300) requires a tubing patch to be on miscible gas injection. The patch was pulled on 04/03/23 during water flood regulator work. The well will now be classified as NOT OPERABLE until the patch is reinstalled. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: AK, D&C Well Integrity Coordinator Sent: Friday, March 8, 2013 9:18 PM To: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL@BP.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, D&C Wireline Operations Team Lead <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Oshiro, Joleen <JOLEEN.OSHIRO@bp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; Weiss, Troy D <Troy.Weiss@bp.com> Cc: AK, D&C DHD Well Integrity Engineer (AKD&CDHDWellIntegri@bp.com) <AKD&CDHDWellIntegri@bp.com>; 'Ryan P Holt (Ryan.Holt@bp.com)' <Ryan.Holt@bp.com>; Arend, Jon <Jon.Arend@bp.com>; Oxner, Gary <Gary.Oxner@bp.com> Subject: UNDER EVALUATION: Injector L-111 (PTD #2020300) Ready for Miscible Gas Injection All, Injector L-111 (PTD #2020300) is currently operating under Administrative Approval AIO 24B.002 for TxIA communication when the well was on miscible gas injection. A tubing patch was set and a subsequent MIT-IA to 4070 psi passed on 07/08/2012. We have permission from the AOGCC to place the well on miscible gas injection for 30 days in order to evaluate the TxIA repair. The well is reclassified as Under Evaluation, and will be placed on a 28-day clock. Miscible gas injection can begin. Plan forward: Well Integrity: Monitor pressure response while well is on miscible gas injection Well Integrity Coordinator: Apply to cancel Administrative Approval AIO 24B.002 if pressure response during 30 day monitoring period is acceptable Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Office: 907.659.5738 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from tyson.shriver@hilcorp.com. Learn why this is important CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:Tyson Shriver; Rixse, Melvin G (OGC) Cc:Oliver Sternicki; PB Wells Integrity Subject:[EXTERNAL] RE: L-111 (PTD# 202-030) Return to Produced Water Injection and Evaluate for TxIA Communication Date:Monday, May 6, 2024 3:10:18 PM Tyson, A 60 days water only injection for monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent: Monday, May 6, 2024 1:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: L-111 (PTD# 202-030) Return to Produced Water Injection and Evaluate for TxIA Communication Mr. Wallace, Well L-111 (PTD# 202-030) is a Kuparuk Borealis WAG injector that is currently classified as Not Operable. The well operated under Administrative Approval AIO 24B.002 for TxIA communication when the well was on MI gas injection, which allowed for water injection only. The AA was active from September 2008 to June 2013 when a tubing patch was set over a possible leak at GLM #3 and the AA was canceled. L-111 continued WAG injection up until April 2023 when the tubing patch was pulled for downhole wellwork. Hilcorp would like to place the well back on water injection as follows: 1. Pull waterflood regulator valves from St #1 & 2. Replace with dummy valves. 2. Perform an MIT-T to 2,500 psi. 3. Pull tubing tail plug and drift to TD. 4. Reclassify well to “Under Eval” and return well to water injection (Kuparuk Borealis Oil Pool). 5. Perform AOGCC online MIT-IA. 6. Monitor and manage IA re-pressurization while Under Eval for up to 60 days. A 60-day under evaluation period is being requested to monitor the well over a longer sustained injection timeframe. Any early IA re-pressurization may be due to thermal expansion and not due to communication of Tubing x Inner Annulus while on produced water injection. By the end of the 60- day under evaluation period, Hilcorp will 1) apply for an AA for PWI only or 2) re-set a patch over GLM #3. Please let me know if you agree with this plan forward as well as any additional documentation that would be required prior to reclassifying the well “Under Eval” and placing on produced water injection. Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L-111 Conductor Top Job Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-030 50-029-23069-00-00 CO 471 ADL 0028239 7605 Conductor Surface Intermediate Production Liner 7198 77 2894 7565 6826 20" 9-5/8" 7" 6433 30 - 107 28 - 2922 24 - 7589 1500 30 - 107 28 - 2631 24 - 7183 None 470 3090 5410 6826 1490 5750 7240 4546 - 7078 4-1/2" 12.6# x 3-1/2" 9.2# L80 22 - 6838 4240 - 6680 Structural 4-1/2" Baker Premier Packer 4-1/2" Baker S3 Packer 4319, 4015 6780, 6388 Date: Torin Roschinger Area Operations Manager Tyson Shriver Tyson.Shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 8/28/2024 Current Pools: BOREALIS OIL Proposed Pools: BOREALIS OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:40 pm, Aug 13, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.13 11:07:34 - 08'00' Torin Roschinger (4662) 324-467 MGR30AUG24 10-404 DSR-8/21/24SFD 8/14/2024 CDW 08/30/2024 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.03 16:39:32 -08'00'09/03/24 RBDMS JSB 090524 Conductor Top Job Well: L-111 PTD: 202-030 API: 50-029-23069-00 Well Name:L-111 Permit to Drill:202-030 Current Status:Not Operable, WAG API Number:50-029-23069-00 Estimated Start Date:August 2024 Estimated Duration:1day(s) Regulatory Contact:Abbie Barker Revision:0 First CallEngineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Aras Worthington (907) 564-4763 (O)(907) 440-7692 (M) Current Bottom Hole Pressure:2,993 psi @ 6,600’ TVDss 8.72 ppg | PPFG Max Anticipated Surface Pressure:2,333 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:400 psi 12/23/2023 Min ID:2.813” @ 2,266’ MD X-Nipple Max Angle:40 deg @ 1,595’ MD Brief Well Summary: L-111 is a Not Operable Kuparuk WAG injector with a surface casing (SC) leak. The well developed an SC leak in June 2024 when bubbling was observed in the conductor x SC annulus while on produced water injection (PWI). A leak-depth- determination indicated a SC leak at ~25”. When the SC leak developed, L-111 was 46 days into a 60-day monitoring period for IA repressurization. A patch previously set over GLM #3 in 2011 to remedy TxIA communication while on MI had been pulled during an April 2023 intervention. Since there is no immediate need to place L-111 on MI injection, a 60-day monitoring period with the well on PWI only was granted by the AOGCC. After the conductor x SC leak is repaired, the well will be placed Under-Evaluation for the remaining 14-days of the 60-day monitoring period. Once the monitoring period is complete, Hilcorp will request an AA for PWI only or re-set a tubing patch. Current Status: The well is currently classified as “Not Operable” due to the SC leak. Objective: Execute conductor top-job. Well Integrity: >07/02/2024: Leak-Depth-Determination identified SC leak at 25” >06/24/2024: OA integrity test failed. Fluid returns to surface via the SC x Conductor annulus >06/22/2024: Evaluate bubbling in the conductor, 0% LEL 1” and 1’ above conductor. Well shut in. >05/21/2024: AOGCC MIT-IA PASSED to 2,439 psi Procedural Steps: DHD 1. Clean out conductor x SC annulus to top of cement with steam. 2. Top job the conductor x SC annulus with cement. Operations/DHD 1. POI well Under-Evaluation on PWI service with cellar observations every tour for remaining 14-days of the 60-day monitoring period. 2. If SC leak is repaired (no bubbling in the conductor or cellar) re-classify well as Operable. a. Hilcorp will apply for an AA for PWI only or re-set a tubing patch over GLM #3 per previous communications made to AOGCC. Attachments x Current Wellbore Schematic x AOGCC Communication for 60-day Under-Evaluation Monitoring Preiod x Sundry Change Form bubbling was observed The well is currently classified as “Not Operable” due to the SC leak. Once the monitoring period is complete, Hilcorp will request an AA for PWI only or re-set a tubing patch. remedy TxIA communication Conductor Top Job Well: L-111 PTD: 202-030 API: 50-029-23069-00 Current Wellbore Schematic: Conductor Top Job Well: L-111 PTD: 202-030 API: 50-029-23069-00 AOGCC Communication for 60-day Under-Evaluation Monitoring Preiod: Tyson, A 60 days water only injecƟon for monitoring and diagnosƟcs is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7 th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:Tyson Shriver <Tyson.Shriver@hilcorp.com> Sent:Monday, May 6, 2024 1:08 PM To:Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc:Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject:L-111 (PTD# 202-030) Return to Produced Water Injection and Evaluate for TxIA Communication Mr. Wallace, Well L-111 (PTD# 202-030) is a Kuparuk Borealis WAG injector that is currently classiĮed as Not Operable. The well operated under AdministraƟve Approval AIO 24B.002 for TxIA communicaƟon when the well was on MI gas injecƟon, which allowed for water injecƟon only. The AA was acƟve from September 2008 to June 2013 when a tubing patch was set over a possible leak at GLM #3 and the AA was canceled. L-111 conƟnued WAG injecƟon up unƟl April 2023 when the tubing patch was pulled for downhole wellwork. Hilcorp would like to place the well back on water injecƟon as follows: 1. Pull waterŇood regulator valves from St #1 & 2. Replace with dummy valves. 2. Perform an MIT-T to 2,500 psi. 3. Pull tubing tail plug and dri Ō to TD. 4. Reclassify well to “Under Eval” and return well to water injecƟon (Kuparuk Borealis Oil Pool). 5. Perform AOGCC online MIT-IA. 6. Monitor and manage IA re-pressurizaƟon while Under Eval for up to 60 days. A 60-day under evaluaƟon period is being requested to monitor the well over a longer sustained injec Ɵon Ɵmeframe. Any early IA re-pressurizaƟon may be due to thermal expansion and not due to communicaƟon of Tubing x Inner Annulus while on produced water injecƟon. By the end of the 60-day under evaluaƟon period, Hilcorp will 1) apply for an AA for PWI only or 2) re-set a patch over GLM #3. Iibϡ (ƄťôŘIJÍīϙŜôIJîôŘϟϙ"iϙbiϙĺŕôIJϙīĖIJħŜϙĺŘϙÍťťÍèēıôIJťŜϙċŘĺıϙbXbi®bϙ ŜôIJîôŘŜϟ You don't often get email from tyson.shriver@hilcorp.com.Learn why this is important CAUTION:This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Conductor Top Job Well: L-111 PTD: 202-030 API: 50-029-23069-00 Please let me know if you agree with this plan forward as well as any addi Ɵonal documentaƟon that would be required prior to reclassifying the well “Under Eval” and placing on produced water injec Ɵon. Tyson Shriver Hilcorp Alaska PBW GC2 OE (L, V, W, Z) o: 907-564-4542 c: 406-690-6385 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Conductor Top Job Well: L-111 PTD: 202-030 API: 50-029-23069-00 Sundry Change Form: Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-111 PRUDHOE BAY UN BORE L-111 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/01/2024 L-111 50-029-23069-00-00 202-030-0 W SPT 4015 2020300 1500 732 734 755 734 374 647 625 607 OTHER P Adam Earl 5/21/2024 MIT-IA tested as per email from Chris Wallace -Under Evaluation 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-111 Inspection Date: Tubing OA Packer Depth 45 2501 2451 2439IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240522080735 BBL Pumped:1.6 BBL Returned:1 Monday, July 1, 2024 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Surface Casing Leak Date:Tuesday, June 25, 2024 9:48:52 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, June 25, 2024 9:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Surface Casing Leak Mr. Wallace, Injector L-111 (PTD #2020300) is currently Under Evaluation to monitor for TxIA communication with a tubing patch out of hole. The well was placed on Produced Water Injection on 05/19/24. On 06/25/24 a surface casing leak was identified, and the well was shut-in and freeze protected. It will now be classified as NOT OPERABLE until the surface casing leak is repaired. Attached is a TIO plot from the Under Evaluation period. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, May 17, 2024 12:38 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-111 (PTD #2020300) AOGCC approved 60-days of Injection Mr. Wallace, I could not find records that I notified you when L-111 (PTD #2020300) was made Not Operable in April of 2023. The well is not due for its scheduled 4-year MIT-IA until 09/02/24. To keep you in the loop, the well is now classified as UNDER EVALUATION for up to 60-days of water only injection per your approval in the attached email. A MIT-T passed to 2,423 psi on 05/14 and an AOGCC witnessed MIT-IA will be performed when the well is thermally stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, April 12, 2023 4:03 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: WAG Injector L-111 (PTD #2020300) Patch out of Hole All, WAG Injector L-111 (PTD #2020300) requires a tubing patch to be on miscible gas injection. The patch was pulled on 04/03/23 during water flood regulator work. The well will now be classified as NOT OPERABLE until the patch is reinstalled. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-111 Pull Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-030 50-029-23069-00-00 7605 Conductor Surface Intermediate Production Liner 7198 77 2894 7565 6826 20" 9-5/8" 7" 6433 30 - 107 28 - 2922 24 - 7589 30 - 107 28 - 2631 24 - 7183 None 470 3090 5410 6826 1490 5750 7240 4546 - 7078 4-1/2" 12.6# x 3-1/2" 9.2# L80 22 - 6838 4240 - 6680 Structural 4-1/2" Baker Premier Packer 4319, 4015 4319, 6780 4015, 6388 Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, BOREALIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239 22 - 6443 N/A N/A Well not Online 1176 0 100 1600 100 N/A 13b. Pools active after work:BOREALIS OIL 4-1/2" Baker S3 Packer 6780, 6388 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 3:11 pm, Apr 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.04.21 14:41:51 -08'00' Torin Roschinger (4662) DSR-4/26/23 RBDMS JSB 042523 WCB 11-28-2023 ACTIVITY DATE SUMMARY 4/2/2023 ***WELL S/I ON ARRIVAL*** RAN 4-1/2'' BLB, 3.805'' G-RING TO TOP PATCH @ 4,189' MD (lrs pumped 40bbls *180 hot @ 1 bpm) RAN 20' x 3.70" DUMMY WHIPSTOCK, DRIFT FREELY & S/D ON PATCH @ 4,181' SLM JAR ON 4-1/2" KB PATCH @ 4,180' SLM, FOR 1 HOUR ***WSTR CONT 4-3-23*** 4/2/2023 T/I/O=700/70/45 Assist Slickline ( WFRs ) Pump 40 bbls 180* diesel down tbg for brush & flush. *** Job continued to 04-03-23*** 4/3/2023 *** job continued from 04-02-23*** Pump 100 bbls 180* diesel down tbg to assist slickline. FWHPs=700/70/40 4/3/2023 ***WSR CONT FROM 4-2-23*** PUMPED 100BBLS HOT(diesel) PULLED 25' 4-1/2'' KB STRADDLE PATCH FROM 4189'MD ***WELL LEFT S/I ON DEPARTURE*** (JOB NOT COMPLETE) 4/4/2023 T/I/O=900/70/50 Assist Slickline ( WFR's ) Pump 66 bbls 180* diesel for brush & flush. Pump 45 bbls diesel for Injectivity test:1540 psi @ 1 bpm, 1620 psi @ 2 bpm, 1720 psi @ 3 bpm. PT tbg to 2500 psi with 0.5 bbls DSL. 1st 15 lost 140, 2nd 15 min lost 37 psi. Good test bleed tbg for draw down test good ***job continued to 04-05- 23*** 4/4/2023 ***WELL S/I ON ARRIVAL*** RAN TEL & SAMPLE BAILER LOC TT @ 6832'SLM/6838'MD (+6' correction) S/D W/ SAMPLE BAILER @ 7028'SLM/7034'MD (44' of btm interval covered) BRUSHED 4-1/2'' & 3-1/2'' TUBING (pumped 66bbl) PERFORMED INJECTIVITY TESTS (1BPM= 1540PSI, 2BPM= 1620PSI, 3BPM= 1720PSI) SET 2.81'' RMX BODY (34'' lih) X-NIP @ 6823'SLM/6826'MD SET DUMMY PRONG IN RMX PLUG BODY @ 6,825' SLM / 6,826' MD (TBG PSI= 890) LRS PERFORMED MIT-T 2500#, (PASS LOSS 140/37) / BEGIN NEGATIVE TEST (failed) PULLED ST#1 RKP-PRONG FROM 4,478' MD (TBG PSI= 540) PULLED ST#1 RKED- DMY VLV FROM 4,478' MD (TBG PSI= 526) ***WSR CONT ON 4-5-23*** 4/5/2023 *** job continued from 04-04-23*** Pumped 83 bbls DSL down TBG to assist SL with valve C/O and inj. testing. Daily Report of Well Operations PBU L-111 () PULLED 25' 4-1/2'' KB STRADDLE PATCH FROM 4189'MD ) SET 2.81'' RMX BODY (34'' lih) X-NIP @ 6823'SLM/6826'MD JAR ON 4-1/2" KB PATCH @ 4,180' SLM, FOR 1 HOUR Daily Report of Well Operations PBU L-111 4/5/2023 ***WSR CONT FROM 4-4-23*** LRS PERFORMED INJECTIVITY TEST OPEN POCKET 1bpm=1050psi, 2bpm=1230psi, 3bpm=1360psi) SET ST#1, RK-LGLV (19/64" ports, .625 spacer, 1318 bwpd) @ 4,478' MD LRS PERFORMED INJECTIVITY TEST (.75bpm = 2500psi, (draw down fail- pressure indicates RMX popped out) PULLED RMX DUMMY PRONG FROM 6,826' MD (S/I TBG PRESSURE 736#PSI) (damaged packing) SET RMX DUMMY PRONG IN RMX BODY AT 6,826' MD (draw down pass 14psi 30min) PULLED ST#2 RKP-PRONG FROM 4,418' MD (TBG 545psi) PULLED ST#2 RKED- DMY VLV FROM 4418'MD LRS PERFORMED INJECTIVITY TEST OPEN POCKET 1bpm=1110psi, 2bpm=11250psi, 3bpm=1350psi) SET ST#2 RK-WRF(19/64'', .625 spacer, 1318 bwpd) IN ST#2 @ 4418'MD PERFORM INJECTIVIT TEST, (1bpm= 1220psi , 1.85bpm= 2500psi) DRIFTED TUBING TO XO @ 4377'MD W/ 20'x3.70'' DMY WHIPSTOCK DRIFT (patch drift) ***WELL LEFT S/I ON DEPARTURE*** The patch is no longer in the WBS, and the plug is shown correctly in the new WBS, below. -WCB (g g) SET RMX DUMMY PRONG IN RMX BODY AT 6,826' MD P: (907) 659-5102 M: (307)399-3816 From: AK, D&C Well Integrity Coordinator Sent: Friday, March 8, 2013 9:18 PM To: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL@BP.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, D&C Wireline Operations Team Lead <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Oshiro, Joleen <JOLEEN.OSHIRO@bp.com>; 'jim.regg@alaska.gov' <jim.regg@alaska.gov>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; Weiss, Troy D <Troy.Weiss@bp.com> Cc: AK, D&C DHD Well Integrity Engineer (AKD&CDHDWellIntegri@bp.com) <AKD&CDHDWellIntegri@bp.com>; 'Ryan P Holt (Ryan.Holt@bp.com)' <Ryan.Holt@bp.com>; Arend, Jon <Jon.Arend@bp.com>; Oxner, Gary <Gary.Oxner@bp.com> Subject: UNDER EVALUATION: Injector L-111 (PTD #2020300) Ready for Miscible Gas Injection All, Injector L-111 (PTD #2020300) is currently operating under Administrative Approval AIO 24B.002 for TxIA communication when the well was on miscible gas injection. A tubing patch was set and a subsequent MIT-IA to 4070 psi passed on 07/08/2012. We have permission from the AOGCC to place the well on miscible gas injection for 30 days in order to evaluate the TxIA repair. The well is reclassified as Under Evaluation, and will be placed on a 28-day clock. Miscible gas injection can begin. Plan forward: Well Integrity: Monitor pressure response while well is on miscible gas injection Well Integrity Coordinator: Apply to cancel Administrative Approval AIO 24B.002 if pressure response during 30 day monitoring period is acceptable Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Office: 907.659.5738 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Well: L-111 i r 4,000 300 3,800 ♦ ■ 29D 280 3,600 270 260 3,400 250 3,200 240 230 3,OOD 220 2,80D 214 TIO Plot 2,600 190 D f Tubing 2.400 180 — On 2.200 ■ Bleed 200G 150 ® * Operable 1 } Not Oper 140 ® ♦ Under Eval �_-o- o 0 0 --o - - e o o -o -o - a o 0 0 - o- -o - o e--0- --0- �� MANIA 1,60D o �—�' 120 —A MAN OA 1,4DD 110 D MAN_OOA 10 1200 MAN_OOOA V MAN_WHT so 1,000 70 800 60 50 cm , 40 400 30 2W 20 10 03+2524 OM'0124 O W24 04d1524 04/22/24 OM2924 056k4 05f1324 052kt 052724 W0324 WIk4 0611724 062424 t Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWellIntegrity@hilcorp.com> Sent: Monday, August 31, 2020 8:45 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Alaska IMS User; Alaska NS - PB - Field Well Integrity; Aras Worthington; Bo York; John Menke; Oliver Sternicki; Stan Golis; Travis Smith - (C) Subject: Injector L-111 (PTD #2020300) POI 08/31/20, to be tested in September 2020 Mr. Wallace, Injector L-111 (PTD # 2020300) is due for its 4 -year AOGCC MIT -IA by the end of August 2020. The well was shut in on 08/07/20 for subsidence work which was completed on 08/30/20. The well was just POI on 08/31/20. To give the well ample time to stabilize, the AOGCC MIT -IA will be scheduled in the beginning days of September 2020. Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska InSp Num: mitBDB200902155256 Alaska Oil and Gas Conservation Commission Rel Insp Num: DATE: Wednesday, September 2, 2020 To: Jim Regg P.I. Supervisor t �. 1l r�' 7�yZ`, SUBJECT: Mechanical Integrity Tests Well L-111 Hilcorp North Slope, LLC Inj O' L-111 FROM: Brian Bixby PRUDHOE BAY UN BORE L-111 Petroleum Inspector 2302 - 2302 ' Src: Inspector 2020300 Reviewed By: SPT Test psi P.I. Supry I� IA NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-111 API Well Number 50-029-23069-00-00 Inspector Name: Brian Bixby Permit Number: 202-030-0 Inspection Date: 9/2/2020 InSp Num: mitBDB200902155256 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-111 "Type Inj O' TVD 4015 -'Tubing 2301 - 2302 - 2302 - 2302 ' PTD 2020300 Type Test SPT Test psi 1500 IA 77 3092 - 3034 - 3022 - BBL Pumped: 2.8 BBL Returned: 1.7 OA 122 150 152 152 - Interval 4YRTST P/F P Notes: Wednesday, September 2, 2020 Page 1 of 1 ® i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 31,2016 TO: Jim Regg Supervisor ��Re , Clh 4/, SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-111 FROM: Jeff Jones PRUDHOE BAY UN BORE L-111 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-111A. Well Number 50-029-23069-00-00 Inspector Name: Jeff Jones Permit Number: 202-030-0 Inspection Date: 8/27/2016 Insp Num: mitJJ160827151254 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-111 Type Inj W 'TVD 4015 - I Tubing 871 7 868 - 871 - 875 - PTD 2020300 ' Type Test SPT Test psi 1500 - IA 242 2198 - 2154 - 2146 - , Interval 4YRTST 1P/F J- P `- OA 220 I 285 - 286 ' 285- Notes: 0.8 BBLS diesel pumped. 1 well inspected,no exceptions noted. • SCANNED JUN .2 3 2017 Wednesday,August 31,2016 Page 1 of 1 Im~'3 Project Well History File Covr--oage 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. :J OJl.- 030 Well History File Identifier Organizing (dOIH~) R';FAN vi Color items: o Two-Sided 1111111111I11111111 ~escan Needed 111111111I111111111 OVERSIZED (Scannable) o Grayscale items: DIG!}" AL DATA v/ Diskettes, No. l o Other, NofType o Maps: o Other items scannable by large scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds NOTES: BY: BEVERLY ROBIN VINCENT SHERY DATE: Project Proofing 111111111I111111111 BY: BEVERLY ROBIN VINCENT SHERYL DATE: BY: BEVERLY ROBIN VINCENT SHERYL ~WINDY DATE: Scanning Preparation J x 30 = '3D Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) 111111111I111111111 ReScanned (iI1lJividoa/¡ugry [special M!wtíon] $cðnnillg CPlllplCIOd) 111111111I111111111 RESCANNED BV: BEVERLV ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (dOli e) 1111111111111111111 12/1 O/02Rev3NOTScanned. wpd • PTD 2'1Zo3 ao Regg, James B (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, August 02, 2012 1:59 PM To: AKDCWelllntegrityCoordinator @bp.com Cc: Regg, James B (DOA) Subject: FW: Permission to Place L -111 (PTD #2020300) on Gas Injection To Evaluate a Patch Repair In the Tubing Attachments: L -111 (PTD #202030) welibore schematic.pdf; MIT PBU L -111 07- 08- 12.xls; L -111 AA 24B -002 TxIA 09- 18- 08.pdf Gerald, We agree with the plan as detailed below, however we believe a 30 day miscible gas injection and monitoring is required rather than just a 2 week period. After the 30 days, evaluate and if all is acceptable, please apply for the Admin Approval AIO 24B.002 to be cancelled at that time. Thanks and Regards, Chris Wallace SEAMED 1!A AY 0 7 2013 Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276 -7542 (fax) chris.wallacePalaska.gov From: AK, D &C Well Integrity Coordinator [ Sent: Wednesday, August 01, 2012 5:46 PM To: Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Permission to Place L -111 (PTD #2020300) on Gas Injection To Evaluate a Patch Repair In the Tubing Jim, Injector L -111 (PTD #2020300) is currently operating under Administrative Approval AIO 24B.002 for TxIA communication when the well was on gas injection, currently allowing for water injection only. A leak detect log performed on 03/31/2011 found a leak at a gas lift mandrel station #3 in the well. A tubing patch was set across the gas lift mandrel on 07/07/2012, and a passing MIT -IA was performed to 4000 psi on 07/08/2012, with an inflatable bridge plug set in the well to better monitor for leakage to the tubing side. We would request your permission to allow the well to be placed on miscible gas injection under evaluation to see if the TxIA communication has been repaired for a M -I gas cycle. The reservoir engineers are saying that their plan would be to have the well placed on gas in January, 2013 (tentatively). The well will still remain on the Monthly Injection Report, and when the well is placed on gas injection, the well will be reclassified as Under Evaluation for increased pressure monitoring scrutiny for the first 2 weeks on gas injection. I'm including a copy of the new welibore schematic, the MIT -IA and a copy of AA AIO 24B.002 for reference. 1 • «L -1,11 (PTD #202030) wellbore schematic.pdf» «MIT PBU L -111 07- 08- 12.xls» «L -111 AA 24B -002 TxIA 09-18 - 08.pdf» Thank you for your consideration, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWelllntedrityCoordinator a(�BP.com 2 TREE= 4-1/16" CIVV 1111 SAF TES: 1{2S READINGS AVERAGE 125 ppm WELLHEA1) = FMC WHEN ON ML WELL REQUIRES A SSSV WHEN ON ACTUATOR = NA L-111 NIL KB. ELEV = 76.4' BF. FL.EV = 52.02' KOP= 800 — H9 TAM FORT COLLAR Max Angle = 40° @ 1595' Datum MD= 7075' Datum ND = 6600' SS 2266' --14 HES X NP, D = 3.813" I 9-5/8" CSG, 40#, L-80, ID = 8.835" H 2922' I - 411 GAS LIFT MANDRELS ST IVD - ND DEV 1Y F€ VLV LATCH FORT DATE 4-1/2" KB PATCH, ID = 2.45" — 4189' ..... ,. 4 3842 3541 4 KBG-2 *DMY BK-5 0 07/14/08 111 3 4199 3896 8 KBG-2 *Ds& BK-5 0 07/14/08 * STA # 3 & # 4 = WV'S HAVE EXTENDED FKG Minimum ID = 2.45" @ 4189' 4308' H4-1/2" HES X NP, D = 3.813" 4-1/2" KB PATCH I 4319' _17" X 4-112" BKR PRIEM PKR, 0 = 3.910" l'41 ■: 3 4-1/2" TBG, 12 6#, L-80, .0152 bpf, ID = 3.958" H 4375' 1 11 4377' H4 X 3-1/2" XO, ID = 2.992" UM 4393' ____BKR IBP w/ 1-3/8" FN (07/07/12) PERFORATION SUMMARY WATERFLOOD MANDRELS REF LOG: TCP PERF ST MD ND DEV TYPE VLV LATCH FORT DATE ANGLE AT TOP PERF: 9° @ 4546' NIP 2 4418 4113 8 MMG-W RKED RKP 0 03/03/02 1 4478 4172 7 MMG-W RKED RKP 0 03/03/02 143te: Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" r. ' 5 4546 - 4586 0 03/04/02 H 5243' H r TAM PORT COLLAR 4-5/8" v 5 4616 - 4636 0 03/04/02 1 "' 4-5/8" IF 5 4660 - 4673 0 03/04/02 4-5/8" ° 5 4719 - 4729 0 03/04/02 6768' H 3 HES X NP, D = 2.813" 4-5/8" ' 5 4768 - 4805 0 03/04/02 6778' H3 X 4-1/2" XO, ID = 2.950" 4-5/8" I ' 5 4832 - 4852 0 03/04/02 2-1/2" r 6 7014 - 7038 0 03/22/02 2-1/2" 6 7047 - 7052 0 03/22/02 6780' _17" X 4-1/2" BKR S-3 PKR, D = 3.875" 2 F2 r 6786' — 14 - 1/2" X 3-1/2" XO, ID = 2.950" 2-1/2" r 6 7070 - 7078 0 03/22/02 6806' — 13 - 1/2" HES X NP, D = 2.813" 6826' — 3-1/2" HES X NP, ID = 2.813" 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" —I 6838' I---- 6838' H3 WLEG, D = 2.905" -1 aMD TT NOT LOGGED 6892' --I PUP JT W/ RA TAG I 7362' --I PUP JT w I RA TAG PBTD H 7505' '•"*" ' ' • 1.1 * 4 k 4 4 0 4 4 4 4 7" CSG, 26#, L-80, .0383 bpf, D = 6.276" —I 7589' L • A • • •■•v•vA AvAN DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 03/06/02 ORIGINAL COMPLETION 07/25/08 PJC GLV CORRECTIONS WELL: L-111 03/16/02 MH/tlh GLV UPDATE 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE PERMIT No: '020300 03/22/02 CWS/KK ADPERFS 07/29/11 JCM/ PJC SET PATCH (07/24/11) API No: 50-029-23069-00 06/06/02 RUtlh GLV UPDATE 01/17/12 TM N/JIVID ADDED H2S SAFETY NOTE SEC 34, T12N, R11E 2339' NSL & 3873' WEL 04/08/03 DRS/TP TVD/MD CORRECTIONS 07/07/12 SET/ PJC SET IBP 07/18/08 JLJ/JMD GLV C/O (07/14/08) BP Exploration (Alaska) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rilalaska.gov; doa .aoacc.prudhoe.bav @alaska.00v; phoebe.brooks(S7alaska.gov; tom.maunderr(aalaska.00v OPERATOR: BP Exploration (Alaska), Inc. ` 012-11 FIELD / UNIT / PAD: Prudhoe Bay /PBU /L -Pad DATE: 07/08/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L -111 / Type Inj. N ' TVD ' 4,015' Tubing 2452 3033' 3034 3021 ' Interval 0 P.T.D. 2020300 ' Type test P Test psi ' 4070 Casing 205 4070 1 3988 3967 , P/F P / Notes: BP internal testing for MI service. Well had IBP set OA 20 ' 24 25 24 for high pressure testin differential purposes. Well is currenity working under AA24B.002 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA_ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU L - 111 07 - 08 - 12 mac_ -�► • • PM Zerz,..a 3oo Regg, James B (DOA) ' From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, August 01, 2012 7:24 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) S/14(7_ Cc: AK, D &C Well Integrity Coordinator 'Reif Subject: July 2012 AOGCC MIT Forms Attachments: July 2012 MIT Forms.zip ..,.... Jim, Phoebe, Please find attached MIT forms for July 2012. Sent Previously SCANNED MAY 0 7 2013 L -218 (PTD #2051190) sent 7/9/2012 04 -11A (PTD #1931580) sent 7/17/2012 S -112 (PTD #2021350) sent with reclassification notice Enclosed in .zip file END 1- 41/0 -23 (PTD #1870320) END 3- 17F/K -30 (PTD #2032160) NS10 (PTD #2001820) EPA Witnessed NS32 (PTD #2031580) EPA Witnessed L5 -29 (PTD #1870450) MPB -25 (PTD # 1972330) MPB -50 (PTD #2042520) EPA Witnessed MPC -25A (PTD # 1960210) MPC -42 (PTD #2040280) B -31 (PTD #1910460) 04 -09 (PTD #1760300) Corrected packer depth (original sent 7/30) 04 -13 (PTD #1780310) Corrected packer depth (original sent 7/30) 04 -350 (PTD #2111060) 11 -02 (PTD #1811280) 17 -15A (PTD #1991310) E -100 (PTD #1971880) #1970180) ,,,,111 ( PTD #2020300 il LPC -01 (PTD #1860480) V -220 (PTD #2080200) — well is currently on gas and was during test, inspector may have been told it was on water Y -03A (PTD # 2042350) secured for drill by on Y -19 Y -07A (PTD #2071050) Please let me know if I can be of further assistance. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegritvCoordinatorc BP.com 1 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(cdalaska.gov; doa. aoocc.prudhoe.bay(aDalaska.gov; phoebe.brooks(aalaska.aov; tom.maunder(rtalaska.gov OPERATOR: BP Exploration (Alaska), Inc. R Ci3 €'1 (1_ FIELD / UNIT / PAD: Prudhoe Bay /PBU /L -Pad DATE: 07/08/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L -111 ', Type Inj. N " TVD " 4,015 Tubing 2452 '3033 '3034 3021 Interval 0 P.T.D. 2020300 Type test P _ Test psi 4070 Casing 205 ' 4070 "3988 3967 P/F P Notes: BP internal testing for MI service. Well had IBP set OA 20 • 24 ' 25 • " 24 for high pressure testing differential purposes. Well is currenity working under AA24B.002 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Dnlling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT PBU L - 111 07 - 08 - 12 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ig TUBING PATCH Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ 4190 -4210 Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ - 202 -0300 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: Anchorage, AK 99519 - 6612 ,: 50- 029 - 23069 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028239 +- L -111 10. Field /Pool(s): PRUDHOE BAY FIELD / BOREALIS POOL 11. Present Well Condition Summary: Total Depth measured 7605 feet Plugs (measured) None feet true vertical 7198.3 feet Junk (measured) None feet Effective Depth measured 7505 feet Packer (measured) 4319, 6780 4189 4210 feet true vertical 7099.62 feet (true vertical) 4015, 6388 3886 3907 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 91.5# H-40 30 - 107 30 - 107 1490 470 Surface 2894' 9 -5/8" 40# L -80 28 - 2922 28 - 2631 5750 3090 Production 7565' 7 "26# L -80 24 - 7589 24 - 7183 7240 5410 Production Liner Liner 10,,,4311141"4 AUG 2 5• 201; Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ - _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 22 - 4377 22 - 4072 3 -1/2" 9.3# L -80 4377 - 6838 4072 - 6445 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker Premier Packer 4319 \ 4015 4 -1/2" Baker S -3 Perm Packer 6780 6388 4 -1/2" KB Packer �.w 4189 3886 4 -1/2" KB Packer RECEJV 3907 12. Stimulation or cement squeeze summary: AUG 16 2011 Intervals treated (measured): U Treatment descriptions including volumes used and final pressure: Mika Oft & Gas Ca s. GQm hs$s n Ancier &g® 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 2892 1508 Subsequent to operation: 7438 1686 14. Attachments: 15. Well Class after work: r Copies of Logs and Surveys Run Exploratory Development ❑ Service 151 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: « Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ 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: 311 -217 Contact Joe Lastufka Printed N , me .e Lastuk Title Petrotechnical Data Technologist Signat, re I\ BEL_ Phone 564 -4091 Date 8/16/2011 R �1L�++ AUG 1 4 � n ff./7 . �r Form 10 -404 Revised 10/2010 BDMS A 1 7 2011 / ' / Submit Original Only G�IZ� (/ L -111 202 -030 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L -111 3/4/02 PER 4,546. 4,586. 4,239.7 4,279.14 L -111 3/4/02 PER 4,616. 4,636. 4,308.71 4,328.42 L -111 3/4/02 PER 4,660. 4,673. 4,352.08 4,364.9 L -111 3/4/02 PER 4,719. 4,729. 4,410.25 4,420.11 L -111 3/4/02 PER 4,768. 4,805. 4,458.58 4,495.08 L -111 3/4/02 PER 4,832. 4,852. 4,521.73 4,541.47 L -111 3/21/02 PER 7,014. 7,038. 6,616.86 6,640.39 L -111 3/21/02 PER 7,047. 7,052. 6,649.21 6,654.12 L -111 3/21/02 PER 7,070. 7,078. 6,671.77 6,679.62 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 • 1 1 • • L -111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY v . AP I .,3, .$w '.j: S f 1 f' . . a o 7/23/2011; ** *WELL SHUT -IN UPON ARRIVAL * ** (E -LINE SET PATCH) INTIAL T /I /O = 550/0/50 PSI !,SPOT EQUIPMENT, RIG UP AND PT. 'LAY DOWN LUBE, RIG UP TOOL STING AND HOT CHECK. FINAL T /I /O = 550/0/50 PSI ** *JOB IN PROGRESS AND CONTINUED ON 24 -JUL- 2011 * ** € i 3 i € E _ 7/24/2011 ,***JOB CONTINUED FROM 23- JUL - 2011 * ** (E -LINE SET PATCH) ; INITIAL T /I /O = 550/0/50 PSI SET BAKER 4.5" KB STRADDLE PATCH © 4190'-420A 5' Fl FMFNT Tn :ELEMENT. OVERALL LENGTH = 25.4'. OD = 3.7 ". MIN ID = 2.45" ( !TOP OF PATCH AT 4188.6'. ;SWAB = C, SSV = C, MASTER = 0, WING = C FINAL T /I /O = 550/0/50 PSI ** *JOB COMPLETE. NOTIFY DSO. LEAVE LOCATION * ** ' 1 7/25/2011 +T /I /O = 1800/40/120. Temp = 98 *. T& IA FL (Pre MITIA). No integral on IA. Well is ?online, IA FL near surface (60'). SV = C. WV, SSV, MV = 0. IA, OA = OTG. j � E i i I Il r 7/26/2011 T /I /0= 1800/130/120 Temp= INJ MIT -IA ** *PASS * ** to 3000 psi ( Post TBG patch Pumped .4 bbls 60* 60/40 methanol to reach test pressure. 1st 15 minutes IA lost 90 psi, 2nd 15 minutes IA lost 10 psi, for a total of 100 psi in 30 minutes. Bled IAP ( —1.2 bbls) FWHP's= 1800/140/120 * *SV =S /I WV, SSV, MV =0 IA & 0A= OTG ** ? : Tags hung & Pad Op notified. I 9 E t � • • FLUIDS PUMPED BBLS 1 DIESEL .4 60/40 METH 1.4 TOTAL TREE = 4- 1/16" CIW 1 SAFETY Ne: WELL REQUIRES A SSSV WHEN WELLHEAD FMC ON ML I - ACTUATOR = NA L-1 1 1 KB. ELEV = 76.4' BF. ELEV = 52.02' KOP= 800' -I 974' I— {9 -5/8" TAM PORT COLLAR I isi Max Angle = 40° @ 1595' Datum MD = 7075' 2266' 1-14-1/2" HES X NIP, ID = 3.813" ( Datum TV D = 6600' SS 19 -5/8" CSG, 40 #, L -80, ID = 8.835" H 2922' I'- , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3842 3541 4 KBG -2 *DMY BK -5 0 07/14/08 I4 -1/2" KB PATCH, ID = 2.45" J—I 4189' -, 0 3 4199 3896 8 KBG -2 *DMY BK -5 0 07/14/08 * STA # 3 & # 4 = DMY'S HAVE EXTENDED PKG Minimum ID = 2.45" @ 4189' 4308' I- 14 -1(2" HES X NIP, ID= 3.813" I 4 -1/2" KB PATCH 4319' I,17" X 4 -112" BKR PREM PKR, ID = 3.910° I \. , --�_ 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 4375' 1 II 4377' H 4 -1/2" X 3 -1/2" XO, ID = 2.992" 1 WATERFLOOD MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE PERFORATION SUMMARY 2 4418 4113 8 MMG -W RKED RKP 0 03/03/02 REF LOG: TCP PERF 1 4478 4172 7 MMG -W RKED RKP 0 03/03/02 ANGLE AT TOP PERF: 9° @ 4546' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE —1 5243' 1-17" TAM PORT COLLAR I 4 -5/8" r 5 4546 - 4586 0 03/04/02 4 -5/8" r 5 4616 - 4636 0 03/04/02 4 -5/8" r 5 4660 - 4673 0 03/04/02 6768' H 3 -1/2" HES X NIP, ID = 2.813" I 4 -518" r 5 4719 - 4729 0 03/04/02 6778' H 3-1/2" X 4-1/2" XO, ID = 2.950" I 4 -5/8" r 5 4768 - 4805 0 03/04/02 4 -5/$" r 5 4832 - 4852 0 03/04/02 �' '-, 6780' 1_I7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 2 -112" r 6 7014 - 7038 0 03/22/02 2 -1/2" 6 7047 - 7052 0 03/22/02 6786' 1-14-1/2" X 3 -1/2" X0, ID = 2.950" I 2 -1/2" r 6 7070 - 7078 0 03/22/02 I 6806' 1-13-1/2" HES X NIP, ID = 2.813" ( I 6826' I--- 13 -1/2" HES X NIP, ID = 2.813" I 13 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2,992" 1-1 6838' I 6838' H 3 -1/2" WLEG, ID = 2.905" I H ELMD TT NOT LOGGED I 6892' I I PUP JT W/ RA TAG I 1 7362' I-I PUP JT w / RA TAG I I PBTD H 7505' .LIy1.1.f1 ?•f4 • • • • • • • • :::::::::::::::: 4 4 7" CSG, 26 #, L -80, .0383 bpf, ID = 6.276" I 7589 DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 03/06/02 ORIGINAL COMPLETION 07/25/08 PJC GLV CORRECTIONS WELL: L -111 03/16/02 MH/tlh GLV UPDATE 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: x 2020300 03/22/02 CWS /KK ADPERFS 07/29/11 JCM/ PJC SET PATCH (07/24/11) API No: 50- 029 - 23069 -00 06/06/02 RL /tlh GLV UPDATE SEC 34, T12N, R11 E 2339' NSL & 3873' WEL 04/08/03 DRS/TP TVD /MD CORRECTIONS 07/18/08 JLJ /JMD GLV C/O (07/14/08) BP Exploration (Alaska) • • [E ALA g A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11IISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Damien Greaves Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 (9,0---d30 Re: Prudhoe Bay Field, Borealis Pool, L -111 Sundry Number: 311 -217 Dear Mr. Greaves: ' .JUL. 1 4 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 holi.. . r weekend. Sin er- y, 011 opt . - Co issi. er DATED this ic? day of July, 2011. Encl. . - STATE OF ALASKA P ALASKA* AND GAS CONSERVA ON CO MMI I SS O f 5itt ) APPLICATION FOR SUNDRY APPROVALS , A) '''- ' ? f11 20 AAC 25.280 _ i 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ } "4` s �R 'Cha�h�e��eeg, ar $ SJOrt Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing 0 r;FirB�ssion ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: TUBING PATCH " 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -0300 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23069 -00 -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 ❑ L -111- 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028239 - PRUDHOE BAY Field / BOREALIS 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): 7605 - 7198.3 7505 - 7099.62 - NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 91.5# H-40 30 107 30 107 1490 470 Surface 2894' 9 -5/8" 40# L -80 28 2922 28 2631 5750 3090 Production 7565' 7" 26# L -80 24 7589 24 7183 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# L -80 22 4377 - - 3 -1/2" 9.3# L -80 4377 6838 Packers and SSSV Tvoe: 4 -1/2" Baker Premier Packer Packers and SSSV MD and TVD (ft): 4319 4015 4 -1/2" Baker S -3 Perm Packer 6780 6388 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/19/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Damien Greaves Printed Name Damien Greaves Title PE Signature 1-- 65 Phone Date 564 -4852 7/5/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY �] Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -5 1 1 -- I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test > Location Clearance ❑ Other: 6r. k w,-+- btess -. M 1 T- 64- t WA S-er f/r Subsequent Form Required: /D.- !1 / 7 APPROVED BY / Approved by: A( !• SIONER THE COMMISSION Date: !II.? r// . I ■ 1 A , Ii V / !1r7 . 44* '04 ;r r 711-1( TX Form 10 -403 Revised 1/2010 �' ' �. J Submit in Duplicate L -111 202 -030 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L -111 3/4/02 PER 4,546. 4,586. 4,239.7 4,279.14 L -111 3/4/02 PER 4,616. 4,636. 4,308.71 4,328.42 L -111 3/4/02 PER 4,660. 4,673. 4,352.08 4,364.9 L -111 3/4/02 PER 4,719. 4,729. 4,410.25 4,420.11 L -111 3/4/02 PER 4,768. 4,805. 4,458.58 4,495.08 L -111 3/4/02 PER 4,832. 4,852. 4,521.73 4,541.47 L -111 3/21/02 PER 7,014. 7,038. 6,616.86 6,640.39 L -111 3/21/02 PER 7,047. 7,052. 6,649.21 6,654.12 L -111 3/21/02 PER 7,070. 7,078. 6,671.77 6,679.62 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 • L -111i: Tubing Patch • • ABRLPDWL11 bp To: J. Bixby/T. Norene ADW Wireline T/L Date: June 27, 2010 C.Olsen/T. Norene ADW Well Service T/L From: Damien Greaves Borealis PE AFE: ABRLPDWL11 Est. Cost: Subject: L -111 is Set Patch to restore well integrity, for MI IOR: 2O injection Job Sequence: 1 S Drift well with dummy patch 2 E Set Patch 3 F MIT -IA Current Status PWI only under AA due to TxIA communication while on MI Last WT Well injecting 2900 BLP @ 1470 psia on 6/26/11 BHP 3200 psig @ 6600 ft SS estimated, last SBHP taken in 2002 @ 2952psi Max Deviation 40 deg @ 1595 ft MD Minimum ID 2.813" @ 6768' HES X Nipple Last Tag 7,020 ft. MD on 03/24/2011 before running LDL Last Downhole LDL on 3/31/2011 OP Latest H2S Value N/A OBJECTIVE: The primary objective of this intervention is to restore well integrity by setting a tubing patch in L -111i to allow injecting MI. A LDL run in March 2011, suggest a leak at GL station 3. 1 of 7 L -111 is Tubing Patch S ABRLPDWL1 1 HISTORY: L -111 i is a major injector that supports 2 big producers in Borealis, L -100 and L -114A. The ability to place well on MI will yield IOR benefits of 200 BOPD over a five (5) year period L -111 i is a vertical WAG injector that has never been pre - produced. It is currently only allowed to inject water. The well has had one slug of MI. The well was taken off of MI on 4/10/08 due to pressure increase on IA. The inner annulus pressure (IAP) built up rapidly to the max allowable annular pressure (MAASP). Many attempts were made to bleed pressure, but pressure would quickly build again on the IAP. At this point the well was approved for PWI only. In July 2008, the DGLV's in stations 3 and 4 were changed to include extended packing in an attempt to return the well to MI. The well passed MITIA to 4000 psia in July and August 2008. The latter was witnessed and approved by AOGCC. In September 2008, the production operator reported rapid increase in IAP and build up rate (BUR) unmanageable. The well was again approved for PWI only on 9/19/2008. Since 2008 the production operator has continued to monitor the IAP and bleeds off the pressure as necessary. On 7/8/2010 the well passed an MIT -IA to 2500 psia.- In March 2011, a LDL was able to determine a possible leak at the GLM # 3 ✓ 2 of 7 L -111i: Tubing Patch • ABRLPDWL11 Well Integrity History > 02/06/08: Cameron welllhead tech adjusted gland nuts on T & IC, cleaned oil from wellhead > 04/10/08: Notified AOGCC by phone & EM of TxIA while on MI, approved to swap to water for MITIA > 07/14/08: DGLVs, MITIA Passed to 4000 psi > 08/08/08: AOGCC MITIA Passed to 4000 psi > 09/05/08: PO call -in IAP BUR unmanageable > 09/19/08: AA24B.002 approved for PWI only due to TxIA on MI > 07/08/10: AOGCC MIT -IA Passed to 2500 psi > 03/16/11: PPPOT -T - Passed > 03/31/11: Possible leak at GLM #3 Contacts: Damien Greaves Production Engineer Office / Cell: 564 - 4852/250 - 7856 cc: Well File Slickline: Pre -Patch 1. RU SL 2. Drift to 4 -1/2" nipple @ 4308' MD with 4 -1/2" x 16' Dummy patch Patch Specs 4 -1/2" Baker packer — L -80 Patch single run system. Use manufacturer's recommended setting procedure. Patch Depth • Patch Setting Depth is 4190' - 4206' ELMD ✓ • Patch Length: 16' element to element. • Top GLM #tdepth at 4195' ELMD from PDS LDL on 3/31/11 7.(1-€( E -line: Set 3. RU E -Line. Conduct PJSM with the crew. 3 of 7 L -111i: Tubing Patch • ABRLPDWL11 4. RIH and set 16 ft long one run w/ 4 -1/2" Baker 35KB Straddle. 5. Log w /CCL and Set Packer at 4190' - 4206' elm per manufacturer's recommendations. POOH. 6. Depth is referenced to PDS LDL 03/31/11 7. RDMO Fullbore 8. MIT -IA to 3000 psi. Hand well over to pad operator to place on well injector. Before placing on injection operator should ensure IA is bled to 500 psi. Discuss with WIE to determine suitability for MI injection. 4 of 7 L -111i: Tubing Patch • 0 ABRLPDWL11 LDL — March 31, 2011 i T , I v T = 830 psi -- IA = 3,100 psi -- OA = 50 psi Dp y w i, smc. P Database File: d:twarriorldata11.111 tecweRI.111 3.db Dataset Pathname: passl2 Presentation Format: wid,�log Dataset Creation: Thu Mar 31 06:25:34 2011 by Log Sondex V7.02 SP1 Charted by: Depth in Feet scaled 1240 7000 CCL -765 100 Temperature (degF) 0 Line Speed (fttmin) -200` -3 Differential Temperature (degF) 0 Head Tension (lb) 200 0 WLD-A 1 0 Temperature (degF) 200 0 WLD- B 1 0 'OILD -C 1 j i I ! , � . t t 4— Temperature Differential Temperature --M # 4-112" x 16` Baker S L -80 side nm patch ' ! Line Speed 4190' - 4206' ELMD Temperature tl. , 4 — WID�A l - •--, GLM #3 I J "ossible L Signature - 4200 ,. _ _ _, Head Tension ) `UVLD -B ,CAL __ ._._.. , i e f ' WLD-C i ..._.._ ,. i l 4 5 of 7 . . . L-111i: Tubing Patch • 0 ABRLPDWL11 L-111 i WBS :WEE - 4 V 18" CAY SAFETY "CTRS: WELL REOURES A SSW WHEN I AUL HEAD - ON ML A CTUA - 76NA.A. L-1 1 1 dr OLEV - " 52.02 1401 , ' ' 803 974' H9-5.19 TA M FO RT CCE.LAR I 43, Angle - 40' 4 19E5' !jai tEll fdp - 7075' avian TVD - 8803' SS 0- /LEIF H 2927 -ST 1163 TN/D EE GAS TY FE V LA CA'TE M 4 I 3842 I 3541 I 4 I 43G2 1 BK-5 I 0 I 07114/C6 3 4190 3888 8 4302 04AY M(-5 0 07/14.08 Minimum ID = zair r: 67e8 • STA N 3 & Al 4 • 1:11.1'Y'S HAVE CCIDDED Fs( G 3-1/2" HES X NIPPLE I 430ff F141 /2' HES X MP, ID • 3 81 T I 4319 r x 4-V2" M IDI NM D - 3.910 - 1-11 437ff '':ii Ak ril • 77' 1+1 .2 x sin xo, o - vn a I 43 WATERILOOD MAXIMS PERFCRATION SUMP RY Mi STI It) TVD (V ri VW LAT011 PORT DATE LOG. T 2 4418 4113 8 1111AG-W W ED RIP 0 03/03,02 ANGLE AT TCP 9 4546 REF CP POW 1 4478 4172 7 IALIG-W FOODD RI4P 0 133/03/Q2 .43W: - @ Nci Fkfer In Radmficri DB for list:v Fell' data SOX SPC INTERVAL OpriStic DATE • 5 4548 , 4566 0 03104402 2 I 524ff 71—TANAPCLRT OCILLAR 4 ' 5 4818 4636 0 0.3104102 • 5 4880 4673 0 0104.02 0711ff 113.1 /2' NES X INN? 0 2_81T I IP 4-56 5 4719 • 4729 0 0104132 67719 113.- 1 /2 X A 1.2 X0, D • 2.950' 1 4-5 IF 5 4768 . 4835 0 010442 4-56" ' 5 4892 - 4852 0 031047132 VW l_ir x 4-v7 Elai S-9 PIO; 11 • 187T I 242 r 6 7C114 • 7038 0 022202 Cif ill — 670ff 114±.2 31 a XO. D • 2_854r I 2 -1/2" r 8 7047 - 7052 0 03 2-12' r 6 7070 - nu a 0 0 3/ 22,02 90017 HI 1 ICS X tiP D 2_81T I I 6026 H.3. 1.2 HES X MP, D • 2111T I I 31,2' TEG, UM, L-813 TCIL 0087 bpf, D. 2_992" H 683ff I sear HI 1 n" NIG, Dr 2.905 I I I-lautyrr war LOGGED I 131192" HAP JT 1M RA TAG I 7392' 1 JT rir/ RA 174G I Para 7509 lirciEff 41cOlri 8+400.0 4.M41111.fol 4104414,01•01 I r css, 26 8, L-83, 0383 1311, Cl • 6176 H 759W AMM.,10.411A0 D A T E R E V BY COMENTS DATE F E U B Y C O M M E N T S SORGALS L i n - C O M H 1 1 0 2 C I I I G I N A L C . 0 1 1 PLUM 07/25;08 PJC GLV O O R R E C T O N S Mai: 1.- 1 1 1 11.3/18108 IMO GLV URA it 1321 15/11 IABUMD A ODEDSSSV SAFETY NOTE RZRIAT Pia. C120303 03122102 CA/0( ADPOWS API 43: 93 4323•Z1083-013 019802 IL.Ih GLV URA TE SEC 34,712N, Ft1 1 EMIT NEL I 3877 'AIL 043883 cRsra NamocolIFECTCINS 07/18106 .,LJ.140 G..V 00037/14.061 EP Esploration (Alaska} 6 of 7 ` L -111i: Tubing Patch • • ABRLPDWL1 1 7 of 7 III • WELL LOG ICIL11-11-: TRANSMITTAL PROAciivE DIAgNoMIC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka 90 - 1 • a- -3 Q a cas 900 Benson Blvd. Anchorage, Alaska 99508 - and '- l --O�� ace) 2-c, ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C *ffiiitieb MAY 2 3 M D Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 29- Mar-11 L-111 BL /EDE 50-029-23069-00 2) Leak Detection - WLD 31-Mar-11 V -119 BL/ EDE 1 1 -00 REC r J Signed : Date : nPR 19 2011 Print Name: c C. - t` PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -88952 E-MAIL : pdsanchoraaec memorvloa.com WEBSITE : www.memorvloo.com C:\Documents and Settings\Diane Williams \Desktop\BP_Transmit.doex MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 To: Jim Regg '~~~'7'y(~'i~ SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC L-111 FROM: Chuck Scheve PRUDHOE BAY UN BORE L-111 Petroleum Inspector Src: Inspector N (1N_ (' (INFTTI F NTT A T . Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN BORE L-111 API Well Number: 50-029-23069-00-00 Inspector Name: Chuck Scheve mitCS100711165759 Permit Number: Insp Num: 202-030-0 Inspection Date: 7/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We^ L-111 ' Type Inj. ; W TVD cols ~ IA s2o zsoo ~ za2a zalo - P.T.D 2020300 TypeTest SPT ~ Test psi 1s00 QA 160 160 160 160 Interval REQvAR p/F P ~ Tubing 1300 1300 ]300 1300 Notes: pre-test pressures observed and found stable. IrSC? 2-~1~.~90Z- Wednesday, July 14, 2010 Page 1 of 1 C~ 5J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks~alaska_gov; tom.maunder@a~ska.gov; doa.aogcc.pnxltroe.bay@alaska.gov OPERATOR: BP Explaratian (Alaska), Inc. FIELD t UNIT J PAD: Prudhoe Bay {PBU ! L Pad DATE: 7/8110 OPERATOR REP: Tiffany Quy AOGCC REP: Chuck Scheve Packer Pretest Init~l 15 Min. 30 Min. Welt L-111 T In. W TVD 4,015 T 1,300 1,300 1,300 1,300 Interval V P.T.D. 2020300 T test P Test 1500 520 2,500 2,420 2,410 P/F P Notes: AOGCC MIT-IA to 2500 psi for AA ownpfianoe OA 16(1 160 16(? 160 Well L-119 T In'. G TYD 6,446' Tubi 2,550 2,550 2,550 2,550 Interval 4 P.T.D. 2020640 T test P Test 1611.5 Casi 100 4,000 3,940 3,940 P/F P Notes: AOGGG MIT-IA to 4000 psi for 4 year UIC OA 20 40 40 40 Well L-123 T In'. G TVD 6,348' T 3,060 3,060 3,060 3,060 Interval 4 P.T.D. 2051940 T test P Test 15$7 820 3,980 3,940 3,930 P/F P Notes: AOGCC MIT-IA to 4000 psi for 4 year UIC OA 270 680 640 610 Well T In'. TVD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD Tu ' Interval P.T.D. T test Test ~ Cast P/F Notes: OA ~-g(~ ~g~ ~ TYPE INJ Codes TYPE TEST Codes ~~, e i .~' - ~ I~ Iv ~ ' ~,~ ~ ~ INTERVAL Codes ,... ,v, ~ i+ n.:.at' I =Initial Test D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Intemal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A = Temperadxe Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O = Olher (describe in notes} MIT Report Form BFL 11!27/07 MIT PBU L-111, 119 & 123 07-0&10 xls • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~'a~:,~4..~~~;.~ + ~! ~ ';'' ~. ~ ZOC ~ August 14, 2009 ~ bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T ~i ~ 2009 ~llasYc~ t~il ~ Ga~ Cons. Commi~~ion Anchoraqe ~~ U y~ ~ ~ V ~,,~ - l I 1 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad 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 w ~ BP Exploretion (Alaska ) inc. Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-oH Report of Sundry Operetions (10-404) eAte L pad B/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 inhibdor/ sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 612 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2,8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L•102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5l6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 2.2 NA 25.5 6127/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6127/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 5~29231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 5~29232290000 NA 2 NA 17 6/26/2009 L404 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 1-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6l26/2009 L-217 2060750 50029233120000 late blocki~ conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6l26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6l27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6l27/2009 • • ~~ a ~ ~ ~ ~ SARAH PAL1N, GOVERNOR ~0 ~..- ~ ~ ~~g~ Qji, ,~ (~~ 333 w 7thavENU€, suiTE Sao Cp1~;J~l~YA'1'Ip~ Ca~II;J~I~K ANCNORAGE.AlASKA 99501-3539 tZ~i-s a~ PHONE (907} 279-1433 FAX (907} 278-7542 ADMINISTRATIVE APPROVAL AIt~ 2AB.002 Mr. Steve Rossberg Wells Manager _ BP Exploration {Alaska) Inc. ~ ~ ry ''I ~I ~ ~,~' ~1 t; ~~~ 7 E1 i P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU L-111 {PTD 2020300) Request for Administrative Approval Borealis Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order {AIO) 24B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. The Commission was notified by BPXA of tubing by inner annuls communication while injecting miscible gas in PBU L-111. Gas lift valves with extended packing were installed to remedy the pressure communication in July 2008 and subsequent pressure tests were performed to prove primary and secondary barriers in the well. An AOGCC witnessed test to 4000 psi passed on August 8, 2008. Subsequent to returning the well to miscible gas injection, the well demonstrates inner annulus repressurization that can be safely managed with periodic pressure bleeds. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU L-111. The Commission believes that the well's condition does not compromise overall well integrity sa as to threaten the environment or human safety, if the well's operation is subject to the constraints enumerated below. AOGCC's administrative approval to continue water injection only in PBU L-111 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; Ai0 24B.002 • • September 19, 2008 Page 2 of 2 3. BPXA shall perform an MIT - IA every 2 years to the maximum anticipated injection pressure; 4. BPXA shall immediately notify the AOGCC and shut in the well If there is any continued deterioration in well integY•ity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; S. After well shut in due to a change in the weIl's mechanical condition, AOGCC approval shall be required to restart injection; and 6. The MIT anniversary date is August 8, 2008. DONE at Anchorage, Alaska and dated September 19, 2008. Daniel T. S ount, Jr. Cathy . 1?oerster Chair Commissioner cc: BPXA Well Integrity Coordinator, PRB-20 P.O. Box 196612 Anchorage, AK 99S 19-66 i 2 RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, ~ 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 of the matter determined by it. Ifthe notice vas mailed, then the period of time shall be 23 days. An application For reconsideration must set out the respect in which the order or decision is believed to be erroneous. 'Che Commission shat) grant ar refuse the application for reconsideration in whole or in part within I O days after ii is filed. Failure to act on it within IO-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this artier or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeat MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distn~butes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration vas 61ed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal A1i1ST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission othernise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t)he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a ~ekend or state holiday, in which event the period runs until S:QO p.m. on the Hero day that does not fall on a weekend or state holiday. UNDER EVALUATION: L-111 (PTD #2020300) Place on water injection while obtain ... Page 1 of 1 • • Regg, James B (DOA) From: NSU,. ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Friday, September 05, 2008 8:18 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Oakley, Ray (PRA) Subject: UNDER EVALUATION: L-111 (PTD #2020300) Place on water injection while obtain AA Attachments: L-111.pdf; L-111 TIO 5-Sept-2008.doc ,, Ali, Well L-111 {PTD #2020300) exhibi#ed TxiA communication when on MI injection in April 2008. The DGLV's were replaced with DGLV's with extended packing and the wail passed an AOGCC witnessed MITIA to 4000 psi while on water injection on 08f08f08. Following this passing test the well was moved back to MI injection for evaluation and monitoring on 08/17f08. The IA was observed to re-pressurize at a rate that is unmanageable by bleeds. The well wilt be swapped to water injection and reclassified as Under Evaluation so that an Administrative Approval can be pursued. Please watch for thermal expansion when the weEl is swapped to water injection as the IA is liquid packed. Plan forward: 1. Opera#ions: Place well on water injection 2. WIC: Prepare paperwork for Administrative Approval Application to the AOGCC A TIO plot and wellbore schematic have been included for reference. «L-111.pdf» «L-111 TIO 5-Sept-2008.doc» Please contact me with any questions or cone r ~~~ ~~~ ~ 2~~~ Thank you, Taylor Wellman {filling in for Anna Dube} Taylor Wellman Alternate -Jason Dahlem Well integrity Projects Engineer (907) 659-5098 {office) {907) 659-5100 pager #1446 x2418 {harmony) {907) 947-9533 {mobile) d~1r~-~ R- ~~_ CC~zt~~~-;~ w~ lcc~l~.- 'r"`MC~,,~ ~~-~`l a'l ~~~~`~j ' l C~Cic~c~;~ ~s/ sF~~ P~l~ rc~ ~~ 1 ~ / ~~,~.~~ ~I `~Iv 9isi2oos PBU L-111 PTD 202-030 9/5/2008 d,p00 3,ppp 2App 1,pOp U3fl d/07 10115/07 11115/U7 1"L116J07 p111F~Jp2 p2/lfl08 p311pl02 pdi181fj8 0511910~i p6119/p6 p7/"lp/Op 0$I10ip$ `T~~ I - • y~ V ~: ~ .,~ ~ ., t,' i i r~.. t TREE= 4-1/16" CM/ WELLHEAD= FMC ACTUATOR = NA KB. ELEV = 76.4' BF. B.EV = 52.02' KOP= 800' Max A ng le = Detum MD = 40 @ 1595' 7075' Datum TV D = 6600' SS 9-5/8" CSG, 40#, L-80, ID= 8.835" 2922' ' Minimum ID = 2.813" @ 6768' 3-1/2" HES X NIPPLE C-,A S 1 IFT MANf1RFl S ST MD ND DEV TYPE VLV LATCH FIDRT DATE 4 3 3842 4199 3465 3820 3 8 KBG-2 KBG-2 DMY DMY BK-5 BK-5 0 0 03/06/02 06/06/02 VVH ItKrLUVU MHNUKtLJ ST MD TVD DEV TYPE VLV LATCH FORT DATE 2 1 4418 4478 4037 4097 8 8 MMG-W MMG-W RK® RKED RKP RKP 0 0 03/06/02 03/06/02 4308' 41/2" HES X NP, ID= 3.813" 4319' T' X4-1C2" BKRPREMERPKR ID= 3.910" 41/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 4375' 4877 41/2" X 3-1/2" XO, ID = 2.992" 1 PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 10 @4546' Note: Refer to Production DB for historical rf data SIZE SPF INTERVAL Opn/Sgz DATE 4518" 5 4546 -4586 O 03/04/02 45/8" 5 4616 -4636 O 03/04!02 4-5/8" 5 4660 -4673 O 03/04/02 4-5/8" 5 4719 - 4729 O 03/04/02 4-5/8" 5 4768 -4805 O 03/04/02 4-5/8" 5 4832 -4852 O 03/04!02 2-1/2" 6 7014 - 7038 O 03/22/02 2-1/2" 6 7047 - 7052 O 03/22/02 2-1l2" 6 7070 - 7078 O 03/22/02 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I--i 6837' ~ 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID= 2.992" ~ 5243' T' TAM PORT CDLLAR 6768' 3-1/2" HES X NP, ID= 2.813 6778' 3-1 /2" X 4-1/2" XO, ID = 2.950" 6780' T' X 4-1 /2" BKR S-3 PKR, ID = 3.875" 6786' 4.1/2" X 3-1/2" XO, ID = 2.950" 6806' 3-1/2" HES X NP, ID= 2.813" 6826' 3-1/2" HES X NP, ID= 2.813" 6838' 3-112" WLEG, ID= 2.905" D_MDTT NOT LOGGED 6892' T' 26# X 20' F'l1P JT W/ RA TAG 2' H T' 26# X 20' PUP JT W/ RA TAG FBTD H 7505' 7" CSG, 26#, L-80, ID= 6.276" 7589' DOTE REV BY COMMENTS DATE REV BY COMMENTS 03/06/02 ORIGINALCOMRETION 03/12/02 CH/TP CORRECTIONS 03/16/02 MH/tlh GLV I~CATE 03/22/02 CWS/KK A DPERFS 06/06/02 RL/tlh GLV t~DATE 04/08/03 DRSlfP TVD/MD CORRECTIONS BOREALIS UNff WELL: L-111 F'ff2Mff No: 2020300 API nb: 50-029-23069-00 SEC 34, T12N, R11 E 2339' NSL & 3873' W~ BP Exploration (Alaska) L 111 SAFETY NOTES: GLM'S @ STA#1  ARE 3-1/2" X 1-1/2" MMG 1MS, WHICH ARE WATERFLOOD MANDRELS. 974' 9-5/8" TA M PORT COLLAR 2266' 4-1/2" HES X NIP, ID = 3.813" OPERABLE: L-111 (PTD #2020300) Place on MI injection for further evaluation Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] q %`D ~ Sent: Saturday, August 09, 2008 7:24 PM ~ q c To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead;~PB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; Fleckenstein, Robert J (DOA) Cc: Wellman, Taylor T; Townsend, S. Eliot; Oakley, Ray (PRA); NSU, ADW Well Integrity Engineer Subject: OPERABLE: L-111 (PTD #2020300) Place on MI injection for further evaluation Follow Up Flag: Follow up Flag Status: Yellow Attachments: L-111 (PTD #2020300) Request to swap to MI Injection; MIT PBU L-111 08-08-08.x1s AEI, Well L-111 (PTD #2020300) passed an AOGCC witnessed MIT-IA to 4,000 psi while on water injection on 08/08/08. fiherefore, the well has been reclassified as Operable and needs to be swapped to MI~ infection for ~ further evaluation, The Wel! will be monitored for possible TxIA communication to M1. The original email request to the AOGCC to allow the Well to be on Mi injection has been included for reference. ~ Please see the attached MIT form for details of the test. «L-111 (PTD #2020300) Request to swap to MI Injection» «MIT PBU L-111 08-08-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 31, 2008 7:50 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Oakley, Ray (PRA) Subject: UNDER EVALUATION: L-111 (PTD #2020300) Place on water injection to obtain AOGCC MITIA All, Well L-111 (PTD #2020300) exhibited TxIA communication when on MI injection in April `08. The well passed an MITIA while shut-in on 7114/08 after replacing the DGLV with a DGLV with extended packing. The well has been reclassified as Under Evaluation so that it may be returned to water injection. Once the well is stable, an AOGCC witnessed MITIA will be conducted for UIC compliance. The well will then be swapped to MI injection and monitored for IA repressurization. Please return the wel- to water injection and watch for thermal expansion as the IA is IigLiid packed. 9/5/2008 OPERABLE: L-111 (PTD #2020300) Place on MI injection for further evaluation Page 2 of 2 • Plan forward: 1. Operations: Place well on water injection 2. Fullbore: AOGCC MITIA to 4000 psi 3. Operations: Swap well to MI injection 4. Well Integrity Engineer: Monitor wellhead pressures for IA repressurization while on MI A TIO plot and wellbore schematic have been included for reference. « File: L-111.pdf » Please call with any questions. Thank you, Anna I~ic6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: {907} 659-5100 x1154 9/5/2008 PBU L-111 PTD 202-030 7/31 /2008 a,~-Oo s,r~oo 2 n00 1 n00 Ofl/14/07 09/14!07 10i1~i07 11/15/07 12/16107 01116/OB 02!16/0$ 03/1fl/0$ 041181Ufl 05119/08 Of,/19lOfl 07120/0$ ~~ ~a,~ ~~ .--T-- , _- -,_ _._--T- , -- -,- -- . _~ . , • C] C] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. r~ ~~ ~ /~~ FIELD /UNIT /PAD: Prudhoe Bay /PBU / L Pad IYl ~ ~ c DATE: 08/08/08 OPERATOR REP: Andrea Hughes AOGCC REP: Chuck Scheve Packer Dept Pretest Initial 15 Min. 30 Min. Well L-111 -Type Inj. W TVD 4,015' Tubing 1,940 1,950 1,980 1,970 Interval O P.T.D. 2020300 Type test P Test psi ~ 4000 Casing 680 4,000 3,940 3,940 P/F P Notes: MIT-IA to evaluate possible TxIA communication. OA 50 60 60 60 Well Type Inj. TVD Tubing Interva! P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle 1=Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU L-111 08-08-08.x1s MEMORANDUM . TO: Jim Regg ~~~ ~5~~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-111 PRUDHOE BAY UN BORE L-1 I 1 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~- Comm Well Name: PRUDHOE BAY UN BORE L-111 Insp Num: mitCS080811131000 Rel Insp Num: API Well Number: 50-029-23069-00-00 Permit Number: 202-030-o Inspector Name: Chuck Scheve Inspection Date: Big/2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-111 Type Inj. w TVD cols IA 6so aooo 3940 3940 p•T• 2020300 TypeTest SPT Test psi lsoo pA so 60 60 60 Interval OTHER p~F P ~ Tubing 1940 1950 1980 1970 NOtes• Test performed prior to gas injection. ~~~.~~dN~~ SAP :~ fl 20G8 Monday, August 18, 2008 Page 1 of 1 L-111 (PTD #2020300) lA Repressurization -NOT OPERABLE • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ _ ,/~/ZR j~ Sent: Tuesday, April 29, 2008 3:39 PMPG~~ `~I I To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; NSU, ADW WL & Completion Supervisor Cc: NSU, ADW WI Tech; Oakley, Ray (PRA); Dahlem, Jason E; NSU, ADW Well Integrity Engineer Subject: L-111 (PTD #2020300) IA Repressurization -NOT OPERABLE All, Due to the proximity of Nabors 9ES rig, we are unable to access L-111 to perform the AOGCC witnessed MITIA. Therefore, the well has been reclassified as Not Operable and needs to be shut in immediately. The well will remain shut ,/ in until it can be accessed to perform the MIT-IA. Please cal( with any questions or concerns, Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, April 10, 2008 10:46 AM ~~~ MAY ~ 2 2008 To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; NSU, ADW WL & Completion Supervisor Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Oakley, Ray (PRA); Winslow, Jack L. Subject: L-111 (PTD #2020300) IA Repressurization -UNDER EVALUATION All, Well L-111 (PTD #2020300) has begun to exhibit IA repressurization on MI injection. The wellhead pressures were equal to tubing/IA/OA 2650/2020/260 on 04/08/08 after bleeding the IA pressure from 1850 psi to 760 psi on 04/05/08. The well has been reclassified as Under Evaluation and shall be swapped to water injection as soon as safely possible. If the well can not be swapped to water within a timely manner, the well shall be shut-in until swapped. Once on water injection, an AOGCC witnessed MITIA will be conducted. The plan for ward is: +~~~- ~ ~'C~~~_-~t: ~~~~` 1. D: Bleed IAP, monitor-DONE, confirmed IA repressurization InJ~C~,ti~ 4(1~1~Zc~c~~ 2. Operations: Swap to water injection `~7 3. F: AOGCC witnessed MITIA 4. WIC: Review MITIA results. Consider sending request for AOGCC Administrative Approval to restrict the well to water injection only due to TxIA communication on MI injection A wellbore schematic and Tl0 plot have been included for reference. « File: L-111 TIO plot.BMP » Please call with any questions. Thank you, Annat ~u6e, ~'.~. Well Integrity Coardinatar 4/29!2008 L-111 (PTD #2020300) IA Repressurization -NOT OPERABLE • GPB V~ells Group Pane: (9U7) 659-51132 Pager: (9a7~ 659-51ao x1154 Page 2 of 2 4/29/2008 ~~~ ~. '~f 00 ~o -~- ~i -~-. 500~l0 tJtr $OOZlS~J L l0ozJ0 W 4 4 ~00~19Zl8 LOOZ! 4 4~9 100~JLZJ~ ~OOZlO W 4 0 000' 4 aoo' ~ oao`~ ~l -#- ~old ail 4 4 4-~ ooo'v • WELLHEAD= FMC ACTUATOR= NA KB. ELEV = 76.4' BF. ELEV = 52.02' KOP= 800' Max A ngle = 40 @ 1595' Datum MD = 7075' Datum TV D= 6600' SS 9-5l8" CSG, 40#, L-80, ID = 8.835" 2922' Minimum ID = 2.813" @ 6768' 3-1/2" HES X NIPPLE 4-1/7' TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 4375' PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 10 @ 4546' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/S DATE 45/8" 5 4546 - 4586 O 03/04/02 45/8" 5 4616 - 4636 O 03/04/02 4-5/8" 5 4660 - 4673 O 03/04/02 45/8" 5 4719 - 4729 O 03/04/02 4-5/8" 5 4768 - 4805 O 03/04/02 45/8" 5 4832 - 4852 O 03/04/02 2-1/7' 6 7014 - 7038 O 03/22/02 2-1/7' 6 7047 - 7052 O 03/22102 2-1/7' 6 7070 - 7078 O 03/22!02 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 6837' L-111 SAFETY NOTES: GLM'S @ STA#1 8 #2 ARE 3-1/2" X 1-1/2" MMG W S, WHICH ARE WATERFLOOD MANDRELS. 974' 9-5/8"TAM PORT COLLAR 2266 4-1/2" HES X NIP, ID = 3.813" C,A S I IFTMANrY2Fl S ST MD TV D DEV TYPE V LV LATCH R~RT DATE 4 3 3842 4199 3465 3820 3 8 KBG-2 KBG-2 DMY DMY BK-5 BK-5 0 0 03/06/02 06/0G/02 VVH ItKrLVVUMHNUKtLJ ST MD TV D DEV TYPE V LV LATCH RCRT DATE 2 1 4418 4478 4037 4097 8 8 MMG-W MMG-W RK® RKED RKP RKP 0 0 03/06/02 03/06/02 4308' -1 41/7' HES X NP, ID= 3.813"J 4319' T' X 4-1CL" BKR PREMER PKR, ID= 3.910" 4377' 41 /2" X 3-1l2" XO, ID = 2.992" 3-1/7' TBG, 9.2#, L-80, .0087 bpf, ID= 2.992" 5243' T' TAM PORT COLLAR 6768' 3-1/7' HES X NP, ID= 2.813" 677$' 3-1/7' X 4-1/2" XO, ID = 2.950" -~ 6780' T' X 4-1 /2" BKR S-3 PKR, ID = 3.875" 6786' 41/7' X 3-1/2"XO, ID =2.950" 6806' 3-1/7' HES X NP, ID= 2.813" 6826' 3-112" HES X NP, ID= 2.813" 6838' -~3-1/7' WLEG, ID= 2.905" -~~MDTTNOT LOGGED 6892' T' 26# X 20' PUP JT W/ RA TAG I T' 26# X 20' PUP JT W/ RA TAG 1 ~ PBTD h 7505' 7" CSG, 26#, L-80, ID = 6.276" 7589' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/02 ORIGINAL COMPLETION 03/12/02 CH/TP CORRECTIONS 03/16!02 MH/tlh GLV UPDATE 03122!02 CWSMK ADPERFS 06/06/02 RL/tlh GLV UPDATE 04/08/03 DRSlfP TVD/MD CORRECTIONS BOREALIS UNIT WELL: L-111 P62MIT No: 2020300 API No: 50-029-23069-00 SEC 34, T12N, R11 E 2339' NSL & 3873' WEL BP Exploration (Alaska) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc f A ýJ ^~\j<-{ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 S rLJ~ ?vI F~ -Œc ~ API NOo: 50-029-23069-00-00 NC BP EXPLORATION (ALASKA) Operator Well Name/No. PRUDHOE BAY UN BORE L-111 2020300 Permit to Dri WAGIN Current Status 1-01L Completion Status ..... 3/6/2002 Completion Date --- 7198 TVD .-- 7605 MD REQUIRED INFORMATION Yes Master Well Data Maint Directional Survey (data taken from Logs Portion of No Samples No Mud Log DATA INFORMATION Types Electric or Other Logs Run Well Log Information ) Electr Dataset Number Log/ Data Type Log Comments Received 4/19/2002 4/19/2002 4/19/2002 3/15/2002 4/19/2002 OH CH Case Case Case Open Case Interval Stop 7480 7480 7480 7605 7480 Start 2000 2000 2000 110 2000 Run No 1 1 1 4 Log Log Scale Media ~ - 5 Col Col Col Col 5 5 5 L-tó704 Log Well Cores/Samples Digital Med/Frmt Log Log ~C Comments Sample Set Number Received Sent Interval Stop nformation cYJN VN Start Name ADDITIONAL INFORMATION Welí Cored? Y /~ ) Daily History Received? Formation Tops ~ ~ Chips Received? Analysis Received? Date: Comments: Compliance Reviewed By: ~ ,........... ~- 1. Operations performed: Operation shutdown_ Stimulate - Plugging _ Perforate - Pre-Prod Converted to WAG Inj Pull tubing Alter casing _ Repair well _ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _ RKB 76 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchoraqe, AK 99519-6612 Service X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2941' FNL, 3873' FEL, Sec. 34, T12N, R11 E, UM (asp's 583044, 5978059) L-111 At top of productive interval 9. Permit number / approval number 3252' FNL, 4242' FEL, Sec. 34, T12N, R11 E, UM (asp's 582679, 5977743) 202-030 At effective depth 10. API number 3237' FNL, 4149' FEL, Sec. 34, T12N, R11 E, UM (asp's 582772, 5977759) 50-029-23069-00 At total depth 11. Field / Pool 3235' FNL, 4133' FEL, Sec. 34, T12N, R11 E, UM (asp's 582788, 5977761) Prudhoe Bay Field / Bore~js..po.9J 12. Present well condition summary #( r,~ K f: ¡: \!,}" Ln R,., ~'-'-' Total depth: measured 7605 feet Plugs (measured) true vertical 7198 feet .' .. 'J Effective depth: measured 7505 feet Junk (measured) ~Ias¡ca OiJ 25 ¡;¡,,~ true vertical 7100 feet " \,{;j~j, vLH:iUÌíS~ílh -.> Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 107' 20" 260 sx Arctic Set (Approx 135' 135' Surface 2894' 9-5/8" 544 sx AS III Lite, 293 2922' 2631' sx Class 'G' Production 7565' 7" 474 sx Class 'G' 7589' 7183' Perforation depth: measured Open Perfs 4546'-4586',4616'-4636',4660'-4673', 4719'-4729', 4768'-4805', 4832'-4852', 7014'-7038',7047'-7052',7070'-7078' true vertical Open Perfs 4240'-4279', 4309'-4328', 4352'-4365', 4410'-4420', 4459'-4495', 4522'-4541', 6617'-6640',6649'-6654',6672'-6680' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4375'.4-1/2" XO 3-1/2" TBG @ 4375'.3-1/2" 9.2# L-80 TBG @ 6778' 3-1/2" XO 4-1/2" TBG @ 6778'.4-1/2" 12.6# L-80 TBG @ 6786'.4-1/2" XO 3-1/2"TBG @ 6786'. 3-1/2" 9.2# L-80 TBG @ 6838'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4319' MD. T' x 4-1/2" Baker S-3 Packer @ 6780' MD. 4-1/2" HES 'X' Nipple @ 2266'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas·Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 06/28/2002 9333 1344 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil Gas Suspended Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ::t~ÞfJ~ Title: Technical Assistant Date Julv 02. 2002 Prepared bv DeWavne R. Schnorr 564-5174 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Form 10-404 Rev 06/15/88 . ~ l~ SUBMIT IN DUPLlCA~ ;~ ~ ~ L-111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/05/2002 SBHPS: LOAD WELL TO SECURE 06/05/2002 SBHPS: DRIFT/TAG; GAS LIFT--TO DUMMY VALVES 06/06/2002 SBHPS: GAS LIFT--TO DUMMY VALVES 06/08/2002 WATER INJECTION STARTED. 06/11/2002 NEW WELL SUPPORT: AC-BLEED; AC-MITIA 06/13/2002 NEW WELL SUPPORT: AC-MITIA EVENT SUMMARY 06/05/02 PUMP 57 BBLS OF DIESEL DOWN THE INNER ANNULUS FOR FREEZE PROTECTION. 06/05/02 START RIGGING UP TO DRIFT AND DUMMY OFF, JOB IN PROGRESS 06/06/02 SET 41/2" XN CS, PULL STA 3 - 4 SET 1" DGLV'S STA 3 - 4 BK LATCH'S FOR CONVERSION. PULL CS RDMO. «< NOTIFY DSO OF WELL STATUS »>. 06/08/02 WATER INJECTION STARTED. 06/11/02 MIT-IA PASSED TO 3000 PSI. (Pre-AOGCC) 06/13/02 MIT-IA PASSED TO 2480 PSI (AOGCC Witnessed) BBLS 0 PRESSURE TEST LUBRICATOR W/ 1 BBL OF DIESEL, (0 TESTS) 57 DIESEL 57 TOTAL FLUIDS PUMPED Page 1 ~ .. ~ ~ 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate - Pre-Prod Converted to WAG Inj Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _ RKB 76 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchoraqe, AK 99519-6612 Service X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2941' FNL, 3873' FEL, Sec. 34, T12N, R11E, UM (asp's 583044, 5978059) L-111 At top of productive interval 9. Permit number / approval number 3252' FNL, 4242' FEL, Sec. 34, T12N, R11 E, UM (asp's 582679, 5977743) 202-030 At effective depth 10. API number 3237' FNL, 4149' FEL, Sec. 34, T12N, R11E, UM (asp's 582772, 5977759) 50-029-23069-00 At total depth 11. Field / Pool 3235' FNL, 4133' FEL, Sec. 34, T12N, R11E, UM (asp's 582788,5977761) Prudhoe Bay Field / Borealis Pool 12. Present well condition summary ~.: r I: I \1 F D Total depth: measured 7605 feet Plugs (measured) ILl<L. '" ""'. true vertical 7198 feet PU 7 ~ qnn? Effective depth: measured 7505 feet Junk (measured) ~;"'-".~ \.) ~ Lwùz.- true vertical 7100 feet Alaska on & Gas Cons. Commission Casing Length Size Cemented Measured ~ß\WoraQÐ True Vertical Depth Conductor 107' 20" 260 sx Arctic Set (Appro x 135' 135' Surface 2894' 9-5/8" 544 sx AS III Lite, 293 2922' 2631' sx Class 'G' Production 7565' 7" 474 sx Class 'G' 7589' 7183' Perforation depth: measured Open Perfs 4546'-4586',4616'-4636',4660'-4673', 4719'-4729', 4768'-4805', 4832'-4852', 7014'-7038',7047'-7052',7070'-7078' true vertical Open Perfs 4240'-4279', 4309'-4328', 4352'-4365', 4410'-4420',4459'-4495', 4522'-4541', 6617'-6640',6649'-6654',6672'-6680' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4375'.4-1/2" XO 3-1/2" TBG @ 4375'.3-1/2" 9.2# L-80 TBG @ 6778' 3-1/2" XO 4-1/2" TBG @ 6778'.4-1/2" 12.6# L-80 TBG @ 6786'.4-1/2" XO 3-1/2"TBG @ 6786'. 3-1/2" 9.2# L-80 TBG @ 6838'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4319' MD. T' x 4-1/2" Baker S-3 Packer @ 6780' MD. 4-1/2" HES 'X' Nipple @ 2266'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaqe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 06/28/2002 9333 1344 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil Gas Suspended Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~..;i"f>"-' øt:J~ TiU, Mo'œl,-",,,e", Date Julv 02. 2002 DeWavne R. Schnorr Prepared bv DeWavne R. Schnorr 564-5174 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Form 10-404 Rev 06/15/88 . SUBMIT IN DUPLICATE ~ 07 ~ ,-..." L-111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/05/2002 SBHPS: LOAD WELL TO SECURE 06/05/2002 SBHPS: DRIFT/TAG; GAS LIFT--TO DUMMY VALVES 06/06/2002 SBHPS: GAS LIFT--TO DUMMY VALVES 06/08/2002 WATER INJECTION STARTED. 06/11/2002 NEW WELL SUPPORT: AC-BLEED; AC-MITIA 06/13/2002 NEW WELL SUPPORT: AC-MITIA EVENT SUMMARY 06/05/02 PUMP 57 BBLS OF DIESEL DOWN THE INNER ANNULUS FOR FREEZE PROTECTION. 06/05/02 START RIGGING UP TO DRIFT AND DUMMY OFF, JOB IN PROGRESS 06/06/02 SET 41/2" XN CS, PULL STA 3 - 4 SET 1" DGLV'S STA 3 - 4 BK LATCH'S FOR CONVERSION. PULL CS RDMO. «< NOTIFY DSO OF WELL STATUS »>. 06/08/02 WATER INJECTION STARTED. 06/11/02 MIT-IA PASSED TO 3000 PSI. (Pre-AOGCC) 06/13/02 MIT-IA PASSED TO 2480 PSI (AOGCC Witnessed) BBLS 0 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (0 TESTS) 57 DIESEL 57 TOTAL FLUIDS PUMPED Page 1 ,..--...., ,,-. 1. Operations performed: Operation shutdown_ Stimulate - Plugging _ Perforate - Pre-Prod Converted to WAG Inj Pull tubing Alter casing _ Repair well_ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _ RKB 76 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchoraae, AK 99519-6612 Service X Prudhoe Bav Unit 4. Location of well at surface 8. Well number 2941' FNL, 3873' FEL, Sec. 34, T12N, R11 E, UM (asp's 583044, 5978059) L-111 At top of productive interval 9. Permit number 1 approval number 3252' FNL, 4242' FEL, Sec. 34, T12N, R11 E, UM (asp's 582679, 5977743) 202-030 At effective depth 10. API number 3237' FNL, 4149' FEL, Sec. 34, T12N, R11 E, UM (asp's 582772, 5977759) 50-029-23069-00 At total depth 11. Field 1 Pool 3235' FNL, 4133' FEL, Sec. 34, T12N, R11 E, UM (asp's 582788, 5977761) Prudhoe Bay Field / Borealis Pool 12. Present well condition summary Total depth: measured 7605 feet Plugs (measured) true vertical 7198 feet RECEIVED Effective depth: measured 7505 feet Junk (measured) true vertical 7100 feet JUL 3 2002 Casing Length Size Cemented Measured~ Oil & Gas~fté(IUtiRßh~ Conductor 107' 20" 260 sx Arctic Set (Approx 135' Anchora(Je135' Surface 2894' 9-5/8" 544 sx AS III Lite, 293 2922' 2631' sx Class 'G' Production 7565' 7" 474 sx Class 'G' 7589' 7183' Perforation depth: measured Open Perfs 4546'-4586',4616'-4636',4660'-4673', 4719'-4729', 4768'-4805', 4832'-4852', 7014'-7038',7047'-7052',7070'-7078' true vertical Open Perfs 4240'-4279', 4309'-4328', 4352'-4365', 4410'-4420', 4459'-4495', 4522'-4541', 6617'-6640',6649'-6654',6672'-6680' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4375'.4-1/2" XO 3-1/2" TBG @ 4375'. 3-1/2" 9.2# L-80 TBG @ 6778' 3-1/2" XO 4-1/2" TBG @ 6778'.4-1/2" 12.6# L-80 TBG @ 6786'.4-1/2" XO 3-1/2"TBG @ 6786'. 3-1/2" 9.2# L-80 TBG @ 6838'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4319' MD. 7" x 4-1/2" Baker S-3 Packer @ 6780' MD. 4-1/2" HES 'X' Nipple @ 2266'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mc! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 06/28/2002 9333 1344 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil Gas Suspended Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,/i}..)?!.~ ~~ T", T,clm'œ'^"".oI Date Julv 02. 2002 DeWavne R. Schnorr Prepared bv DeWavne R. Schnorr 564·5174 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .,;} Form 10-404 Rev 06/15/88 . nBDMS 8Ft SUBMIT IN DUPLICATE ~ JUL 8 2002 .~ A 06/05/2002 06/05/2002 06/06/2002 06/08/2002 06/11/2002 06/13/2002 L-111 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SBHPS: LOAD WELL TO SECURE SBHPS: DRIFT/TAG; GAS LIFTnTO DUMMY VALVES SBHPS: GAS LIFTnTO DUMMY VALVES WATER INJECTION STARTED. NEW WELL SUPPORT: AC-BLEED; AC-MITIA NEW WELL SUPPORT: AC-MITIA .... EVENT SUMMARY 06/05/02 PUMP 57 BBLS OF DIESEL DOWN THE INNER ANNULUS FOR FREEZE PROTECTION. 06/05/02 START RIGGING UP TO DRIFT AND DUMMY OFF, JOB IN PROGRESS 06/06/02 SET 41/2" XN CS, PULL STA 3 - 4 SET 1" DGLV'S STA 3 - 4 BK LATCH'S FOR CONVERSION. PULL CS RDMO. «< NOTIFY DSO OF WELL STATUS »>. 06/08/02 WATER INJECTION STARTED. 06/11/02 MIT-IA PASSED TO 3000 PSI. (Pre-AOGCC) 06/13/02 MIT-IA PASSED TO 2480 PSI (AOGCC Witnessed) BBLS 0 PRESSURE TEST LUBRICATOR W/ 1 BBL OF DIESEL, (0 TESTS) 57 DIESEL 57 TOTAL FLUIDS PUMPED Page 1 ~~; f' TREE = 4-1/16" CWV WELLHEAD = FrIIC SAFETY NOTES: GLM '5 @ STA #1 & #2 AClUA TOR = NA L-111 ARE 3-1/2" X 1-1/2" M MG-W'S, WHICH KB. 8.B' = 76.4' ARE WATERFLOOD MANIRELS. BF. 8.EV - 52.02' KOP= 800' -f 974' H 9-518" TA M PORT COLLAR I Max Angle :, 40 @ 1595' Datum M) = 4-1/2" HES X NIP, ID = 3.813" I Datum lVD = 8800' SS . I 2266' I 9-5/8" CSG, 40#, L-80, ID = 8.835" 2922' P ~ GAS LIFT Mð.NDR8.S I ST MD lVD DEV TYPE VLV LATCH FDRT DATE LJ 4 3842 3465 3 KBG-2 DMY BK-5 0 03/06/02 3 4199 3820 8 KBG-2 DMY BK-5 0 06/06/02 WA lERFLOOD MANIRELS Minimum ID = 2.813" @ 6768" ST MD lVD DEV TYPE VLV LATCH FDRT DATE 3-1/2" HES X NIPPLE 2 4418 4037 8 MMG-W RKBJ RKP 0 03/06/02 1 4478 4097 8 MMG-W RKBJ RKP 0 03/06/02 I I 4308' 4-1/2' Hffi X NP, ID - 3.813" I :8 ~ 4319' U T' X4-112" BKRPREMERPKR, ID- 3.910" I I 4-1/2' lBG,12.6#, L-BO, .0152 bpf, D =3.958" H 4375' 4377' 4-112' X 3·1/2" XO,ID = 2.992" D 3-1/2' TBG, 9.2#, L-80, .0087 bpf, ID = 2.992' I PffiFORATION SUMll1ARY REF LOG: TCP ÆRF ANGLEA TTOPPffiF: 10 @ 4546' -f 5243' H 7' TAM FDRT COLLAR I Note: Refer to Production DB for historcal perf data SIZE SPF INTffiV AL Oon/Saz [\1\ lE 4-5/8" 5 4546 - 4586 0 03104102 4-5/8" 5 4616 - 4636 0 03104102 I 6768' 3-1/2' Hffi X NP, ID= 2.813" I 4-5/8" 5 4660 - 4673 0 03104102 I 4-5/8" 5 4719-4729 0 03104102 ---t 6778' 3-1/2' X 4-1/2" XO,ID = 2.950" ~ 4-5/8" 5 4768 - 4B05 0 03104102 g( I 6780' L 7' X4-112" BKRS-3PKR,ID -3.875" I 4-5/8" 5 4832 - 4852 0 03104102 )ð 2-1/2' 6 7014 - 7038 0 03122/02 I 6786' 4-112' X 3-1/2" XO,ID - 2.950" 2-1/2' 6 7047 - 7052 0 03122/02 I 6806' 3-1/2' Hffi X NP, ID = 2.813" I 2-1/2' 6 7070 - 7078 0 03122/02 I I I 6826' 3-1/2' Hffi X NP, ID = 2.813" I I I 3-1/2"TBG, 9.2#, L-BO, .0087 bpf,lD =2.992" 683T I I 6838' 3-1/2' WLEG, ID = 2.905" I H 8.MD TT NOT LOGGED I 6892' T' 26#X20'PUPJTW/RA TAG I I 7362' T' 26# X 20' PUP JTW/ RA TAG I I RnD 7505' -I 7" CSG, 26#, L-BO, .0383 bpf, ID = 6.276" 7589' I [\1\ lE RB' BY COrvTv1ENTS DATE REV BY COMrvENTS GPB BOREALIS 03106102 ORlGINA.L COMPLETON WELL: L-111 03112102 CH/TP CORRECTIONS PffiMT No: 202-0300 03116102 MH/th GLV UPDATE AA No: 50-029-23069-00 03122102 CWS/KK A [PERFS SEC 34, T12N, R11E 2339' NSL & 3873' W8. 06106102 RUth GLV UPDATE BP Exploration (Alas ka) ~ ~ ilJ64- 7/1(02- :!IF -¡(f(pv I7TS 7/7/0 L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend_ Alter casing _ Repair well_ Change approved program 1. Type of request: Pre-Producer Converted to Inject 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora e, AK 99519-6612 4. Location of well at surface 2941' FNL, 3873' FEL, Sec. 34, T12N, R11E, UM At top of productive interval 3252' FNL, 4242' FEL, SEC 34, T12N, R11 E, UM At effective depth 3237' FNL, 4149' FEL, Sec. 34, T12N, R11E, UM At total depth 3235' FNL, 4133' FEL, Sec 34 T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 107' 20" Surface 2894' 9-5/8" Production 7565' 7" Operational shutdown _ Plugging _ Pull tubing 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X (asp's 583044, 5978059) (asp's 582679, 5977743) (asp's 582772, 5977759) (asp's 582788, 5977761) 7605 feet 7198 feet 7505 feet 7100 feet Cemented 260 sx ArcticSet (Approx) 544 sx AS III Lite, 293 sx Class 'G' 474 sx Class 'G' Plugs (measured) Junk (measured) Re-enter suspended well _ Pre-Producer Converted Time extension Stimulate to Injector Variance Perforate Other X 6. Datum elevation (DF or KB feet) RKB 76.2 feet 7. Unit or Property name Prudhoe Ba Unit 8. Well number L-111 9. Permit number / approval number 202-030 10. API number 50-029-23069-00 11. Field / Pool Prudhoe Ba Field / JUL 3 2002 Alaska Oil & Gas Cons. t;omm¡SSIOI Anchoraoe True vertical Depth 135' Measured Depth 135' 2922' 7589' 2631' 7183' Perforation depth: measured Open Perfs 4546'-4586',4616'-4636',4660'-4673', 4719'-4729', 4768'-4805', 4832'-4852', 7014'-7038', 7047'-7052', 7070'-7078' true vertical Open Perfs 4240'-4279', 4309'-4328', 4352'-4365', 4410'-4420', 4459'-4495', 4522'-4541', 6617'-6640', 6649'-6654', 6672'-6680' Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 4375'.4-1/2" XO 3-1/2" TBG @ 4375'.3-1/2" 9.2# L-80 TBG @ 6778'. 3-1/2" XO 4-1/2" tbg @ 6778'. 4-1/2" 12.6# L-80 TBG @ 6786'. 4-1/2" XO 3-1/2" TBG @ 6786'. 3-1/2" 9.2# L-80 TBG @ 6838'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4319' MD. 7" x 4-1/2" Baker S-3 Packer @ 6780' MD. 4-1/2" HES 'X' Nipple @ 2266'. 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for comm . g operation 15. Status of well classification as: Ju e 4, 002 16. If proposal was verbally ved / Oil Gas Suspended _ Tom Maunder 31-May-02 Name of approver Date approved Service WAG INJECTOR 17. I hereby certify that the foregoing is tnynd :rect to the best of my knowledge. Questions? Call Bruce W. Smith @ 564-5093. Signed ~ V / ~ Title: Borealis Development Petroleum Engineer Date June 04. 2002 Bruce W. Smith Pre ared b DeWa ne R. Schnorr 564·5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ Bo/ Test _ Location clearance ,. I ZL Mechanical Integrity Test ¥ Subsequent form required 10- ~()T Approved by order of the Commission Form 10-403 Rev 06/15/88 . OrIginal Signed By Cammy Oechsli TaylO!' Approval no. ~o \) -~ÔI Commissioner Date SUBMIT IN TRIPLICATE .~ ~, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylolìý\ Chairman THRU: Tom Maunder ~\() 1V\l1 P.I. Supervisor (l"Y' G Á)"':) FROM: Chuck Scheve (:p Petroleum Inspector NON- CONFIDENTIAL DATE: June 13, 2002 SUBJECT: Mechanical Integrity Tests BPX L Pad PBU Borealis Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING I P I P I P Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs L Pad and witnessed the initial MIT on wells L-III ,L-115and L-117. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. MIT PBU L Pad 6-13-02 CS1.xls 6/20/2002 bp /"".. ./"". ~..- ~.,..... --,~ ~...-- ·'.'4\~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 04, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for L-111 Conversion from Pre-Produced Injector to WAG Injector BP Exploration Alaska, Inc. proposes to convert well L-111 from a pre-produced injection well to an active injector (both water and MI (WAG flood)) as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: S DfT, Dummy off GL Design, Run Static Survey. MITIA to 4000 psig. Slickline Work: 1. Drift and tag to at least 7100' MD, to verify access to perfs. 2. DGLVs 3. Obtain SBHPS stop counts at: 7176' - 40-min, 7075' - 20/30min, 6972' - 20m in. MITIA to 4000 psig. Last test: Max Deviation: Top Perf deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S value: Well bore Fluids: BHT & BHP: Reference Log: 05/13/02 1622 BOPD, 1240 Mscfpd 400 @ 1595' MD 10° @ 4546' MD 2.813"X nipple @ 6768', 6806' & 6826' MD Perf job 3/22/02 7501' MD Perf Job 3/22/02 o ppm 4/9/02. Freeze protected tubing & IA to 2200' with diesel. L-111 i 158°F & 2800 psia @ 6600' TVDSS Schlumberger MWD Log 02/27/02 Note: Simops on CloinCl Construction. drillinCl. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW@BP.com ~ ~. .~ Sincerely, ø~ ../-d;;M.J. Bruce W. Smith GPB Borealis Development Engineer ~~. ~. " 1REE = 4-1/16" CIW WELLHEAD = Ftv'C L-111 SAFETY NOTES: GLM'S @ STA #1 & #2 ACTIJA TOR = NA ARE 3-1/2" X 1-1/2" M MG-W'S, WHICH KB. 8..BI = 76.4' ARE WATERA.OODMANmELS. BF. 8..EV = 52.02' KOP= 800' -I 974' H 9-518" TA M PORT COLLAR I r./ax Angle = 40 @ 1595' D3tum rvD = 4-1/2" f-ES X NP, ID = 3.813" I D3tum lV D = 8800'SS I 2266' I 9-5/8" CSG, 40#, L-80, ID = 8.835' 2922' ~ ~ GAS LIFT M\Næ8..S L ST MD lVD ŒV lYPE VLV LATCH FDRr DATE 4 3842 3465 3 KBG-2 DMY BK-5 0 03/06/02 3 4199 3820 8 KBG-2 DMY BK-5 0 06/06102 WA lERFLOOD MANæELS Minimum ID = 2.813" @ 6768" ST MD lVD ŒV lYPE VLV LATCH FDRr DATE 3-1/2" HES X NIPPLE 2 4418 4037 8 Mtv'G-W RKED RKP 0 03/06/02 1 4478 4097 8 Mtv'G-W RKED RKP 0 03/06/02 I I 4308' 4-112" HEB X NP, ID = 3.813" I ~ ~ 4319' LJ T' X4-112" BKRPREMERPKR, ID= 3.910" I I 4-1/2" lBG, 12.6#, L-BO, .0152 bpf, D = 3.958" H 4375' I 4377' 4-1/2" X 3-112" XO, ID - 2.992" 0 I 3-112" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I PERFORATION SUrvMARY RB" LOG: TCP ÆRF ANGLEATTOPPERF: 10 @ 4546' I -I 5243' H T' TAM FDRr COLLAR I Note: Pefer to Production DB for historical perf data SIZE SPF INTERV AL OpnlSqz Oð.lE 4-5/8" 5 4546 - 4586 0 03104102 4-5/8" 5 4616 - 4636 0 03104102 I 6768' 3-1/2" HEB X NP, ID = 2.813" I I 4-5/8" 5 4660 - 4673 0 03104102 ---t 4-518" 5 4719-4729 0 03104102 6778' 3-1/2" X4-1/2"XO, ID =2.950" - 4-5/8" 5 4768 - 4805 0 03104102 8( 6780' LJ T' X 4-112" BKR S-3 PKR, ID - 3.875" I 4-5/8" 5 4832 - 4852 0 03104102 ø 2-112" 6 7014 - 7038 0 03122102 6786' 4-112" X 3-1/2" XO, ID = 2.950" 2-1/2" 6 7047 - 7052 0 03122102 I 6806' 3-1/2" HES X NP, ID = 2.813" I 2-1/2" 6 7070 - 7078 0 03122102 I . - 6826' 3-1/2" HES X NP, ID = 2.813" I I 3-112" TBG, 9.2#, L-BO, .0087 bpf, ID = 2.992" 6837' ¡ 6838' 3-1/2" WLEG, ID = 2.905" I H 8..MD TT NOT LOGGED I 6892' T'26#X20'PLPJTW/RATAG I I 7362' T' 26# X 20' PLP JTWI RA TAG I I R3TD 7505' I 7" CSG, 26#, L-BO, .0383 bpf, ID = 6.276" 7589' Oð.lE RBI BY COrvMß\JTS DATE REV BY COMrvENTS GPB BOREALIS 03l06A12 ORIGINAL COMPLEfON WELL: L-111 03112102 CHI1P CORRECllONS PERMT f\b: 202-0300 03116102 MHlth GLV LPDATE AA No: 50-029-23069-00 03122102 CWSIKK AIFERFS SEC34, T12N, R11E 2339' NSL & 3873'W8.. 06106102 RUth GLV LPDATE BP Exploration (Alaska) .~ ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service . ~.. , 2. Name of Operator 1 7. Permit Number BP Exploration (Alaska) Inc. 1_ 'X'" 7:" I: 202-030 3. Address ," . 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1~~~~~; 50-029-23069-00 4. Location of well at surface ,":::-"~'-'":''-~''' 9. Unit or Lease Name 2339' NSL, 3874' WEL, SEC. 34, T12N, R11E, UM I W""PLr:r!PN ' A f d . . í< . -Ju·i¡.il;;'[~.: " ..J Prudhoe Bay Unit t top 0 pro uctlve Interval ¡ ....L.....~ '6 L,-f 2027' NSL, 4242' WEL, SEC. 34, T12N, R11 E, UM ! ---; 10. Well Number At total depth . \!ERIJ7af · 2044' NSL, 4133'WEL, SEC. 34, T12N, R11E, UM : -Æ~I . 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Borealis Pool RKB ::;; 76.2' ADL 028239 (Undefined) 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 2/21/2002 2/27/2002 3/6/2002 N/A MSL One 17. Total Depth (MD+ TVD) 118. Plug Back Depth (MD+ TVD) 119. Directional Survey 20. Depth where SSSV set 1 21. Thickness of Permafrost 7605 7198 FT 7505 7100 FTI 1m Yes 0 No (Nipple) 2266' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, USIT 23. CASING SIZE 20" 9-5/8" Classification of Service Well L·111i WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 107' 42" 1260 sx Arctic Set (ADDrox.) 28' 2922' 12-1/4" 544 sx Articset III Lite, 293 sx 'G' 24' 7589' 8-3/4" ~74 sx Class 'G' AMOUNT PULLED 7" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf MD TVD 4546' - 4586' 4240' - 4279' 4616' - 4636' 4309' - 4328' 4660' - 4673' 4352' - 4365' 4719' - 4729' 4410' - 4420' 4768' - 4805' 4459' - 4495' 4832' - 4852' 4522' - 4541 ' 2-1/2" Gun Diameter, 6 spf MD TVD '7014' - 7038' 6617' - 6640' 7047' - 7052' 6649' - 6654' . 7070' - 7078' 6672' - 6680' SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 6838' PACKER SET (MD) 4319' & 6780' 25. 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2300' Freeze Protect with 78 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 1 0, 2002 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BBL 4/28/2002 4 TEST PERIOD 1792 2180 0.0 Flow Tubing ¡vasing Pressure CALCULATED OIL-BSL GAs-McF WATER-BSL Press. 24-HoUR RATE 28. CORE DATA 1"'\ r" si'" r~ M ~ K IF'" _ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corelCÌililli ~ [T V [: U CHOKE SIZE I GAS-OIL RATIO 64 379 OIL GRAVITY-API (CORR) No core samples were taken. " r¡ 'ion? U 7 L,' t..¡.,. Alaska 011 & Gas Cons. CommiSSIon Anchorage Form 10-407 Rev. 07-01-80 I; L RBDMS 8FL MAY I 5 2002Submit In Duplicate G J'::: .~, 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Ugnu 3108' 2813' Schrader Bluff M 4152' 3849' Schrader Bluff N 4388' 4083' Schrader Bluff 0 4548' 4242' Base Schrader / Top Colville 5248' 4932' CM1 5991' 5633' HRZ 6627' 6239' Kalubik 6866' 6472' Kuparuk D 6990' 6593' Kuparuk C 7009' 6612' LCU / Kuparuk B 7186' 6786' Kuparuk A 7314' 6911' Base Kuparuk / Mileveach 7413' 7009' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys .~ 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. c , 6. r:::n¡rD· t~~"~,tij n n I'1n~\f) t) :/ ¿tdjc. Alaska 011 & Gas Cons. CommISSIOn Anchorage 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant L-111 i Well Number 202-030 Permit No. / A roval No. INSTRUCTIONS Date os~o9- Prepared By Name/Number: Terrie Hubble, 564-4628 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 (DF, 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 /""'. ~. 02/20/02 02/21/02 03/06/02 Nabors 9ES POST RIG WORK 03/22/02 COMPLETED JEWELRY LOG, IPERFS AND STATIC SURVEY. RIH W/ PSP, TAG TD @ 7507', LOG STATIC PRESSURES, LOGGED JEWELRY LOG OUT. RIH W/ 2.5" HSD 6 SPF (3 RUNS), PERFORATED 7014'-7038', 7047'-7052', 7070'-7078', POOH/ RUN BACK IN AND LOG POST PERF STATIC PRESSURES, POOH, RDMO, LEFT WELL SI. NOTIFY DSO OF STATUS AND DEPARTURE. 04/09/02 LOAD IA WITH 77 BBLS OF 1900 F CRUDE TO POP WELL. 12.23 (ppg) (psi) ,671 400 (psi 9.30 (ppg) 2,631.0 (ft) 2,922.0 (ft) LOT 2/24/2002 ) ) AM 0:15:51 3/12/2002 Printed: r--'. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-111 i L-111 i DRILL +COMPLETE NABORS NABORS 9ES Start: 2/21/2002 Rig Release: 3/6/2002 Rig Number: 9-ES Spud Date: 2/21/2002 End: 3/6/2002 Nipple up diverter system while slick line work on L 114. Move on L 111 / cont nipple up diverter system while slick line work on L 110 continues. 16:30 - 21 :30 SURF Relocate pit unit, move rig off L 115, move on L 111. Set matting boards, spot sub over well bore. 21 :30 - 00:00 SURF Connect service lines, spot cuttings tank, begin take water to pits. NABORS RIG 9-ES ACCEPTED THIS DATE 2/20/2002 1800 HRS 2/21/2002 00:00 - 02:30 2.50 DRILL P SURF Take on water, mix spud mud while complete nipple up diverter system. 02:30 - 06:00 3.50 DRILL P SURF Make up 12 1/4 bha, motor I mwd assy. 06:00 - 07:00 1.00 DRILL P SURF Test diverter system. Witness waived by John Spaulding AOGCC Pre - spud meeting all personnel. 07:00 - 08:00 1.00 DRILL P SURF Tag btm at 107 ft, commence spud well, 12114 hole 107 - 163 ft. 08:00 - 10:00 2.00 DRILL N DFAL SURF Pump press erratic, pull to surface for inspection. Layout mwd, make up new mwd. Test same, press normal. 10:00 - 00:00 14.00 DRILL P SURF Resume drill ahead 12 1/4 hole drctnl, 163 - 1750 ft. WOB 10,000, RPM 70, SPM 220, SPP 2400, GPM 650, TQ 6400 AST = 7.25 hrs, ART = 2.75 hrs Up 84, Dn 78, Rot 81 SPUD WELL 0700 HRS, 2/21/02 2/22/2002 00:00 - 02:30 2.50 DRILL P SURF Poh for bit, well bore good cond, normal drag, no loss I gains. 02:30 - 03:00 0.50 DRILL P SURF MU bit #2, C/O stab, test motor I mwd assy. 03:00 - 04:00 1.00 DRILL P SURF Flow check, rih, precaut wash 90ft to btm, no fill. 04:00 - 10:00 6.00 DRILL P SURF Resume drill ahead 12 1/4 hole, drctnl, 1750 - 2940 ft. Geologist confirms td. 10:00 - 11 :00 1.00 DRILL P SURF Circ I recip, shaker clean, normal cuttings volume. 11 :00 - 13:00 2.00 DRILL P SURF Flow check, poh to 598 ft. hole good condo 13:00 - 15:00 2.00 DRILL P SURF Rih, wash 90 ft to btm. No fill. 15:00 - 16:00 1.00 DRILL P SURF Flow check, circ / recip, clean returns. 16:00 - 17:00 1.00 DRILL P SURF Poh for 9 5/8 csg run. 17:00 - 19:30 2.50 DRILL P SURF Handle bha #2, layout motor I mwd assy. Std bk hwdp. 19:30 - 20:00 0.50 DRILL P SURF Clear floor drlg tools. 20:00 - 22:00 2.00 CASE P SURF RU for 9 5/8 csg, MU Franks circ tool, make dummy run 9 5/8 mandrel hgr. 22:00 - 00:00 2.00 CASE P SURF Assemble shoe track I float equip, fill and check floats. Follow with 9 5/8 40# BTC L80 csg. 2/23/2002 00:00 - 04:00 4.00 CASE P SURF Cont rih 9 5/8 csg, make up and land mandrel hgr. Csg to btm no problems. Well bore good condition. 04:00 - 08:00 4.00 CASE P SURF Rig up cmt hd, circ equip, circ I cond to specs. No loss I gains. Install hose on standpipe manifold to bypass around pinhole leak. 08:00 - 10:00 2.00 CASE P SURF Commence cmt 9 5/8 csg as follows: Pump 5 bbl CW 100 Test lines to 3500 psi, pump remaining 5 bbls CW 100. Pump 75 bbl Mudpush XL spacer 10.2 ppg. SD. Launch bottom plug. Printed: 3/12/2002 10:15:59 AM ~ /~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-111 i L-111 i DRILL +COMPLETE NABORS NABORS 9ES Start: 2/21/2002 Rig Release: 3/6/2002 Rig Number: 9-ES Spud Date: 2/21/2002 End: 3/6/2002 2/23/2002 08:00 - 10:00 2.00 CASE P SURF Pump 440 bbllead slurry (10.7 ppg, ASllllite at 6 bpm) Pump 57 bbl tail slurry (Class G, 15.8 ppg) Drop top plug, flush with 10 bbl H2O. Line up rig pump, displace with 205 bbl mud. Recip pipe until cmt started in annulus. Then started getting sticky. Land on ring. Bump plug correct displacement, FCP = 800 psi, build to 1300 psi and hold 5 min. Bleed and check floats. Floats holding. BUMP PLUG. CMT IN PLACE 10:05 HRS. RECOVER 205 BBLS CMT RETURNS @ SURFACE. 10:00 - 12:00 2.00 CASE P SURF Layout cmt equip, back out Idg jt, clear fllor. 12:00 - 14:30 2.50 CASE P SURF Nipple dn diverter assy. 14:30 - 16:00 1.50 CASE P SURF Clean out beneath RT with vac truck. 16:00 - 19:30 3.50 CASE P SURF Prepare and nipple up wellhead assembly. Test metal-metal seal to 1000 psi - OK. Nipple up bope, all related equip. 19:30 - 00:00 4.50 CASE P SURF Prepare and test bope as follows: Bop, choke mnfld, choke I kill lines 250 - 4000 5 min each test. Annular 250 - 3500 5 min. Floor and safety valves, standpipe to pumps 250 - 4000 5 min. Accumulator time I volume test. All tests successful, no re-tests. Witness waived by John Spaulding AOGCC 2/24/2002 00:00 - 06:30 6.50 DRILL P PROD1 Begin PU 4" dp in sgls from shed, stand bk in mast. 06:30 - 09:30 3.00 DRILL P PROD1 MU bha #3, load source LWD, function test same, MU remainer bha #3. 09:30 - 10:00 0.50 DRILL P PROD1 Pass thru Tam collar, test to 1000 psi. Test MWD. Test successful. 10:00-11:00 1.00 DRILL P PROD1 Resume rih bha #3. 11 :00 - 12:30 1.50 DRILL P PROD1 Slip / cut drlg line, service top drv, functiom COM 12:30 - 13:30 1.00 DRILL P PROD1 Follow bha with 4" dp to 2772 and tag float collar. 13:30 - 14:30 1.00 DRILL P PROD1 Test 9 5/8 csg 3000 psi / 30 min. Test good. 14:30 - 15:30 1.00 DRILL P PROD1 Drill cmt, float equip, and rat hole to 2940 ft. 15:30 - 16:00 0.50 DRILL P PROD1 Drill new fmtn 2940 - 2960 ft. 16:00 - 17:00 1.00 DRILL P PROD1 Flow check. Displace well to 9.3 ppg LSND drlg fluid. 17:00 - 17:30 0.50 DRILL P PROD1 Perform LOT. Results = 400 psi press, 12.22 EMW, 2631 ft TVD 17:30 - 00:00 6.50 DRILL P PROD1 Flow check. Commence drill ahead 8 3/4 hole drctnl, 2960 - 3991 ft. No loss I gains. WOB 15, RPM 55, SPP 2550, SPM 202, GPM 590, TQ 7100 Up 145, Dn 90, Rot 109 AST = 1.6 hrs, ART = 2.1 hrs 2/25/2002 00:00 - 04:00 4.00 DRILL P PROD1 Drill ahead 8 3/4 hole drctnl, 3991 - 4458 ft. 04:00 - 04:30 0.50 DRILL P PROD1 Circ sweep, prepare for wiper trip. 04:30 - 06:00 1.50 DRILL P PROD1 Flow check, poh to 9 5/8 shoe. Slight swabbing 3352 - 2920. 20K over pull. Recip I work free. 06:00 - 06:30 0.50 DRILL P PROD1 Service top drv, blocks, crown. 06:30 - 07:30 1.00 DRILL P PROD1 Flow check, rih, wash I ream 3170 - 3521 ft. Wash 90 ft to btm. No fill. 07:30 - 00:00 16.50 DRILL P PROD1 Resume drill ahead 8 3/4 hole drctnl, 4458 - 6140 ft. No loss / gains. WOB 15, RPM 55, SPP 2550, SPM 202, GPM 590, TQ Printed: 3/12/2002 10: 15:59 AM .~ ,,-....., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-111 i L-111 i DRILL +COMPLETE NABORS NABORS 9ES Start: 2/21/2002 Rig Release: 3/6/2002 Rig Number: 9-ES Spud Date: 2/21/2002 End: 3/6/2002 2/25/2002 07:30 - 00:00 16.50 DRILL P PROD1 7000 Up 162, Dn 117, Rot 135 AST = 6 hrs, ART = 9 hrs 2/26/2002 00:00 - 03:30 3.50 DRILL P PROD1 Cont dril ahead 8 3/4 hole drctnl 6140 - 6514 ft. 03:30 - 05:00 1.50 DRILL P PROD1 Circ hi vis sweep, wt up to 10.1 ppg, shaker clean, normal cuttings return. 05:00 - 05:30 0.50 DRILL P PROD1 Pump wt pill , blow dn top drive. 05:30 - 07:00 1.50 DRILL P PROD1 Flow check, poh wiper trip to 9 5/8 csg shoe. Well bore good condo Intermittent drag to 35 near shoe. 07:00 - 07:30 0.50 DRILL P PROD1 Service top drive, blocks, crown. 07:30 - 11 :00 3.50 DRILL P PROD1 Flow check, rih, precaut wash 90 ft to btm. No fill. No obstructions. 11 :00 - 00:00 13.00 DRILL P PROD1 Resume drill ahead 8 3/4 hole drctnl6514 - 7448 ft. No loss I gains. Connections free. WOB 15, RPM 60, SPP 3425, SPM 180, GPM 525, TQ 9000 Up 198, Dn 134, Rot 158 AST = 0 hrs, ART = 13.53 hrs 2/27/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Drill f/7448' to 7605'. TD called by geologist. PUW: 198k; SOW: 134k; ROT: 162k. 01 :30 - 02:30 1.00 DRILL P PROD1 Circ sweep around. Condition fl wiper trip. 02:30 - 03:30 1.00 DRILL P PROD1 POH to 6214' (stds above old hole section. No problems. 03:30 - 04:30 1.00 DRILL P PROD1 RIH. Wash last stand to bottom. No fill. Hole in good shape. 04:30 - 05:30 1.00 DRILL P PROD1 Circ sweep around. Rotate & reciprocate. Cond for casing. 05:30 - 08:00 2.50 DRILL P PROD1 POH to HWDP. No problems. Monitor well-OK. 08:00 - 11 :00 3.00 DRILL P PROD1 Std back HWDP. LD DC's. Remove source. LD remaining BHA. Clean & clear floor. 11 :00 - 13:00 2.00 CASE P PROD1 Change to 7" rams. 13:00 - 13:30 0.50 CASE P PROD1 Test bop door seals 3500 psi. Test good. 13:30 - 14:00 0.50 CASE P PROD1 Place csg equip rig floor, rig up same for 7" csg run. 14:00 - 14:30 0.50 CASE P PROD1 PJSM, make up float equip / shoe track, test same. Floats good. 14:30 - 18:00 3.50 CASE P PROD1 Follow with 7" 26#, L-80, BTC Mod csg to 9 5/8 shoe. 18:00 - 18:30 0.50 CASE P PROD1 Circ 1.5 times csg volume at shoe. 18:30 - 00:00 5.50 CASE P PROD1 Resume rih 7" csg. (157 jts) Total loss = 8 bbls. 2/28/2002 00:00 - 01 :30 1.50 CASE P PROD1 Cont rih 7" csg, MU cmt hd, blow dn top drive. 01 :30 - 04:00 2.50 CASE P PROD1 Circ I cond mud for cmt. 100% returns, no circ losses. 04:00 - 06:30 2.50 CASE P PROD1 Cmt 7" csg as follows: Pump 5 bbls CW 100, test lines to 4000 psi, drop btm plug, pump 15 bbls CW 100 Pump 30 bbls Mudpush XL 11.5 ppg. Pump 42 bbls batch mixed slurry, GasBlok 15.8 ppg, Drop top plug, displace with 287 bbls mud. Bump plug with FCP 525 psi, build to 4000 psi. Bleed, floats holding. CMT IN PLACE, PLUG BUMPED 0600 HRS 06:30 - 07:00 0.50 CASE P PROD1 Rig dn csg run tools, clear floor. Back out Idg jt pup. 07:00 - 14:00 7.00 CASE P PROD1 MU Tam combo tool, rih on 4" dp to port collar at 5243 ft. Slow going with shifting tool. 14:00 -16:00 2.00 CASE P PROD1 Open port collar, circ annular volume at 6 bpm. Printed: 3/12/2002 10:15:59 AM ~. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-111 i L-111i DRILL +COMPLETE NABORS NABORS 9ES Start: 2/21/2002 Rig Release: 3/6/2002 Rig Number: 9-ES Spud Date: 2/21/2002 End: 3/6/2002 2/28/2002 16:00 - 17:00 1.00 CASE P PROD1 Cmt 2nd stage as follows: 10 bbls CW 100, test lines, 30 bbls CW100, 20 bbls Mudpush, 57 bbls 15.8 ppg slurry, displace with 56 bbls mud. 17:00 - 19:00 2.00 CASE P PROD1 Close Port Collar. Attempt to test. Unable to pressure up beyond -700 psi without breaking circ. Made several attempts to open & reclose tool, then test, with same results. Assumed upper cups were bad, as it would hold - 400 psi and this pressure could be bled off with no continuing backflow. Start circ excess cement from DP and annulus. Cmt returns to surface after 76 bbls. Cont circ all cmt & contaminated cement (-80 bbls) out of well. Cup failure at Tam shifting tool. Circ & condo 19:00 - 22:00 3.00 CASE P PROD1 POH, layout and re-dress Tam tool with lower cups only. Inspection shows all cups failed. 22:00 - 00:00 2.00 CASE N DFAL PROD1 Make up Howco "Champ" 7" pkr, spaced 30 ft above Tam tool for re-cmt 2nd stage. 3/1/2002 00:00 - 01 :00 1.00 CASE N DFAL PROD1 Lay dn Idg jt 01 :00 - 02:30 1.50 CASE N DFAL PROD1 Install 7" packoff, test to 5000 psi. Test good. 02:30 - 04:30 2.00 CASE N DFAL PROD1 Change to variable rams, test to 3500 psi. test good. 04:30 - 05:00 0.50 CASE N DFAL PROD1 Make up Tam tool I Howco Champ pkr combo for 2nd stage cmt job. 05:00 - 10:00 5.00 CASE N DFAL PROD1 Rih 4" dp to 5200 ft. 10:00 - 14:30 4.50 CASE N DFAL PROD1 Latch into port collar and open. Attempt pass below collar. Can not pass. PU out port collar, make up circ sub / top drive. Latch into port collar, open and pass below collar. Set pkr, verify port collar open. 14:30 - 15:30 1.00 CASE N DFAL PROD1 Attempt circ through port collar, no returns at annulus.Total 35 bbls. Attempt reverse circ, no returns. Total 25 bbls. 5 bpm @ 1500 psi both methods. 15:30 - 20:00 4.50 CASE N DFAL PROD1 Reduce mud wt to 9.1 ppg. 20:00 - 23:00 3.00 CASE N DFAL PROD1 Pump 80 bbls 9.1 ppg mud dn 7 X 9 5/8 annulus. No returns. 5 bpm @ 700 psi. Release pkr, attempt circ dn 4" dp to balance mud wts 4" dp X 7". No returns. Pkr packed off. Reverse circ dn 4 X 7 ann, work free, regain eirc, balance mud wts. Flow check. 23:00 - 00:00 1.00 CASE N DFAL PROD1 Attempt close port collar, work / rot / build torque. Can not slide collar sleeve. Continued effort close port collar. 3/2/2002 00:00 - 00:30 0.50 CASE N DFAL PROD1 Cont wash across Tam collar for latch up. 00:30 - 01 :30 1.00 CASE N DFAL PROD1 Multiple attempts closing port collar. Eventual latch up, can not release from collar. Cont effort, pull free. 01 :30 - 02:00 0.50 CASE N DFAL PROD1 Set pkr, test to 3000 psi, verify port collar closed. 02:00 - 05:00 3.00 CASE N DFAL PROD1 Poh slowly, Tam cups dragging with possible cmt pkf. 05:00 - 05:30 0.50 CASE N DFAL PROD1 Layout Tam tool I pkr assy. Discover cmt / rocks inside cups. 05:30 - 06:00 0.50 CASE N DFAL PROD1 Clear floor all unneeded tools. 06:00 - 06:30 0.50 CASE N DFAL PROD1 Service top drive. 06:30 - 07:30 1.00 CASE N DFAL PROD1 Place Schlum equip on floor, rig up same. 07:30 - 09:00 1.50 CASE N DFAL PROD1 PJSM. Make up USIT tools, calibrate, prepare for rih. 09:00 - 17:30 8.50 CASE N DFAL PROD1 Rih wireline to 5275' WLM, can not pass restriciton. Attempt to log up. Tool failed. Printed: 3/12/2002 10:15:59AM r-". r----.. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-111 i L-111 i DRILL +COMPLETE NABORS NABORS 9ES Start: 2/21/2002 Rig Release: 3/6/2002 Rig Number: 9-ES Spud Date: 2/21/2002 End: 3/6/2002 3/2/2002 09:00 - 17:30 8.50 CASE N DFAL PROD1 POH, lay dn USIT, make up gauge ring / junk bskt, rih to 5300 ft. Set down. POH. Had to work GRlJB through TAM collar. Hung up multiple times. POH. JB Full of jelled, contaminated mud. Some small pieces of hard cement. RIH wI GRlJB to 5225'. POH. Same recovery. 17:30 - 18:00 0.50 CASE N DFAL PROD1 Load shed with DCs I bha. 18:00 - 19:00 1.00 CASE N DFAL PROD1 Make up bit / scraper bha, rih same. 19:00 - 21 :00 2.00 CASE N DFAL PROD1 Follow with 4" dp to 4980 ft. 21 :00 - 23:30 2.50 CASE N DFAL PROD1 Begin wash to bit depth 5327 ft I scraper 5230 ft. Much returns cmt (Gelled and hardened) at surface. Cont circ / cond, clean well bore. Bulhead warm drlg mud dn 7 X 9 5/8 ann this time period also. 23:30 - 00:00 0.50 CASE N DFAL PROD1 Poh 4" dp, 5100 ft midnite depth. 3/3/2002 00:00 - 01 :30 1.50 CASE N DFAL PROD1 Cont poh 4" dp for USIT. 01 :30 - 02:30 1.00 CASE N DFAL PROD1 Handle bha, layout bit I scraper assy. 02:30 - 03:30 1.00 CASE P PROD1 Rig up Schlum equip, shallow test, "0" computer. 03:30 - 09:00 5.50 CASE P PROD1 Rih US IT wireline, log well from Tam collar (5243) to 2000 ft. Prelim results show cmt, Tam collar to 3950 ft. 09:00 - 10:00 1.00 CASE P PROD1 Layout Schlum equip, release unit. 10:00 - 13:30 3.50 CASE P PROD1 Prepare and test bope as follows: Blind I pipe rams, 250 I 4000 - 5 min Annular, 250 I 3500 - 5 min Choke I kill lines, all related valving, plumbing, 250/4000 - 5 min Standpipe / top drv, to pumps, 250/4000 - 5 min Floor valves, all safety equip, 250 / 4000 - 5 min Accumulator, time I volume I press test All tests successful, no re-tests. Witness waived by Chuck Sheavey AOGCC 13:30 -14:30 1.00 CASE P PROD1 Make up bit I hwdp / jar assy, rih same. 14:30 - 15:30 1.00 CASE P PROD1 Slip I cut drlg line. 15:30 - 18:00 2.50 CASE P PROD1 Rih 4" dp to 7480 ft. 18:00 - 21 :00 3.00 CASE P PROD1 Wash to 7" float collar at 7504 ft, circ btms up, pump hi vis sweep, displace well to 9.1 ppg brine. Perform LOT 7 X 8 3/4 annulus during this period. Results = 12.39 EMW 21 :00 - 22:00 1.00 CASE P PROD1 Test 7" csg to 4000 psi I 30 min. Test successful. Freeze protect annulus. 22:00 - 23:00 1.00 CASE P PROD1 Poh 4" dp to 4800 ft. 23:00 - 23:30 0.50 CASE P PROD1 Spot perf pill 4300 - 4800 ft. 23:30 - 00:00 0.50 CASE P PROD1 Resume poh 4" dp to 4000 ft, midnite depth. 3/4/2002 00:00 - 01 :00 1.00 CASE P PROD1 Cont poh 4" dp for USIT. 01 :00 - 01 :30 0.50 CASE P PROD1 Handle bha, layout jars. 01 :30 - 02:30 1.00 CASE P PROD1 Place Schlum equip on floor, rig up same. 02:30 - 06:00 3.50 CASE P PROD1 Rih wireline, bond log 7587 - 5000, repeat to 3500 ft. Poh wireline. 06:00 - 07:00 1.00 CASE P PROD1 Layout Schlum equip, clear floor. 07:00 - 07:30 0.50 CASE P PROD1 Service top drive I crown. 07:30 - 08:00 0.50 CASE P COMP PJSM, load perf guns to pipe shed. Inspect, record dimensions. 08:00 - 09:30 1.50 CASE P COMP PJSM, make up 4 5/8 HMX Millinium - 5 spf guns. Rih same. Printed: 3/12/2002 10:15:59 AM ,~ /~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-111 i L-111 i DRILL +COMPLETE NABORS NABORS 9ES Start: 2/21/2002 Rig Release: 3/6/2002 Rig Number: 9-ES Spud Date: 2/21/2002 End: 3/6/2002 3/4/2002 09:30 - 12:30 3.00 CASE P COMP Rih perf assy on 4" dp @ 1 min I std. to 4892 ft. 12:30 - 14:00 1.50 CASE P COMP Rig up Schlum, correlate perf depth, poh wireline, rig dn Schlum. 14:00 - 15:00 1.00 CASE P COMP Space out correct depth, guns at 4852 - 4546 ft. Press up, fire guns. Flow check 15 min. Note 2.5 bblloss. Well static. 15:00 - 16:30 1.50 CASE P COMP Circ pump wt pill, poh 4" dp. 16:30 - 17:00 0.50 CASE P COMP Flow check, stand bk hwdp. 17:00 - 18:30 1.50 CASE P COMP PJSM, inspect guns, all shots fired, no debris left in well. Lay out perf assy. 18:30 - 19:30 1.00 CASE P COMP Make up hwdp bha, rih same. 19:30 - 22:00 2.50 CASE P COMP Rih 4" dp to 7504 ft, scraper spaced at 5190 ft. 22:00 - 00:00 2.00 CASE P COMP Circ sweep, displace well with clean 8.9 ppg brine. 3/5/2002 00:00 - 01 :00 1.00 CLEAN P COMP Complete displacing wellbore to clean 8.9 ppg. brine. Monitor well - static. Pump slug. 01 :00 - 05:00 4.00 CLEAN P COMP POH UD 4" DP. 05:00 - 06:30 1.50 CLEAN P COMP UD HWDP, Jars, Boot baskets & Bit. Minimal debris recovered in junk baskets. Clear floor. 06:30 - 07:30 1.00 CLEAN P COMP PJSM. RlU HES slickline wI 6" guage ring. 07:30 - 09:30 2.00 CLEAN P COMP Make guage ring run to 7508'. 09:30 - 10:00 0.50 CLEAN P COMP RID HES slickline. 10:00 - 10:30 0.50 RUNCO COMP Drain stack, pull wear bushing. 10:30 - 13:00 2.50 RUNCO COMP Rig up to run completion tubing. Make dummy run wI Hanger and landing joint. 13:00 - 00:00 COMP Run completion string as per program; utilizing torque - turn on all TC II connections. 3/6/2002 00:00 - 01 :30 1.50 COMP Complete running completion tubing string. Total: 73 Jts 3.5" + 103 Jts 4.5". 01 :30 - 02:00 COMP MIU tbg. Hgr. & Landing Jt.- verify space out. 02:00 - 03:30 COMP Circulate & spot 8.9 ppg. corrosion inhibited brine in annulus. 03:30 - 06:30 COMP Land Hgr. R.I.L.D.S. Set "S-3" Pkr wI 2800 psi. Bleed off then set "Premier" Pkr wI 4200 psi Hold 4200 psi for 30 minute tubing test. Bleed tubing to 2000 psi. Pressure annulus to 4000 psi and hold for 30 minute test. Bleed tubing to shear DCK valve. Bleed all. 06:30 - 07:00 0.50 WHSUR P COMP Install TWC. Test to 2800 psi. 07:00 - 09:00 2.00 WHSUR P COMP NID BOPE. 09:00 - 12:00 3.00 WHSUR P COMP N/U Adapter Flange & Tree. Test both to 5000 psi. 12:00 - 13:00 1.00 WHSUR P COMP RlU DSM. Pull TWC. RID DSM. 13:00 - 16:00 3.00 WHSUR P COMP RlU Little Red. Test lines to 2500 psi. Reverse 78 bbls. Diesel. Allow to U - Tube to Freeze protect annulus to 2300'. 16:00 - 18:00 2.00 RIGD P COMP Install BPV. Test to 1000 psi. Blow down all lines. Complete cleaning pits & Cellar. Secure Tree. RIG RELEASED AT 18:00 HRS. Printed: 3/12/2002 10:15:59 AM C> ) ) -, ANADRILL SCHLUMBERGER Survey report 27-Feb-2002 03:57:44 Page 1 of 4 Client BP Exploration (Alaska) Inc. Field. Prudhoe Bay 1 Borealis Well. . L-111i Spud date............. ... 21-Feb-02 API number 50-029-23069-00 Last survey date......... 27-Feb-02 Engineer. . St. Amour Total accepted surveys. . . 83 MD of first survey.. ..... o . 00 ft COUNTY: . . . Nabors 9ES MD of last survey..... ... 7605.00 ft STATE: . . . . Alaska ----- Survey calculation methods------------- ----- Geomagnetic data -- ------------------ Method for positions.....: Minimum curvature Magnetic model....... ....: BGGM version 2001 Method for DLS...... .....: Mason & Taylor Magnetic date............: 21-Feb-2002 Magnetic field strength..: 1149.43 HCNT ----- Depth reference ----------------------- Magnetic dec (+E/W-) . . . . . : 2 6 .10 degrees Permanent datum.. .... ....: Mean Sea Level Magnetic dip.. ..... ......: 80.76 degrees Depth reference..... .....: Driller's Pipe Tally GL above permanent.... ...: 47.90 ft ----- MWD survey Reference Criteria --------- KB above permanent.... ...: N/A Reference G. .............: 1002.68 mGal DF above permanent.......: 76.20 ft Reference H. ..... ........: 1149.43 HCNT Reference Dip. ...........: 80.76 degrees ----- Vertical section origin---------------- Tolerance of G...... .....: (+1-) 2.50 mGal Latitude (+N/S-) . . . . . . . . . : 0.00 ft Tolerance of H..... ... ...: (+1-) 6.00 HCNT Departure (+E/W-) . . . . . . . . : 0.00 ft Tolerance of Dip....... ..: (+1-) 0.45 degrees ----- Platform reference point--------------- ----- Corrections --------------------------- Latitude (+N/S-) . . . . . . . . . : -999.25 ft Magnetic dec (+E/W-) . . . . . : 26.10 degrees Departure (+E/W-) . . . . . . . . : -999.25 ft Grid convergence (+E/W-). : 0.00 degrees Total az corr (+E/W-) . . . . : 26.10 degrees Azimuth from rotary table to target 260.00 degrees (Total az corr = magnetic dec - grid conv) Sag applied Y/N : No degree: 0.00 ) ) ANADRILL SCHLUMBERGER Survey Report 27-Feb-2002 03:57:44 Page 2 of 4 -------- ------ ------- -- ----- ---------------- ---- ----- --- -------- ------ ------- ---------------- Seq Measured Incl Az imu th Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (Ü) (deg) (deg) (Ü) (Ü) (Ü) (Ü) (Ü) (Ü) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 251.15 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 127.00 0.14 244.43 127.00 127.00 0.15 -0.07 -0.14 0.16 244.43 0.11 MWD_IFR_MSA 3 201. 88 0.57 218.06 74.88 201.88 0.51 -0.40 -0.45 0.60 228.52 0.60 MWD_IFR_MSA 4 293.33 1. 08 230.64 91. 45 293.32 1. 60 -1.30 -1. 40 1.91 227.00 0.59 MWD_IFR_MSA 5 385.54 2.07 233.89 92.21 385.49 3.86 -2.84 -3.42 4.44 230.29 1. 08 MWD_IFR_MSA 6 479.90 3.30 239.87 94.36 479.75 7.94 -5.20 -7.14 8.84 233.92 1. 34 MWD_IFR_MSA 7 570.63 4.90 244.52 90.73 570.24 14.12 -8.18 -12.90 15.28 237.61 1. 80 MWD_IFR_MSA 8 663.35 6.98 247.06 92.72 662.46 23.43 -12.08 -21. 66 24.80 240.85 2.26 MWD_IFR_MSA 9 755.48 9.37 250.18 92.13 753.65 36.28 -16.81 -33.88 37.82 243.61 2.64 MWD_IFR_MSA 10 846.44 11. 42 250.36 90.96 843.11 52.46 -22.35 -49.32 54.15 245.63 2.25 MWD_IFR_MSA 11 940.73 13.72 249.09 94.29 935.13 72.64 -29.48 -68.56 74.63 246.74 2.46 MWD_IFR_MSA 12 1034.33 17.81 251. 85 93.60 1025.19 97.72 -37.90 -92.55 100.01 247.73 4.44 MWD_IFR_MSA 13 1127.23 21. 43 253.29 92.90 1112.69 128.65 -47.21 -122.31 131.10 248.90 3.93 MWD_IFR_MSA 14 1220.86 26.53 252.97 93.63 1198.21 166.42 -58.26 -158.71 169.06 249.84 5.45 MWD_IFR_MSA 15 1314.52 29.47 252.35 93.66 1280.90 210.02 -71.37 -200.67 212.99 250.42 3.15 MWD_IFR_MSA 16 1406.99 32.87 251. 09 92 .47 1360.01 257.37 -86.41 -246.10 260.83 250.65 3.74 MWD_IFR_MSA 17 1500.03 38.75 248.26 93.04 1435.43 310.87 -105.39 -297.08 315.22 250.47 6.56 MWD_IFR_MSA 18 1594.60 40.23 249.84 94.57 1508.41 369.91 -126.88 -353.25 375.34 250.24 1. 89 MWD_IFR_MSA 19 1689.81 39.91 249.93 95.21 1581.27 430.25 -147.96 -410.80 436.63 250.19 0.34 MWD_IFR_MSA 20 1788.09 38.37 248.37 98.28 1657.50 491.17 -170.02 -468.77 498.65 250.06 1. 86 MWD_IFR_MSA 21 1882.43 39.27 249.02 94.34 1731. 00 549.16 -191.51 -523.87 557.78 249.92 1. 05 MWD_IFR_MSA 22 1976.17 40.13 249.38 93.74 1803.12 607.98 -212.77 -579.84 617 . 65 249.85 0.95 MWD_IFR_MSA 23 2070.06 39.99 249.75 93.89 1874.98 667.41 -233.87 -636.47 678 . 07 249.82 0.29 MWD_IFR_MSA 24 2163.41 37.43 250.70 93.35 1947.82 724.93 -253.63 -691.39 736.45 249.86 2.82 MWD_IFR_MSA 25 2254.67 34.08 250.27 91. 26 2021. 87 777 . 52 -271.43 -741.65 789.76 249.90 3.68 MWD_IFR_MSA 26 2347.59 30.37 249.96 92.92 2100.46 826.32 -288.27 -788.24 839.30 249.91 4.00 MWD_IFR_MSA 27 2440.58 26.58 249.80 92.99 2182.19 869.96 -303.52 -829.86 883.63 249.91 4.08 MWD_IFR_MSA 28 2535.14 24.38 250.57 94.56 2267.55 910.04 -317.32 -868.13 924.30 249.92 2.35 MWD_IFR_MSA 29 2627.49 24.35 251. 24 92.35 2351.67 947.66 -329.78 -904.13 962.40 249.96 0.30 MWD_IFR_MSA 30 2720.91 19.95 249.75 93.42 2438.18 982.39 -341.50 -937.33 997.60 249.98 4.75 MWD_IFR_MSA ') ) ANADRILL SCHLUMBERGER Survey Report 27-Feb-2002 03:57:44 Page 3 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degl tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2814.34 15.99 252.91 93.43 2527.03 1010.86 -350.80 -964.60 1026.41 250.02 4.36 MWD_IFR_MSA 32 2882.56 14.06 254.16 68.22 2592.92 1028.43 -355.82 -981.55 1044.06 250.07 2.87 MWD_IFR_MSA 33 2983.84 12.90 250.91 101. 28 2691.41 1051.83 -362.88 -1004.07 1067.64 250.13 1. 37 MWD_IFR_MSA 34 3077.00 12.90 249.52 93.16 2782.22 1072.33 -369.92 -1023.64 1088.43 250.13 0.33 MWD_IFR_MSA 35 3171.32 11.42 249.79 94.32 2874.42 1091.87 -376.83 -1042.27 1108.30 250.12 1. 57 MWD_IFR_MSA 36 3264.37 10.10 249.78 93.05 2965.83 1108.97 -382.83 -1058.57 1125.67 250.12 1.42 MWD_IFR_MSA 37 3358.11 8.40 251. 69 93.74 3058.35 1123.83 -387.82 -1072.79 1140.74 250.12 1. 84 MWD_IFR_MSA 38 3451.68 5.55 252.93 93.57 3151.22 1135.09 -391.30 -1083.60 1152.09 250.14 3.05 MWD_IFR_MSA 39 3544.12 1. 55 223.98 92.44 3243.47 1140.54 -393.51 -1088.75 1157.68 250.13 4.61 MWD_IFR_MSA 40 3637.33 2.90 111.09 93.21 3336.63 1139.54 -395.27 -1087.42 1157.03 250.02 4.06 MWD_IFR_MSA 41 3731.27 2.94 114.46 93.94 3430.45 1135.52 -397.12 -1083.01 1153.52 249.86 0.19 MWD_IFR_MSA 42 3824.18 3.06 112.85 92.91 3523.23 1131.47 -399.07 -1078.56 1150.02 249.70 0.16 MWD_IFR_MSA 43 3917.30 5.60 93.03 93.12 3616.08 1124.95 -400.28 -1071.73 1144.04 249.52 3.13 MWD_IFR_MSA 44 4010.29 5.69 91. 68 92.99 3708.62 1116.02 -400.65 -1062.59 1135.61 249.34 0.17 MWD_IFR_MSA 45 4103.31 6.95 90.34 93.02 3801.08 1105.97 -400.82 -1052.35 1126.10 249.15 1. 36 MWD_IFR_MSA 46 4196.47 7.78 87.13 93.16 3893.47 1094.16 -400.54 -1040.42 1114.85 248.94 0.99 MWD_IFR_MSA 47 4289.09 7.88 85.16 92.62 3985.22 1081.62 -399.69 -1027.83 1102.81 248.75 0.31 MWD_IFR_MSA 48 4382.80 7.83 86.08 93.71 4078.05 1068.88 -398.71 -1015.06 1090.56 248.56 0.14 MWD_IFR_MSA 49 4477.31 7.41 87.16 94.51 4171.73 1056.43 -397.97 -1002.55 1078.65 248.35 0.47 MWD_IFR_MSA 50 4570.57 9.79 79.47 93.26 4263.94 1042.53 -396.22 -988.75 1065.18 248.16 2.83 MWD_IFR_MSA 51 4663.43 9.68 75.87 92.86 4355.46 1026.85 -392.87 -973.41 1049.71 248.02 0.67 MWD_IFR_MSA 52 4756.31 9.49 74.17 92 .88 4447.04 1011. 44 -388.88 -958.48 1034.36 247.92 0.37 MWD_IFR_MSA 53 4850.61 9.19 74.19 94.30 4540.09 996.22 -384.70 -943.75 1019 .15 247.82 0.32 MWD_IFR_MSA 54 4943.81 9.13 75.01 93.20 4632.11 981. 45 -380.76 -929.45 1004.42 247.72 0.15 MWD_IFR_MSA 55 5037.09 9.03 74.70 93.28 4724.22 966.78 -376.92 -915.24 989.81 247.62 0.12 MWD_IFR_MSA 56 5130.33 9.56 76.15 93.24 4816.23 951.77 -373.13 -900.66 974.90 247.50 0.62 MWD_IFR_MSA 57 5223.97 12.18 75.44 93.64 4908.18 934.17 -368.79 -883.55 957.43 247.34 2.80 MWD_IFR_MSA 58 5317.00 15.27 75.64 93.03 4998.55 912.16 -363.28 -862.18 935.59 247.15 3.32 MWD_IFR_MSA 59 5411.34 17.62 76.14 94.34 5089.02 885.53 -356.78 -836.28 909.20 246.90 2.50 MWD_IFR_MSA 60 5504.69 19.55 80.70 93.35 5177.50 855.81 -350.87 -807.14 880.11 246.51 2.59 MWD_IFR_MSA ) ) ANADRILL SCHLUMBERGER Survey Report 27-Feb-2002 03:57:44 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ------ -------- ------ ------ ----- ----- ------ -------- ------ ------- ------ -------- -------- ------ -------- ------ ------ ------ 61 5598.41 19.03 80.70 93.72 5265.96 824.85 -345.87 -776.59 850.12 245.99 0.55 MWD_IFR_MSA 62 5692.29 19.08 82.99 93.88 5354.70 794.22 -341. 52 -746.25 820.69 245.41 0.80 MWD_IFR_MSA 63 5785.81 22.48 87.60 93.52 5442.13 761. 22 -338.91 -713.21 789.63 244.58 4.03 MWD_IFR_MSA 64 5880.17 21. 94 86.70 94.36 5529.49 725.83 -337.14 -677 . 58 756.82 243.55 0.68 MWD_IFR_MSA 65 5973.14 21. 39 86.72 92.97 5615.89 691. 75 -335.17 -643.32 725.39 242.48 0.59 MWD_IFR_MSA 66 6064.67 20.06 87.45 91.53 5701.49 659.60 -333.51 -610.97 696.07 241.37 1. 48 MWD_IFR_MSA 67 6158.52 18.82 86.78 93.85 5789.99 628.61 -331.95 -579.78 668.08 240.21 1. 34 MWD_IFR_MSA 68 6251.47 17.77 86.42 92.95 5878.24 599.63 -330.22 -550.65 642.07 239.05 1.14 MWD_IFR_MSA 69 6345.42 16.77 86.09 93.95 5967.96 571.90 -328.40 -522.82 617.40 237.87 1. 07 MWD_IFR_MSA 70 6439.83 16.06 84.58 94.41 6058.52 545.34 -326.24 -496.23 593.86 236.68 0.88 MWD_IFR_MSA 71 6535.44 15.05 85.31 95.61 6150.62 519.80 -323.97 -470.69 571. 41 235.46 1. 08 MWD_IFR_MSA 72 6629.12 14.09 83.61 93.68 6241.29 496.31 -321.71 -447.24 550.92 234.27 1.12 MWD_IFR_MSA 73 6724.10 13 .28 82.35 94.98 6333.57 473.87 -318.97 -424.93 531.33 233.11 0.91 MWD_IFR_MSA 74 6818.12 12.55 82.56 94.02 6425.22 452.87 -316.21 -404.10 513.11 231.96 0.78 MWD_IFR_MSA 75 6911.50 11. 93 82.62 93.38 6516.47 433.10 -313.66 -384.47 496.18 230.79 0.66 MWD_IFR_MSA 76 7002.98 11.45 81. 31 91. 48 6606.06 414.57 -311. 07 -366.12 480.42 229.65 0.60 MWD_IFR_MSA 77 7094.61 11.12 80.92 91. 63 6695.91 396.64 -308.30 -348.40 465.22 228.49 0.37 MWD_IFR_MSA 78 7186.36 10.93 80.27 91.75 6785.97 379.10 -305.43 -331.09 450.46 227.31 0.25 MWD_IFR_MSA 79 7278.96 10.54 81.13 92.60 6876.95 361.85 -302.64 -314.07 436.16 226.06 0.46 MWD_IFR_MSA 80 7373.81 9.91 82.83 94.85 6970.29 345.03 -300.29 -297.40 422.64 224.72 0.74 MWD_IFR_MSA 81 7465.81 9.56 81.92 92.00 7060.97 329.49 -298.23 -281.98 410.43 223.40 0.42 MWD_IFR_MSA 82 7533.11 9.36 81.85 67.30 7127.35 318.43 -296.66 -271. 03 401. 83 222.41 0.30 MWD_IFR_MSA Final Projected Survey at TD 83 7605.00 9.15 81. 77 71.89 7198.31 306.87 -295.02 -259.59 392.97 221.34 0.29 Projection c)2002 Anadrill IDEAL ID6_1C_10 Schlumberger L-111 Minimum Curvature / Lubinski 221.330° N 0.000 ft, E 0.000 It KB 76.400 ft relative to c Survey / DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin TVD Reference Datum: ) MSL MSL 44.100 ft relative to +0.000° 0.000 nT 0.000° February 22, 2002 BGGM 2000 True North +0.000° Well Head Total Corr Mag North -> True North: Local Coordinates Referenced To: Grid Convergence Angle Grid Scale Factor: Geodeti Survey Report - 04-Mar-2002 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) L-Pad 1L-111 Report Date: Client: Field: Structure I Slot: Wel TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: L-, 1 L-111 500292306900 L -111/ February 22, 2002 129.533° 11999.26 ft /5.437/ 0.278 NAD27 Alaska State Planes, Zone 4, US Fee1 N 70 21 0.107, W 149 1932.832 N 5978058.760 ftUS, E 583043.510 ftUS +0.63495331° 0.99990783 TortI Grid Coordinate System: Location LatlLong: Location Grid NlE YIX: Borehole: UWI/API#: Date: ratio: Survey Name I AHD I DDII ERD Longitude 1932.833 19 32.837 19 32.846 1932.874 9 32.933 149 49 49 49 49 w w w w w Goo, N 70 21 N 7021 N 7021 N 7021 N 7021 Grid Coordinates Easting ~ 583043.51 583043.37 583043.06 583042.13 583040.13 Northing ftUS 5978058.76 5978058.69 5978058.36 5978057.44 5978055.89 0.11 0.60 0.59 .08 DLS '/100fl EI-W ftL 0.00 -0.14 -0.45 -1.40 -3.42 -0.07 -0.40 -1.30 -2.84 0.14 0.60 1.90 4.39 TVD f!L 0.00 27.00 201.88 293.32 385.49 0.0 244.4 218.1 230.6 233.9 0.14 0.57 1.08 2.07 201 .88 293.33 385.54 Station ID ) 1933.042 1933.210 19 33.46( 9 33.823 9 34.274 149 149 149 49 49 w w w w w 79 N 70 21 0.056 N 70 21 0.026 N 7020 59.988 N 7020 59.942 N 70 20 59.887 583036.43 583030.70 583021 .98 583009.83 582994.44 5978053.48 5978050.44 5978046.44 5978041.58 5978035.87 .34 .80 2.26 2.64 2.25 -7.14 -12.90 -21.66 -33.88 -49.32 -5.20 -8.18 -12.08 -16.81 -22.35 8.62 14.66 23.38 34.99 49.35 479.75 570.24 662.46 753.65 843.11 239.9 244.5 247.1 250.2 250.4 3.30 4.90 6.98 9.37 11.42 479.90 570.63 663.35 755.48 846.44 149 19 34.837 149 19 35.537 149 19 36.407 149 1937.471 149 19 38.697 w w w w w N 7020 59.817 N 70 20 59.734 N 70 20 59.643 582885.47 N 70 20 59.534 582843.66 N 70 20 59.405 582975.28 .40 .74 58295 582921 5978028.53 5978019.84 5978010.20 5977998.75 5977985.18 2.46 4.44 3.93 5.45 3.15 -68.56 -92.55 -122.31 -158.71 -200.67 -29.48 -37.90 -47.21 -58.26 -71.37 67.41 89.58 116.22 148.56 186.12 935.13 025.19 1112.69 1198.2 1280.90 249. 251.9 253.3 253.0 252.4 13.72 17.81 21.43 26.53 29.47 940.73 1034.33 1127.23 1220.86 1314.52 1940.025 1941.515 943.156 149 149 149 w w w N 70 20 59.257 N 70 20 59.070 N 70 20 58.859 582798.40 582747.64 582691.72 5977969.64 5977950.09 5977927.98 3.74 6.56 .89 -246.10 -297.08 -353.25 -86.4 1 -105.39 -126.88 227.41 275.33 328.56 1360.01 1435.43 1508.41 251.1 248.3 249.8 32.87 38.75 40.23 1406.99 1500.03 1594.60 4/18/2002-1 :40 PM of 3 Page ASP Final Survey.xls L-111 1944.838 19 46.532 149 149 w w N 702058.652 N 70 20 58.435 Station ID 1948.142 1949.778 19 51 .432 1953.038 19 54.506 149 149 149 149 149 w w w w w N 70 20 58.223 N 702058.014 N 70 20 57.807 N 702057.612 N 702057.437 582521 .84 582466.11 582409.73 582355.03 582304.98 5977861.48 5977839.60 5977817.88 5977797.51 5977779.15 1.05 0.95 0.29 2.82 3.68 -523.87 -579.84 -636.47 -691.39 -741.65 -191.51 -212.77 -233.87 -253.63 -271 .43 489.77 542.70 595.93 647.05 693.60 1731 .00 1803.12 1874.98 1947.82 2021 .87 249.0 249.4 249.8 250.7 250.3 39.27 40.13 39.99 37.43 34.08 1882.43 1976.17 2070.06 2163.41 2254.67 ) W 1491955.868 W 1491957.084 W 149 19 58.20~ W 1491959.254 W 149 20 0.224 N 70 20 57.271 N 702057.121 N 702056.986 N 70 20 56.863 N 702056.748 582258.59 582217.14 582179.03 582143.18 582110.11 5977761.80 5977746.09 5977731.87 5977719.01 5977706.93 4.00 4.08 2.35 0.30 4.75 -788.24 -829.86 -868.13 -904.13 -937.33 -288.27 -303.52 -317.32 -329.78 -341.50 737.02 775.96 811.59 844.72 875.45 2100.46 2182.19 2267.55 2351.67 2438.18 250.0 249.8 250.6 251.2 249.8 30.37 26.58 24.38 24.35 19.95 2347.59 2440.58 2535.14 2627.49 2720.91 149201.021 149201.517 149202.175 149202.746 149 20 3.291 W W W W W N 702056.656 N 70 20 56.607 N 70 20 56.537 N 70 20 56.468 N 70 20 56.400 582082.95 582066.05 582043.61 582024.12 582005.58 5977697.33 5977692.12 5977684.81 5977677.56 5977670.44 4.36 2.87 1.37 0.33 1.57 -964.60 -981.55 -1004.07 -1023.64 -1 042.27 -350.80 -355.82 -362.88 -369.92 -376.83 900.44 915.41 935.58 953.79 971.28 2527.03 2592.92 2691.41 2782.22 2874.42 252.9 254.2 250.9 249.5 249.8 15.99 14.06 12.90 12.90 11.42 2814.34 2882.56 2983.84 3077.00 3171.32 149203.767 149204.182 149 20 4.499 149204.649 149204.610 W W W W W N 70 20 56.341 N 70 20 56.292 N 70 20 56.258 N 70 20 56.236 N 70 20 56.219 581989.34 581975.19 581964.41 581959.29 581960.64 5977664.26 5977659.11 5977655.51 5977653.24 5977651.50 1.42 1.84 3.05 4.61 4.06 -1058.57 -1072.79 -1083.60 -1088.75 -1087.42 -382.83 -387.82 -391 .30 -393.51 -395.27 986.55 999.69 1009.44 1014.50 1014.94 2965.83 3058.35 3151.22 3243.47 3336.63 249.8 251.7 252.9 224.0 111.1 0.10 8.40 5.55 1.55 2.90 3264.37 3358.11 3451.68 3544.12 3637.33 ) 149204.481 149204.351 149204.151 149 20 3.884 149 20 3.585 W W W W W N 70 20 56.201 N 70 20 56.181 N 702056.170 N 70 20 56.166 N 70 20 56.164 581965.07 581969.54 581976.38 581985.53 581995.76 5977649.70 5977647.80 5977646.67 5977646.40 5977646.34 0.19 0.16 3.13 0.17 1.36 -1083.01 -1078.56 -1071.73 -1062.59 -1052.35 -397.12 -399.07 -400.28 -400.65 -400.82 1013.42 1011.94 1008.34 1002.58 995.95 3430.45 3523.23 3616.08 3708.62 3801.08 114.5 112.8 93.0 91.7 90.3 2.94 3.06 5.60 5.69 6.95 3731.27 3824.18 3917.30 4010.29 4103.31 149 20 3.237 149 20 2.869 149 20 2.496 149202.130 149201.727 W W W W W N 702056.167 N 702056.175 N 702056.185 N 702056.192 N 702056.210 582007.69 582020.27 582033.02 582045.52 582059.31 5977646.76 5977647.75 5977648.86 5977649.75 5977651.65 0.99 0.31 0.14 0.47 2.83 -1 040.42 -1027.83 -1015.06 -1002.55 -988.75 -400.54 -399.69 -398.71 -397.97 -396.22 987.86 978.91 969.74 960.92 950.49 3893.47 3985.22 4078.05 4171.73 4263.94 87.1 85.2 86.1 87.2 79.5 7.78 7.88 7.83 7.41 9.79 4196.47 4289.09 4382.80 4477.31 4570.57 49 20 1.279 49 20 0.842 49200.412 W W W N 70 20 56.243 N 70 20 56.282 N 70 20 56.323 582074.60 582089.49 582104.17 5977655.16 5977659.32 5977663.66 0.67 0.37 0.32 -973.41 -958.48 -943.75 -392.87 -388.88 -384.70 937.85 924.99 912.13 4355.46 4447.05 4540.09 75.9 74.2 74.2 9.68 9.49 9.19 4663.43 4756.31 4850.61 4/18/2002-1 :40 PM Page 2 of 3 ASP Final Survey.xls L-111 Station ID EI-W DLS Longitude - J!!L ..J°/100.!!; -929.45 0.15 N 7020 56.362 W 149 19 59.994 -915.24 0.12 N 70 20 56.399 W 149 19 59.579 5130.33 9.56 76.2 4816.23 874.99 -373.13 -900.66 0.62 5977675.70 582147.12 N 702056.437 W 149 1959.153 5223.97 12.18 75.4 4908.18 860.42 -368.79 -883.55 2.80 5977680.24 582164.19 N 702056.479 W 149 1958.653 5317.00 15.27 75.6 4998.55 842.17 -363.28 -862.18 3.32 5977685.98 582185.49 N 70 20 56.534 W 149 19 58.028 5411.34 17.62 76.1 5089.02 820.18 -356.78 -836.28 2.50 5977692.77 582211.32 N 70 20 56.598 W 149 19 57.271 5504.69 19.55 80.7 5177.50 796.51 -350.87 -807.14 2.59 5977699.00 582240.38 N 70 20 56.656 W 149 19 56.420 5598.41 19.03 80.7 5265.96 772.57 -345.87 -776.59 0.55 5977704.34 582270.88 N 70 20 56.705 W 149 19 55.527 5692.29 19.08 83.0 5354.70 749.28 -341.52 -746.25 0.80 5977709.02 582301.16 N 702056.748 W 14919 54.640 ) 5785.81 22.48 87.6 5442.13 725.49 -338.91 -713.21 4.03 5977712.00 582334.17 N 702056.774 W 14919 53.67E 5880.17 21.94 86.7 5529.49 700.63 -337.14 -677.58 0.68 5977714.17 582369.77 N 70 20 56.791 W 14919 52.634 5973.14 21.39 86.7 5615.89 676.53 -335.17 -643.32 0.59 5977716.52 582404.01 N 70 20 56.810 W 149 1951.632 6064.67 20.06 87.4 5701 .50 653.92 -333.51 -610.97 1.48 5977718.53 582436.33 N 702056.827 W 14919 50.687 6158.52 18.82 86.8 5789.99 632.14 -331.95 -579.78 1.34 5977720.44 582467.50 N 702056.842 W 14919 49.776 6251.47 17.77 86.4 5878.24 611.61 -330.22 -550.65 1.14 5977722.49 582496.61 N 702056.859 W 149 1948.924 6345.42 16.77 86.1 5967.96 591.87 -328.40 -522.82 1.07 5977724.62 582524.41 N702056.877 W1491948.111 6439.83 16.06 84.6 6058.52 572.68 -326.24 -496.23 0.88 5977727.08 582550.97 N 702056.898 W 1491947.334 6535.44 15.05 85.3 6150.63 554.12 -323.97 -470.69 1.08 5977729.62 582576.48 N 70 20 56.921 W 149 1946.588 6629.12 14.09 83.6 6241 .29 536.93 -321.71 -447.24 1.12 5977732.15 582599.91 N 70 20 56.943 W 149 19 45.902 6724.10 13.28 82.3 6333.58 520.14 -318.97 -424.93 0.91 5977735.13 582622.18 N 70 20 56.970 W 149 19 45.251 6818.12 12.55 82.6 6425.22 504.31 -316.21 -404.10 0.78 5977738.12 582642.97 N 702056.997 W 149 1944.642 6911.50 11.93 82.6 6516.47 489.43 -313.66 -384.47 0.66 5977740.89 582662.57 N 702057.022 W 1491944.068 7002.98 11.45 81.3 6606.06 475.37 -311.07 -366.12 0.60 5977743.68 582680.90 N 70 20 57.048 W 149 1943.532 7094.61 11.12 80.9 6695.91 461.59 -308.30 -348.40 0.37 5977746.65 582698.58 N 70 20 57.075 W 14919 43.014 7186.36 10.93 80.3 6785.97 448.01 -305.43 -331.09 0.25 5977749.70 582715.85 N 70 20 57.103 W 149 19 42.50f ) 7278.96 10.54 81.1 6876.95 434.67 -302.64 -314.07 0.46 5977752.68 582732.84 N 70 20 57.130 W 149 19 42.01 '1 7373.81 9.91 82.8 6970.29 421.89 -300.29 -297.40 0.74 5977755.22 582749.48 N702057.154 W1491941.524 7465.81 9.56 81.9 7060.97 410.16 -298.23 -281.98 0.42 5977757.46 582764.88 N 702057.174 W 14919 41.073 7533.11 9.36 81.8 7127.35 401.76 -296.66 -271.03 0.30 5977759.14 582775.81 N 70 20 57.189 W 14919 40.753 7605.00 9.36 81.8 7198.29 392.87 -295.01 -259.46 0.00 5977760.92 582787.36 N 702057.206 W 1491940.415 Survev Error Model: (No Error Model Selected) L-111 ASP Final Survey.xls Page 3 of 3 4/18/2002-1 :40 PM Date Delivered: ¡I&GasCons·Cornmiion Anchorage Received BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 f: Sf) 1 ' " " RECEIVEDI 9 2002 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: { -~ L-111 L-102 L-102 L-102 L-102 L-102 L-102 L-102 L-102 L-102 w- 22160 22143 22143 22143 22143 22143 22143 22152 22152 22152 USIT PEX,AIT,& SHC PEX-AIT PEX-D/N SHC PEX & SHC QUAD COMBO PEX & SHC QUAD COMBO SSTVD PP,IMPULSE DATA MD VISION RESISTIVITY TVD VISION RESISTIVITY 03/02102 03/21/02 03/21/02 03/21/02 03/21/02 03/21/02 03/21/02 03/19/02 03/19/02 03/19/02 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 do,.::}...o¿sa ;=;}(\d- C R (Ö 2 ( Well Job # Log Description Date Color Sepia BL CD Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Field: Borealis Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite Anchorage, AK 99501 00 SC~IunI.IP(III' Company: NO. 995 4/ 6/2002 ..--. ~ MWD/L WD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-111i Date Dispatched: 1-Mar-02 I nstallation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Flo ies Surveys 2 dW'O 0 n Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 /' ,...'" ~ViÃ\VŒ mJ~ !Æ~!Æ~[{!Æ / ALASKA. OIL AND GAS / CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Neil Mcgee Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-111 i BP Exploration (Alaska), Inc. Pennit No: 202-030 Sur. Loc. 2339; NSL, 3873' WEL, Sec. 34, T12N, RUE, UM Btrnhole Loc. 2058' NSL, 3876' WEL, Sec.34, T12N, RIlE, UM Dear Mr. McGee: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Your application for waiver of the diverter requirements at 20 AAC 25.035 (c) is noted. At this time, we cannot approve your request. Further discussion and review of the available infonnation is requested to allow consideration of this request for future wells. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit L-I1Ii. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sjpcerely, ~,~ Qu..-~ \. ~ (j./ Cammy Oèchsli Tayl~~-O' Chair BY ORDER OF THE COMMISSION DATED this 19th day of February, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '..t ~ STATE OF ALASKA ALASK )IL AND GAS CONSERVATION COW~SION PERMIT TO DRILL 20 MC 25.005 ~A '2-{'ifI01- !r~ t~ 1 a. Type of work III Drill o Redrill 11 b. Type of well o Exploratory ~tratigraPhiC Test 0 Development Oil ORe-Entry o Deepen III Service 0 Development Gas Single zon~ 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 75.5' Prudhoe Bay Field / Borealis 3. Address 6. Property Designation Pool (Undefined) P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2339' NSL, 3873' WEL, SEC. 34, T12N, R11 E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1981' NSL, 4921' WEL, SEC. 34, T12N, R11E, UM L-111 i Number 2S100302630-277 At total depth 9. Approximate spud date 2058' NSL, 3876' WEL, SEC. 34, T12N, R11 E, UM 02/23/02 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028241, 2058' MD No Close Approach 2560 7700' MD / 7147' TVD 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 42 Maximum surface 2722 psig, At total depth (TVD) 6480' / 3370 psig 18. Casing Program Specifications Setting Depth Quantitv of Cement Size Too Bottom Hole Casinn Weinht Grade CouDlina Lenath MD TVD MD TVD linclude stane data) 42" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 60 sx Arctic Set (ADDrox.) 12-1/4" 9-5/8" 40# L-80 BTC 3002' Surface Surface 3002' 2676' 03 sx Articset Lite, 287 sx 'G' 8-3/4" 7" 26# L-80 BTC-M 7700' Surface Surface 7700' 7147' 93 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate RECEIVED Production Liner FES 0 5 2002 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments II Filing Fee o Property Plat o BOP Sketch o Diverter Sketch II Drilling Program II Drilling Fluid Program o Time vs Depth Plot o Refraction Analysis o Seabed Report o 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fO~Oing is tzn¡ correct to the be~t of my ~nowl~~ge . Signed Lowell craN...,. ~_ ß~ _ - -' Title Senior Drilling Engineer Date Z. -4-~Z- "';';;';;'>'" "'Of',,''''' ~ ;ù ;;:;:;9;,;:\' Permit Number API Nu~er q APP~~"~ Û 0- See cover letter 2D2-- D.3D 50-62 ~ 2.3~ ~OO I for other reauirements Conditions of Approval: Samples Required DYes (IlNo Mud Log Required DYes 6ilNo Hydrogen Sulfide Measures DYes .SNo Directional Survey Required L¥Yes DNo Required Working Pressure for BOPE D2K D3K D4K D5K D10K D15K D 3.5K psi for CTU TëS.t ßOfE {., '\ o<¡¡)her; ~. W..¿~... ... 10 M<- 15....-,.,,) .!i.~,\ey «~u..<:re... "",f d¢..:.¿J:· ~ (: p . . . B by or er of ~ 11'-1 'ß1~ 1Jv1¡;{ ADD roved By Ongmal Signed Y Commissioner the commission Date ,~ Form 10-401 Rev. 12-01-85 "'........, TJ I GH~/~L Subn it rn Triplicate ~ bp ... .."'.'11, -..,~ ~~.- ~~- --:.~-- .~ F~" ·'1'·'1'- ". ~ To: Date: February 10, 2002 From: Bruce W. Smith GPB Borealis Development Engineer Subject: Dual Iniector Inte2ritv The Borealis Field has been developed in Kuparuk aged hydrocarbon zones, in an area that directly over lays oil discoveries in the Schrader Bluff Pool, which is expected to be called the Orion Field. The Orion field development is in the study and planning stage, with Borealis in the full development stage. Using the planning information currently developed for the Orion field it was determined that many of the same identified injection well locations planned for Borealis were near the planned intersection points needing injection in the Orion horizon. Dual Injectors are planned to be used for certain injector locations. These injectors would be based on a BP design called Ultra-Slim Hole basis. This basis is 9 5/8 inch surtace casing set in the SV-1 formation at approximately 2900 TVD. A long string would be placed to TD and cemented to 500 ft above the Schrader Bluff formation. This string would be evaluated using a cement evaluation log such as a USIT, CBL, CPT or other approved devices with the rig on location. Once cement integrity is proven, the Schrader Bluff Formation would be selectively perforated, A straddle completion would be run with packers placed above and below the pertorated interval. The straddle would consist a permanent packer (such as a Baker S- 3 style) set approximately 200 feet above the Kuparuk Formation, a second permanent packer (such as a Baker Premium style) would be set approximately 200 feet above the Schrader Bluff pertorations. The straddle tubular would be made up of 3 Y2 inch L-80 material standard tubing such as 9.2# L-80 premium thread and 4 Y2" 12.6# L-80 premium thread materials. Flow and integrity control of the straddle would be maintained with two or more Schlumberger (Camco) MMG-W water flood injection mandrels. These mandrels accept injection valves, which are double-checked. Additionally the mandrels each an external check as part of the body. A proposed testing procedure is listed below; this method is split between original installation and future testing procedures. cc: ~ ~ Dual Injector Integrity Welllntearitv Testina Mechanicallntearitv Test (MIT) OriQinal Completion (Ria present) 1. After Well Has been cased and cemented, casing, wellhead and BOP will be pressured tested to meet or exceed the requirements of 20 AAC 25.410. 2. The casing will be evaluated with a cement evaluation log. 3. Once this log has been evaluated and cement is deemed to provide isolation, the rig will perforate using TCP guns to shoot the Schrader Bluff formation at or slightly above balance. 4. The completion will be run and set. 5. The completion will be run with dummy valves in place in the water injection mandrels. 6. The lower injection zone of the Kuparuk will be perforated after the rig moves off. 7. Pressure Test Tubing for 30 min. 8. Pressure test tubing and annulus 9. Bleed off tubing with pressure on annulus. Prior to placina well on Kuparuk Injection (Initial AOGCC witnessed MIT) 1. Well on injection and warmed up and stable 2. Pressure test the annulus and hold for 30 min. Usina the same MIT testina schedule as PBU (AOGCC Witnessed normal scheduled testing) 1. Safe out injector 2. Freeze protect injector 3. Place plug in tubing tail profile 4. Pressure test tubing to required pressure. This test will prove integrity of tubing, plug in tail pipe, water injection mandrels and dummies in water Injection mandrels. 5. Bleed off pressure 6. Pressure test annulus to required pressure. This test will prove integrity of casing, wellhead, packer and reverse flow to tubing. 7. Bleed off pressure. 8. Pull plug and return well to injection. Intearitv issues durinQ Injection (Kuparuk injection only) 1. Water Injection mandrels have external check valves 2. Water Injection valves will be dummied wi pressure test. 3. Annulus, Injection Rate and Pressure will be monitored daily. 4. Normal cycle of AOGCC Witnessed testing (AOGCC MIT) InteQritv Issues durinQ dual injection (Kuparuk and Schrader Bluff) ~, ."-"': Dual Injector Integrity 1. Water Injection mandrels have external check valves 2. Water Injection valves have two check valves internally 3. An Injection safety valve, (similarly to a Halliburton MC flapper type injection valve) would be installed in the tailpipe. When the injector is shut-in, this flapper would close and prevent cross flow from the Kuparuk to the Schrader Bluff. 4. Annulus, Injection Rate and Pressure will be monitored daily. 5. Normal cycle of AOGCC Witnessed testing (AOGCC MIT) Intecaritv issues durincalniection (Schrader Bluff injection only) 1. A plug would be placed in the tailpipe to prevent injection into the Kuparuk. 2. Water Injection mandrels have external check valves 3. Water Injection valves have dual check valves. 4. Annulus, Injection Rate and Pressure will be monitored daily. 5. Normal cycle of AOGCC Witnessed testing (AOGCC MIT) Please call (Bruce Smith 440-8008, hm: 345-2948, office: 564-5093) if there are any questions. ,-... .~ .. ''''f _..~ ~4!;- ~~ ~. ·'I'~I\~ ". bp To: Tom MaunderlWinton Aubert, AOGCC Date: February 4, 2002 From: Neil Magee Subject: Dispensation for 20 AAC 25.035 (c) on L-ll1 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the 8 Boreilis/Ivishak well~at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure contr<ÿor shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All six of the surface holes for the Borealis Development (L-1l6, L-llO, L-1l4, L-1l5, L-106,L-104 and L-l 07) and the first Ivishak well (L-O 1) were drilled to the shale underlying the SV-l sands. The shale underlying the SVl is the deepest planned surface ca~g setting depth for future pad development wells. This casing point is ±300' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-lll is planned to reach a 9.5 ppg mud weight before TD at 2,676' TVDss. This request is being made based on L-Pad data submitted regarding mud weight, gas monitoring, recent open hole surface logging of L-l 06 (PEX/Dipole sonic) and meeting ,;'. between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. Sincerely, ~/::þ~ ADW Engineer 564-5119 8 o 500 1000 - .a ~ 1500 Q > I- - .c Õ. 2000 Q) Q 2500 ------- ~. Borealis Suñace Hole Mud Weight MW (ppg) 9 8.5 9.5 3000 --p----------- 3500 . L -01 . L-114 . L-116 ¿ L-110 ) ( Pore Pressure . L-107 . L-115 ---'L-104 . Borealis Mud Plots 2/4/02 10 .,-..... ~ IWell Name: I L-111 i Drill and Complete Plan Summary / I Type of Well (service I producer I injector): I Dual Injector ./ Surface Location: X = 583,043' Y = 5,978,059' As-Stacked 2339FSL (2940' FNL), 3873' FEL (1405' FWL), Sec. 34, T12N, R11E Target Location: X = 582,000' Y = 5,977,690' Top Schrader: 1981 FSL (3297' FNL), 4921' FEL (357' FWL), Sec. 34, T12N, R11 E Target Location: X = 582,940' Y = 5,977,770' Top Kuparuk 2051 FSL (3228' FNL), 3980' FEL (1298' FWL), Sec. 34, T12N, R11 E Bottom Hole Location: X = 583,043.78' Y = 5,977,778.83' 2058' FSL (3220' FNl), 3876' FEL (1402' FWl), Sec. 34, T12N, R11 E / I Rig: I Nabors 9ES ./ 1 Operating days to complete: 117.3 1 AFE Number: 15M4023 I Estimated Start Date: 12/23/2002 ~ 7700' 1/ I I TVD: 17147' 1 BF/MS: 130' I RKB: 175.5' I Well Design (conventional, slimhole, etc.): 1 Ultra Slim hole (Iongstring) I Objective: I Schrader/Kuparuk Formation Mud Program: 12 'IA" Surface Hole (0-3002'): Fresh Water Surface Hole Mud Densitv Viscosity Yield Point API FL PH lPiJci) (seconds) (lb/1 OOft~) (mls/30min) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5-9.5 below Permafrost 9.0 - 9.5 J / 200-250 50 - 70 <10 8.5- 9.5 interval TD 9.6 max ..; 200-250 50 - 60 <10 8.5- 9.5 8 3,4" Intermediate I Production Hole (3002' - 7700'): 4% KCUPolymer Interval Density Tau 0 YP PV pH API HTHP (ppg) Filtrate Filtrate Upper 9.3 4-7 20-25 8-12 8.5-9.5 4-6 Interval ,I Top of HRZ 10.3 v 5-8 20-25 8-14 8.5-9.5 3-5 <10 by toTD HRZ L-111 i Drilling Program Page 1 ~ /'..--.\ Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM PiDe (fpm) ppg-emw ("/32) (in2) 0-2,000 600 4" 17.5# 90 1800 9.7 N/A 18,18,18,13 .875 2,000' -2,678' 650 4" 17.5# 110 2400 10.3 N/A 18,18,18,13 .875 Intermediate/Production Hole: 8 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 3002' - 7700' 575 4" 17.5# 200 3400 11.3 N/A 6x15 1.03 Directional: Ver. Anadrill P9 Slot SA KOP: 300' Maximum Hole Angle: 420 at 1402' MD ".. Close Approach Wells: All wells pass major risk criteria. L-114 - 30' offset to 350' / IFR-MS corrected surveys will be used for survey validation. Gyro will be on standby for suriace hole close approaches. ram: Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Den / Neu Open Hole: Cuttings Evaluation Cased Hole: USIT cement evaluation Formation Markers: Formation TODS MDbkb TVDss Estimated pore pressure, PPG SV5 1465' SV4 1610' Base Permafrost 1775' SV3 1950' SV2 2120' SV1 2440' UG4A 2755' ~5;I. -~ UG3 3110' . ... -- UG1 3535' Ma 3855' Na 4075' Hvdrocarbon bearinQ 8.8 DDQ EMW L-111 i Drilling Program Page 2 ~ ",,-,\ Oa 4275' Obf Base 4630' CM2 (Colville) 5025' CM1 (Colville) 5615' THRZ 6195' BHRZ (Kalubik) 6370' K-1 6420' TKUP 6480' Hydrocarbon BearinQ 3370 psi, 10.0 PPQ EMW Kuparuk C 6490' LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) 6923' TD Criteria "'\f\t-'J "'t 150' below Miluveach top ......- C IT b" p aSln gJ U Ing rogram: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg C.D. MDfTVD MDfTVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 11 0/11 0 12 %" 9 5/8" 40# L-80 BTC 3002' GL 3002'/2676' 8%" 7" 26# L-80 BTC-m 7700' GL 7700'/7147' TubinQ 31t2" 9.2# L-80 NSCT 2000' 4562'/4237' 6800'/6268' Tubing 41t2" 12.6# L-80 NSCT 5000' GL 4562'/4237' r' ; Testin : Depth 20' min from surface shoe Test Type LOT EMW/ 13.5 ppg EMW Target Cement Calculations: Note: The following surface cement calculations are based upon a single stage job. A port collar will be utilized if hole conditions indicate that cement may not circulated to surface in a single stage. Casin Size 9-5/8" Surface Basis: Lead: Based on 2002' of annulus in the permafrost @ 250% excess and 130' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ./ Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2252' MD ./ Total Cement Volume: Lead 319 bbl 11789 ft ý403 sks of Dowell ARTICSET Lite at 10.7 and 4.44 dIsk. Tail 60 bbl I 336f1--1 287šks of Dowell Premium 'G' at 15.8 and 1.17 cf/sk. Note: The production interval cementing design is a two stage slurry.utilizing 15.8 ppg G cement across the Kuparuk and the Schrader. L-111 i Drilling Program Page 3 ,.--... ~ (#Nt, '- - c};:i4f ____ Casin Size 7" Production Longstring Basis: Stage 1: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 6599' MD (estimated) Stage 2: Based on TOC 500' above top of Schrader formation +,.20% excess Cement Placement: From 500' below Schrader 5600' to 3756' MD estimated Total Cement Volume: Stage 1 40 bbls / 224/".1.Q't sks of20well Premuim "G" at 15.8 and 1.17cf/sk 1..1.1' wG!-, Stage 2 63 bbls / 353 f17/ 302 sks of Dowell Premuim "G" at 15.8 and 1.17cf/sk. Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based on . the requirement for MI service up to 4000 psi the BOP equipment will be tested to 4000 / psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: ~370 psi @ 6480' TVDss - Kuparuk Sands 2722 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) / 4000 psi (The casing and tubing will be tested to 4000 psi.) 9.2 ppg filtered seawater / 6.8 ppg Diesel · Planned BOP test pressure: · Planned completion fluid: Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. L-111 i Drilling Program Page 4 ~ ~ DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor is scheduled to bepstalled prior to 22 February 2002. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: / . 1. MIRU Nabors 9ES on Slot SA. / 2. Nipple up diverter spool and riser. A diverter waiver has been applied for. PU 4" OP as required and stand back in derrick. 3. MU 12 W' drilling assembly with MWO/GR and directionally drill surface hole to approximately 3002' ./ MO / 2676' TVO. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. The actual ~rface hole TO will be +/-100' TVO below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A Tam port collar may be run in the casing to allow for secondary cementing if hole conditions indicate that cement may not reach surface during primary cementing operations. ,,' 5. NO diverter spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling p5sembly with MWO/GR/RES/OEN/NEU and RIH to float collar. Test the 9-5/8" casing to 3000 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.3 ppg 4% KCL drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. ./ B. Drill ahead and increase mud weight to 9.6 ppg prior to entering the SctJJ:ader Oa sand. 9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.3 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. /' 10. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for running 7" 26# long- string. ./ 11. Run and cement the 7" production casing in two stages. This is expected to be a two stage job with 15.B ppg lead across the Kuparuk followed by a 15.8 ppg tail across the Schrader utilizing a TAM port collar. Displace the casing with 9.2 ppg brine during cementing operations. 12. Freeze protect the 7" x 9-5/B" annulus as required. Record formation breakdown pressure on Morning Report. 13. Cleanout possible cement stringers to 7" float collar and displace well to clean brine with a perf pill across Schrader interval/ 14. Test the casing to 4000 psi for 30 [Pffi. 15. RU Schlumberger and run USIT log on e-line from the 7" float collar to the 9 5/B" surface shoe. 16. Perforate Schrader interval on TCP. 17. Make scraper run and POOH laying down excess drill-pipe. ./ 1B. Run the combination 3-1/2" 9.3#, L-BO NSCT / 4-1/2",12.6#, L-BO TC-II straddle completion assembly. Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear RP valve and install TWC. Test below to 2700 psi. 19. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 20. Freeze protect the well by pumping diesel to the lowermost 4-1/2" GLM. Allow diesel to U-tube from the annulus to tubing. 21. Rig down and move off. L-111 i Drilling Program Page 5 ,~ .~. L-111 i Hazards and Contingencies Job 1: MIRU Hazards and Contingencies / ~ L-Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all ti~S. ~ The closest surface location is L-114, 30 feet to the east. Surface shut-in will be required as this well is on production. ~ Check the landing ring height on L-111.The BOP nipple up may need review fo,!»pace out. ~ Based on pore pressure data and experienced gained on the first seven Borealis L-pad wells (and 3 previous L-pad Ivishak wells) the AOGCC has been asked for dispensation from the diverter requirement on the 121ft¡" surface hole. During the Surface Hole Planning Meeting and PJSM's the absence of a diverter on the surface hole on this is to be discussed. Monitoring the hole, checking connections, importance of maintaining mud properties (including pre-treating with DrillTreat for Hydrates), focus on avoiding swabbing situations, importance of not loading up the hole (hole cleaning), evacuation drills, muster areas, etc. should be topics for discussion and action. The waiver has been justified based on extensive penetrations below "L" pad with no shallow gas problems and L-106 open hole surface logging. The absence of the ability to divert requires even greater diligence while drilling the surface hole. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drilling Surface Hole ~ No faults are expected to be penetrated by L-111 i in the surface interval. ~ There is one close approach issue in the surface hole. All wells pass major risk criteria. The closest existing well, L-114i is 30' center-center at surface to -350' MD. Gyro survey tools will be on standby while drilling the surface hole until Clear of magnetic intereference. ~ Gas hydrates have been observed all wells drilled on L-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. "Successfully Drilling Surface Hole. (Attached) L-111 i Drilling Program Page 6 .~ /~ Job 3: Install Surface CasinQ Hazards and Contingencies ,/' ~ It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. If hole conditions indicate that cement to surface may be an issue, a 9-5/8" port collar will be positioned at ±1000'MD to allow a secondary circulation. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement / 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Dowell Cement Program" .:. "Surface Casing Port Collar Procedure" Job 7: DrillinQ Production Hole Hazards and Contingencies ~ L -111 i will cross a fault in the UG3 at -3150' TVDss (+/-150'). The estimated throw of the fault is approximately 100'. The well will be _0° when crossing the fault. Loss circulation is considered to be a moderate risk. The second fault is at a depth of 4000' TVDss (+/-100') near the top of the Schrader. The estimated throw is 60'. The well will be _0° when crossing the fault. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: The reservoir pressure of the Kuparuk has been determined to be 10.00 ppg. In the worst case scenario of 10.0 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.1 ppg at the surface casing shoe, 1004 ppg mud in the hole the kick tolerance is 25 bbls. LOT's of 13.5ppg (L-01), 1504ppg (L-116), 15.6 ppg (L-114), 13.7ppg (L- 110), 13.8ppg (L-107), 15.2 ppg (L106), 13.2 ppg (L-115) and 13.1 ppg on L-104 have been recorded in offset L-Pad wells. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.1 ppg. ~ L-Pad development has had "kick tolerances" in the 35-45 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ There are no "close approach" issues with the production hole interval of L-111 i. ~ A 4% KCL polymer mud system will be used in the production interval. Experience suggests that wiper trips will be required more frequently in the SV and Ugnu - each 1000' of hole in the SV and Ugnu. Subsequent wiper trip through these intervals will be required on an alternating day basis to stabilize these intervals. Flow rates should be maintained in the 575 gpm range particularily while drilling with higher ROP's (300'/hr) through the SV and Ugnu intervals. Note: Baroid will prepare hydraulic and hole cleaning models for these hole intervals prior to spud. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests L-111 i Drilling Program Page 7 ~ ..--...... .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HrZ" Job 9: Case & Cement Production Hole Hazards and Contingencies > The Ugnu 4A is not expected to be oil bearing. For this reason the 7" casing will be cemented to 500' above the Schrader sand if logs indicate that it is oil bearing otherwise the cement will be brought up to 1000' above the Kuparuk. The top of the hydrocarbon interval should be verified with LWD resistivity log. > A 7" TAM port collar will be utilized in the production casing string. This will be positioned 500' below the Schrader formation to allow for a stage cement job utilizing 15.8 ppg G across the Schrader interval. The Kuparuk will be cemented in the first stage utilizing 15.8 ppg G from TD to 500' above the Kuparuk. > Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of dead crude (2000'), the hydrostatic pressure will be 10.0 ppg vs the 10.0 ppg EMW of the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude however the hydrostatic pressure of the mud and diesel should exert a 46 psi overbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping peJP1its.) ~ A cement bond log (USIT) will be run to confirm cement quality and the TOC. This will be done with the rig prior to perforating the well. ~ If the cement job is suspect be immediately prepared to run a temperature log following the cement job to verify TOC. > The well will be under-balanced after displacing the cement with 9.2 ppg brine. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. > Ensure a minimum hydrostatic equivalent of 10.3 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Dowell Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" Job 10: Perforate Well Hazards and Contingencies > The Schrader interval of the well will be TCP perforated prior to running the completion. After placing a brine perf pill weighted to 9.2 ppg the well will be perforated across a 8.8 ppg (to be confirmed) EMW reservoir for an overbalance of 90 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. L-111 i Drilling Program Page 8 ~ .'",""", ~ A USIT log will be required from the ETD to the top of cement. Send results of USIT log into Anchorage office as soon as practical for evaluation. Reference RPs .:. See attached Initial Perforating Procedures Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The Schrader interval of the well will be perforated. ~ Take care while passing through TAM port collar with packer and completion string. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus L-111i Drilling Program Page 9 ~ ~ Borealis L-111 i Proposed Completion TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 9-5/8",40 #/ft, L-80, BTC 3003' 4-1/2" 'X' Landing Nipple with 3.813" seal bore ./ 7" x 4-1/2" Baker "Premium" ~ Production Packer 50' above top Schrader perforation 3-1/2" MMGW Water Flood GLM with Injection Valve with New Vam BxP 7" 'TAM port collar below Schrader Plug Back Depth 7620' ./ 7", 26 #Ift, L-80, BTC-Mod 7700' Cellar Elevation = ±47' RKB-MSL = ±77' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' I Gas Lift Mandrels with handling pups installed. # 1 2 3 4 MD GAS LIFT MANDRELS Type Valve Type Dummy Dummy RP Dummy TBD TBD TBD TBD 3-1/2" MMGW 3-1/2" MMGW 4-1/2" KBG-2 4-1/2" KBG-2 4-1/2" 12.6# L-80, Premium Connection Tubing 3-1/2" NSCT Tubing below top packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 7" x 4-1/2" Baker "S-3" Packer +1- 250' above Kuparuk 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" WireLine Entry Guide set at +1-150' above the Kuparuk FormatiDn Date 2-1-02 Rev By Comments NM Proposed Completion (P9) Borealis WELL: L-111 API NO: 50-029-1111 BP Alaska L-111 bp Schlumberuer art Minimum Curvature! Lubinski 260.000 N 0.000 ft, E 0.000 ft KB eRe SUrvey I DLS Computation Method: Vertical Section Azimuth: Geodeti e Profi I osed Well January 30, 2002 BP Exploration Alaska Prudhoe Bay Uni L-Pad /L-111 Pro Report Date: Client: Field: Structure I Slot: Well 76.5 ft relative to MSL 44.100 ft relative to MSL Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Ground Level Elevation: Iy Feasibility study Pads) WOA(Dri L- L- 50029 ) 26.095 57471.1 Magnetic Declination: Total Field Strength: Magnetic Dip Declination Date Sea Bed Borehole: UWUAPI#: 72 nT L-111 (P9) / January 30, 2002 32.737 /2154.10 ft/5.489 Survey Name I Date: Tort I AHD I DDII ERD ratio: 80.761 February 27, 2002 BGGM 2001 True North +26.095 Well Head US Feel 0.30 NAD27 Alaska State Planes, Zone 4, 49.32579101 Grid Coordinate System: Location Lat/Long Location Grid N/E Y IX Magnetic Declination Model North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: N 70.35003039, W N 5978059.000 ftUS, E 583043.000 ftUS +0.63494944 0.99990783 Longitude 149.32579101 149.32579101 149.32579353 149.32580278 149.32585636 w w w w w N 70.35003039 N 70.35003039 N 70.35003009 N 70.35002905 N 70.35002287 Grid Coordinates Easting ~ 583043.00 583043.00 58304 2.69 583041.56 583034.98 Northing ~ 5978059.00 5978059.00 5978058.89 5978058.49 5978056.16 DLS 710o.!!! 0.00 0.00 1.50 2.50 4.00 E/-W (ft) Õ.OO 0.00 -0.31 -1.45 -8.05 N/-S (ft) 0.00 0.00 -0.11 -0.49 -2.75 Grid Convergence Angle Grid Scale Factor: o 2 51 8.40 300.00 350.00 399.98 499.72 251.15 251.15 251.15 251.15 0.75 2.00 6.00 Station ID KBE KOP Bid 1.5/100 Bid 2.5/100 Bid 4/100 ) 149.32596319 149.32612295 149.32633466 149.32659735 149.32690972 w w w w w N 70.35001061 N 70.34999225 N 70.34996793 N 70.34993775 N 70.34990187 583021.87 583002.27 582976.29 582944.06 582905.73 5978051.53 5978044.59 5978035.40 5978023.99 5978010.44 4.00 4.00 4.00 4.00 4.00 -21.21 -40.89 -66.97 -99.33 -137.81 -7.24 -13.96 -22.86 -33.91 -47.04 22.15 42.69 69.92 103.71 143.89 598.73 696.52 792.63 886.58 977.91 251.15 251.15 251.15 251.15 251.15 10.00 14.00 18.00 22.00 26.00 600.00 700.00 800.00 900.00 1000.00 149.32727031 149.32767733 149.32812883 149.32862254 149.32863415 w w w w w N 70.34986043 N 70.34981368 N 70.34976180 N 70.34970508 N 70.34970374 582861.49 582811.55 582756.14 582695.56 582694.14 5977994.78 5977977 .12 5977957.51 5977936.08 5977935.58 4.00 4.00 4.00 4.00 4.00 -182.23 -232.37 -287.99 -348.81 -350.24 -62.21 -79.32 -98.31 190.27 242.62 300.69 364.19 365.68 1066.19 1150.98 1231.86 1308.45 1310.13 251.15 251.15 251.15 251.15 251.15 30.00 34.00 38.00 42.00 42.09 1100.00 1200.00 1300.00 1400.00 1402.26 149.33023963 149.33124578 149.33145301 w w w N 70.34951925 N 70.34940363 N 70.34937983 582497.14 582373.68 582348.25 5977865.88 5977822.20 5977813.21 0.00 0.00 0.00 -548.02 -671.97 -697.50 -119.07 119.56 -187.08 -229.39 -238.10 572.18 701.60 728.25 1541.50 1686.50 1716.36 251.15 251.15 251.15 42.09 42.09 42.09 1714.04 1909.44 1949.68 End Bid 00 SV5 SV4 Drp 4/1 1/30/2002-9:08 AM of 3 Page (P9) report.xls L-lll Longitude 149.33170708 149.33218073 W W Geo Grid Coordinates Eãsting (ftUS) 5'ã'2'3i""7 . 0 7 582258.95 17 61 Northing ~ 5977802 5977781 DLS 1100ft) 4.'00 4.00 Azim iL 251.15 251.15 Incl 1 40.08 36.08 MD !!!. 2000.00 2100.00 Station ID 149.33228260 149.33261110 149.33299602 149.33309286 149.33333361 W W W W W 4929618 N 70.34928449 N 70.34924675 N 70.34920250 N 70.34919138 N 70.34916369 582246.45 582206.14 582158.91 582147.02 582117.48 5977777.19 5977762.93 5977746.22 5977742.02 5977731.56 4.00 4.00 4.00 4.00 4.00 -787.15 -799.70 -840.17 -887.59 -899.52 -929.18 -268.71 -272.99 -286.80 -302.99 -307.06 -317.19 85 834.96 877.21 926.72 939.17 970.14 821 1832.99 1851.50 1915.80 2002.32 2026.50 2092.12 251.15 251.15 251.15 251.15 251.15 35.17 32.08 28.08 26.99 24.08 2122.77 2200.00 2300.00 2327.27 2400.00 Base Permafrost ) 149.33362225 149.33365480 149.33386057 149.33404743 149.33418177 W W W W W N 70.34913052 N 70.34912677 N 70.34910313 N 70.34908165 N 70.34906621 582082.06 582078.07 582052.81 582029.89 582013.40 5977719.03 5977717.62 5977708.69 5977700.57 5977694.74 4.00 4.00 4.00 4.00 4.00 -964.74 -968.75 -994.10 -1017.12 1033.67 -329.33 -330.70 -339.35 -347.21 -352.86 1007.27 1011.45 1037.93 1061.96 1079.24 2184.77 2196.50 2279.82 2376.79 2475.23 251.15 251.15 251.15 251.15 251.15 20.08 19.58 16.08 12.08 8.08 2500.00 2512.47 2600.00 2700.00 2800.00 SV3 SV2 149.33422211 149.33426310 149.33429094 149.33429094 149.33429094 W W W W W N 70.34906156 N 70.34905686 N 70.34905367 N 70.34905367 N 70.34905367 582008.45 582003.42 582000.00 582000.00 582000.00 5977692.99 5977691.21 5977690.00 5977690.00 5977690.00 4.00 4.00 4.00 4.00 4.00 -1038.64 -1043.69 -1047.12 1047.12 1047.12 -354.56 -356.28 -357.45 -357.45 -357.45 1084.43 1089.70 1093.29 1093.29 1093.29 2516.50 2574.65 2674.56 2676.49 2676.50 251.15 251.15 251.15 251.15 85.77 6.41 4.08 0.08 0.00 0.00 2841.60 2900.00 3000.00 3001.93 3001.94 SVl 149.33429094 149.33429094 149.33429094 149.33429094 149.33429094 W W W W W N 70.34905367 N 70.34905367 N 70.34905367 N 70.34905367 N 70.34905367 582000.00 582000.00 582000.00 582000.00 582000.00 5977690.00 5977690.00 5977690.00 5977690.00 5977690.00 0.00 0.00 0.00 0.00 0.00 -1047.12 -1047.12 -1047.12 -1047.12 -1047.12 -357.45 -357.45 -357.45 -357.45 -357.45 1093.29 1093.29 1093.29 1093.29 1093.29 2831.50 3186.50 .50 .50 .50 3611 3931 4151 85.77 85.77 85.77 85.77 85.77 0.00 0.00 0.00 0.00 0.00 3156.94 3511.94 3936.94 4256.94 4476.94 End Drp /9-5/8" Csg Pt UG4A UG3 UG1 Ma WS2 ) 149.33429094 149.33429094 149.33428834 149.33428631 149.33428177 W W W W W N 70.34905367 N 70.34905367 N 70.34905372 N 70.34905377 N 70.34905388 582000.00 582000.00 582000.32 582000.57 582001.13 5977690.00 5977690.00 5977690.03 5977690.05 5977690.10 0.00 0.00 1.50 2.50 2.50 -101].12 -1047.12 -1046.80 -1046.55 -1045.99 -3§l.45 -357.45 -357.43 -357.41 -357.37 1093.29 1093.29 1092.96 1092.72 1092.15 4236.50 4286.50 4336.50 4351.50 4374.55 85.77 85.77 85.77 85.77 85.77 0.00 0.00 0.75 .13 .70 4561.94 4611.94 4661.94 4676.94 4700.00 Schrader Target Bid 1.5/100 Bid 2.5/100 WS1 149.33427860 149.33423185 149.33412591 149.33396422 149.33389213 W W W W W N 70.34905397 N 70.34905514 N 70.34905777 N 70.34906179 N 70.34906360 582001.52 582007.28 582020.31 582040.21 582049.09 5977690.13 5977690.62 5977691.73 5977693.42 5977694.18 2.50 4.00 4.00 4.00 4.00 -1045.60 -1039.84 -1026.79 -1006.87 -357.34 -356.91 -355.95 -354.48 -353.82 1091.77 1086.02 1073.00 1053.13 1044.27 4386.48 4474.34 4573.46 4671.43 4706.50 85.77 85.77 85.77 85.77 85.77 2.00 5.52 9.52 13.52 14.97 4711.94 4800.00 4900.00 5000.00 5036.19 Bid 4/100 149.33374765 149.33347717 149.33315410 W W W N 70.34906721 N 70.34907395 N 70.34908199 582066.87 582100.16 582139.92 5977695.69 5977698.52 5977701.90 4.00 4.00 4.00 -997.99 -980.19 -946.87 -907.07 -352.50 -350.04 -347.10 1026.51 993.27 953.57 4767.76 4861.99 4953.66 85.77 85.77 85.77 17.52 21.52 25.52 5100.00 5200.00 5300.00 Obf Base 1/30/2002-9:08 AM Page 2 of 3 (P9) report.xls L-111 Longitude 149.33280441 149.33251169 w w Geo N7 N 70.34909802 Grid Coordinates Eãsting ~ 582182.96 582218.98 Northing ~ 5977705.57 5977708.64 DLS nOD!!! 4.00 0.00 E/-W J!2. -863.99 -827.93 Azim L 85.77 85.77 Incl 1 29.28 29.28 MD (ft) 5393.89 5467.83 Station ID 149.32983376 149.32795822 149.32765024 149.32732108 149.32731207 w w w w w N 70.34916474 N 70.34921146 N 70.34921914 N 70.34922734 N 70.34922755 582548.56 582779.38 582817.29 582857.80 582858.91 5977736.68 5977756.33 5977759.56 5977763.01 5977763.10 0.00 0.00 4.00 4.00 4.00 -498.03 -266.98 -229.04 -188.49 -187.38 24 -316.85 -299.76 -296.95 -293.95 -293.87 -341 874.61 545.49 314.98 277.13 236.68 235.56 50 5691.50 6104.72 6177.38 6268.72 6271.50 5101 85.77 85.77 85.77 85.77 85.77 29.28 29.28 26.00 22.00 21.88 6144.24 6617.98 6700.00 6800.00 6803.00 End Bid CM2 CM Orp 4/100 ) 149.32704435 149.32684653 149.32682129 149.32674953 149.32665317 w w w w w N 70.34923422 N 70.34923914 N 70.34923977 N 70.34924154 N 70.34924395 582891.85 582916.20 582919.31 582928.14 582940.00 5977765.90 5977767.97 5977768.24 5977768.99 5977770.00 4.00 4.00 4.00 4.00 4.00 -154.40 -130.03 -126.92 -118.08 -106.21 -291.43 -289.63 -289.40 -288.75 -287.87 202.66 178.35 175.24 166.43 154.58 6362.67 6446.50 6458.77 6496.50 6556.49 85.77 85.77 85.77 85.77 85.77 18.00 14.50 14.00 12.45 10.00 6900.00 6987.34 7000.00 7038.75 7099.92 Top HRZ Base HRZ 149.32665317 149.32663889 149.32602082 149.32580993 w w w w N 70.34924395 N 70.34924430 N 70.34925969 N 70.34926493 582940.00 582941.75 583017.82 583043.78 5977770.00 5977770.15 5977776.62 5977778.83 4.00 0.00 0.00 0.00 -106.21 -104.45 -28.31 -2.33 -287.87 -287.74 -282.11 280.19 154.58 152.83 76.87 50.95 6556.50 6566.50 6999.49 7147.22 85.77 85.77 85.77 85.77 10.00 10.00 10.00 10.00 7099.93 7110.08 7549.75 7699.76 K- Top Kuparuk End Orp /Target Kuparuk C Top Miluveach TO / 7" Csg Pt ) 1/30/2002-9:08 AM 58 582000.00 582940.00 583043.78 Page 3 of 3 Northin 5978059.00 5977690.00 5977770.00 5977778.83 2339 FSL 3874 FEL S34 T12N R11E UM 1981 FSL 4922 FEL S34 T12N R11 E UM 2051 FSL 3981 FEL S34 T12N R11 E UM 2058 FSL 3877 FEL S34 T12N R11 E UM tion: Surface Target Target BHL (P9) report.xls Schrader End Orp / L-111 ~ ~ VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska L-lll (P9) Structure: Section At: Date: Prudhoe Bay Unit - WOA L-Pad 260.00 deg January 30, 2002 Schlumberuer o ...................j'... i i I KOP Bid 1.5/100300 MD 300 TVD ······················/··O·.&)ò····z5ï·ls··ò·äi·()ïiëpäitüre··············· ~ ____ Bld2.5/100350MO 350TVD ~ 0.75Q 251~15oaz o departure Bid 4/100 fOO MD 400 TVD 2.00 0 251;15 Gaz 2 departure I i ... ..... ....................~...... 1000 ..-----1---.~-_.. I i ¡ i ¡ ¡ End ~Id 1402 MD 1310 TVD j .... .......7....... n. .......~4l;mt. -ZSt:t5<..-."..departuro--,.' --.---.---..--.---- I Hold Angle 42.0~ 0 ¡ Drp 4/100 1950 MD 1716 T~JD . 42.09 0 251.15 Gaz 728 dep~tture -r ---~--.............¡......... -- SV; ","7H !Ùf;) fG··~r. f:D'- ..... s~n 1T'-Ü!} MD n::<7 trJ[) -.... ¡ ..... Bfi;:~ rtÜ'n.m0~;C21irM!.r; ¡is:!"1 IJr)" -..--l--.------ ..... ~~~}~ ::'Tt') ~~ìr) 202"j ~'~;n'- ..... 2000 ._........~.._.;..~.....__..-_.~ .........¡........ ._.......~...._....__..__.___w ..j...- __. __ ._ ___ m_. . <vi (Xi2 ;1Ù x ':r; 1j:ve;-'" i --- ..... O)::J 2(/) 8:E o 0) ..... > o ..c co ; ..... ::~ví ?f)-12 \'1:) Ú;·tï·\i:VO·..· ¡ I i i ..-- -- UT4!>'-~~ 1 S"T"M¡;-;?&:V::vTf r i End D,p /9-518" Csg Pt 3002 MD 2676 TVD O.OOo!85.71°az i-Ö93 '~p~rt~re-' ! -- -- '.-- 3000 II C --- --.- ...- .-- ~ UG3 .h'i2" MiJ :i1~F lVn Hold Angl~ 00.00 0 ......:t:: _0 ..c~ ã.::e 0)- Oca ~ Cõ u.;..: '';:¡ 0) a>C:: > > 0) 0) ::JUJ t= TIG13~3T\1;T:~5 r¡Tv(f T-~-----t -~~-+ Hold Angle 29.28 0 . . ..... ..... ..... .....Sc!:!.ad':!'r.TadIet~~.62.~O ..~.23!.IVI?... ..... .J __.__. ßOOO A.E;nQ"'7 1D.93..depaJ1ur~_L ~-?_. ~d ~J10~. 46~ M!?_ 4~7 T~D._ .~ 1 ..~o.oo" 85T7oaz 1093departure j ._ .__ '_..~ BI~_2.5:QOO ~~62._~D __~33_~JVº : _____ ' 0.75 ° 15.71 °az 1093 departure ------ Bid 4/10C) 4712 MD 4386 TVD 2.00 ° 8~. 71 °az 1092 departure -r i 4000 ___..-.-M WSi44i'iM[)<1- r,¿n ..- V;S;4!i;!T~ß.,ì~:1 n1,) 0f,¡ ~jð'-t) "7;Ô:~C~ì,D ," ; 5000 -- - -- .[,.. UL-; 5 ·~&B t'"~O :; 1 \,2 End Bid 5394 MD 5037 TVD 29.28 ° 85.77"az ! 911 departure ..- -.- L. CM! ;);·14 \\1D 5\iJ2 T':G - -. -- -~ ..- - - -.- - 6000 I End Drp/Target . ............................+ ............?l.Qº.Mº...J¡.~.~.I.J.Y.º.... i 10.00 ° 85.77 °az ¡'" ¡'RT "",i, "!"i' l;ij';'~::PartU" ~L.: _.... :.1.: ..... ~I-JH.'" H~l ""jj, if€> cm T'JD--: ~: --: ~ --::::"I"::: ~ ; Drp ~/'OO ........ ~··i~:2'~~5i\9?~rY.º.... 315 ~eparture .L ...¡.. i , + f,~~jl:~,~"f 7000 TD/7"CsgPt i ...............l.lOO.MP.....lHl.IY. ?..... . 10.00" 85.77 "az i 51 departure i ...............!.... . ¡ <2000 -1000 0 1000 2000 Vertical Section Departure at 260.00 deg from (0.0. 0.0). (1 in 3000 1000 feet) ) Schlumberuer 200 200 o PLAN VIEW Client: BP Exploration Alaska Well: L-ll1 (P9) Field: Prudhoe Bay Unit - WOA Structure: L-pad Scale: 1 in = 200 ft Date: 30-Jan-2002 o -200 -400 -600 -800 1000 1200 200 09° True North Mag Dee E 26 o ^ ^ ^ :r: I- 0:: o Z ) -200 -400 300 MD 300 TVD O.(X)Q 25 ON 0 E 2W 280 5 Target End Drp TVD "az 85.77 6618 MD Hold End Drp 19 5/8" Csg 3002 M ºJ~Q.:... 357 S 'rTarQE I 4237 0.00 0 85.77 ca; -200 -400 :r: I- ~ o C/) V V V 357 S -600 200 o -200 EAST »> -400 -800 -600 <<< WEST 4662 MD 4336 TVD 0.75· 85.77 °az 357 S 1047 W -1000 -600 -1200 .~ .~ Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 It Depth Range: 28.50 to 7699.76 It Maximum Radius: 2000.00 It Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/26/2000 Validated: No Planned From To Survey It It 28.50 7699.76 Planned: Plan #9 V1 Version: 19 Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station Casing Points EX NWE#1 NWE1-01 NWE1-01 V3 1270.23 1250.00 83.86 29.07 56.85 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01A VO 1270.23 1250.00 83.86 29.11 56.83 Pass: Major Risk EX NWE#1 NWE1-02 NWE1-02 V2 399.37 400.00 180.65 6.81 173.84 Pass: Major Risk PB L Pad L-01 L-01 V14 347.27 350.00 221.16 5.51 215.65 Pass: Major Risk PB L Pad L-104 L-104 V7 345.76 350.00 354.06 5.68 348.38 Pass: Major Risk PB L Pad L-106 L-106 V14 390.02 400.00 325.51 6.10 319.44 Pass: Major Risk PB L Pad L-107 L-107 V14 149.99 150.00 236.42 3.31 233.11 Pass: Major Risk PB L Pad L-110 L-110 V11 348.63 350.00 105.82 6.15 99.66 Pass: Major Risk PB L Pad L-114 L-114 V14 349.59 350.00 30.32 5.38 24.94 Pass: Major Risk PB L Pad L-115 L-115V7 441.03 450.00 216.45 7.20 209.29 Pass: Major Risk PB L Pad L-116 L-116V10 348.29 350.00 135.85 5.32 130.52 Pass: Major Risk I PB L Pad L-117 L-117V11 348.12 350.00 226.02 5.32 220.70 Pass: Major Risk I PB L Pad L-120 Plan L-120 V5 Plan: PI 345.27 350.00 425.61 5.93 419.68 Pass: Major Risk ,,~ .~ L-111 i Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in both NWE offset wells and all eight Borealis wells to date. These are expected to be encountered near the base of the Permafrost at 2123'MD and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · A majority of the L-Pad development wells will have "kick tolerances" in the 35-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 10.0 pore pressure. Read the Shale Drilling Recommended Practice. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. · L-111 i will cross a fault in the UG3 at -3150' TVDss (+/-150'). The estimated throw of the fault is approximately 100'. The well will be _0° when crossing the fault. Loss circulation is considered to be a moderate risk. The second fault is at a depth of 4000' TVDss (+/-100') near the top of the Schrader. The estimated throw is 60'. The well will be _00 when crossing the fault. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE L-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies ,/"'--. ~ \ H 204438 DATE 01/17/02 CHECK NO. 00204438 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR ALASKAO I LA DISCOUNT NET 00 011602 CK011602E PYMT OMMENTS: HANDL I NG I NST: 100.00 100.00 ~ Per it to Drill ee S/H - Terrie Hub Ie X4628 Coos. Con1mÎ$SIon l-- - \ \ \1 TOTAL ~ rHE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 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 ClìY BANK CLEVELAND, OHIO No. H 204438 CONSOLIDATED COMMERCIAL ACCOUNT 56·389 4i'2 00204438 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 I I AMOUNT $100. 001 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 NOT VALID AFTER 120 DAYS A.. '/ ~vf1lt/. III 2 0 ~ ~ :18111 I: 0 ~ ¡. 2 0 :18 g 5 I: 008 ~ ~ ¡. gill /~ ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIER/PARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME Mtl i-III.' , CHECK 1 CHECK WHAT APPLIES STANDARD LEITER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL Tbe permit is for a new wellbore segment of existing weD -----.J Permit No, . API No. . (If api number last two (2) Production sbould continue to be reported as a function .of digits are between 60-69) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(1), aU records, data and REDRlLL logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API number (SO -70/80) from / records, data and logs acquired for well (name on permit). EXPLORATION ANNULAR DlSfOSAL Annular disposal has not been requested. . . \/0 1NJECTI07" ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . L..J YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . RED RILL THIS WELL DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L..J YES + SP ACING EXCEPTION Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume tbe liability of any protest to tbe spacing exception tbat may occur. . \\O-':¡~'9\\,~~\o"""~' ~~\-..,)~, c~-\-\-Q ~\.~~, ~-3\çl(~':) C).,,-\- ~ ~~ as ö')) \,) ,,~ ,,~~«:~. ~Jc ~"', ~ ....,-..~ \ ~ 'to ,().~~~~~~ ,,~~'\ ~ ~ ~~ c ~\C:o~"'-":>'t~V'Ç).~~ ~~\t~ c-\-~~"-~~~o.~\st \,,~'"~~\___~.. ~'("' d.." '-~.....") ~ ~ ~.\-~ ......~ ,,~~~~~<t;"';a: ~() ().\'\O""" Templates are locate }ndrJve\j~tem~ :-ç- ~ ~~ ~ -.N ~ tS.. <;. . Ann. disposal para req ON/OFF SHORE Redrll Dev PROGRAM: Exp .u/~ GEOLAREA UNIT# 1. Permittee 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 well bore plat included.. . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . 11. Permit can be issued without conservation order. . . 12. Permit can be issued without administrative approval 13. Can permit be approved before 15-day wait. e¡r WM"e-V reßc:.u<'ST€<i - - '2..1'2....2- ç,,¿' Mo..f< G<;" ~s) - -rt.<..Á ;.. ~ ~. ~~ - ~( ~M. Comments/Instructions: ) . . sig. 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 '¥CïOO 27. Choke manifold complies w/API RP-53 (May 84) . 28. Work will occur without operation shutdown. 29. Is presence of H2S gas probable. ) Permit can be issued w/o hydrogen sulfide measures. cÐN Data presented on potential overpressure zones . . . y ~ Seismic anal~~is of shallo~ gas zones. . . . . . .. ~.. A /Ý N Seabed condition survey (If off-shore). . . . . . . . . . . . . Y N Contact name/phone for weekly progress reports [explora only] Y N FIELD & POOL ADMINISTRATION :~~ 2~~;'~l- ENGINEERING APPR ~¡7, ~ ~. iP'Z- ~~ GEOLOGY 30. 31. 32. APPR DATE 33. -Þ- ~2- 34. ANNULAR DISPOSAL Y N ~ Y N - Y N Y N - Y N 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 (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION TEM ~~."; WGA WçA- DATE - APPR COT DTSo2/ ! I (a è JMH ðM f-T ~ 19 I o~ RPC_ SFD~ G:\geology\permits\checklist.doc
