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Home My WebLink About197-051Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -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 S-22B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-051 50-029-22119-02-00 12221 Conductor Surface Intermediate Liner Liner 8819 80 2651 5370 4248 2948 9197 20" 13-3/8" 9-5/8" 7" 4-1/2" 8561 35 - 115 34 - 2685 32 - 5402 5204 - 9452 9273 - 12221 35 - 115 34 - 2685 32 - 5167 5006 - 8795 8630 - 8819 12219 470 2260 4760 5410 7500 9197, 11700 1490 5020 6870 7240 7430 7120 - 12219 4-1/2" 12.6# L-80 30 - 9275 6679 - 8819 Structural 4-1/2" HES TNT Packers (2) 9187, 8552 / 9218, 8580 6985, 9067, 9187, 9218 6559, 8441, 8552, 8580 Torin Roschinger Operations Manager Leslie Reavis lreavis@hilcorp.com (907)777-8326 PRUDHOE BAY, Aurora Oil / Prudhoe 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 0028257, 0028258 30 - 8632 N/A N/A 803 732 450 725 1940 1356 N/A 13b. Pools active after work:Aurora Oil / Prudhoe Oil 4-1/2" Baker S3 Packers (2) 6985, 6559 / 9067, 8441 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 No SSSV Installed Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.11 21:15:09 - 08'00' Torin Roschinger (4662) By Grace Christianson at 11:57 am, Jun 12, 2024 DSR-6/12/24 RBDMS JSB 061924 WCB 8-30-2024 ACTIVITY DATE SUMMARY 5/30/2024 ***WELL S/I ON ARRIVAL*** RAN 20' x 2-7/8" D. GUNS(3.16" swell rings), 3.00" S. BLR (msfb), DRIFTED FREELY TO PX PLUG @ 9197' MD RAN 3.85" G-RING TO X-NIP @ 2188' SLM/2208' MD (+20' correction) LOGGED DUAL SPARTEK GAUGES PER PROGRAM ***JOB COMPLETE, WELL LEFT S/I*** 5/31/2024 ***WELL S/I ON ARRIVAL*** (ADPERF) RIG UP YJ ELINE PT PCE 300 PSI LOW /3000 PSI HIGH. FUNCTION TEST WLVS PERFORATE INTERVAL 7214'-7233' WITH GEO RAZOR XDP GUN 6SPF 60 DEG PHASE CCL TO TOP SHOT 8.5' CCL STOP DEPTH 7205.5' CORRELATED TO SLB PERFORATING RECORD DATED 17-NOV-2019 PERFORM WELL CONTROL DRILL WITH WSL RDMO YJ ELINE ***WELL S/I ON DEPARTURE, JOB COMPLETE *** Daily Report of Well Operations PBU S-22B PERFORATE INTERVAL 7214'-7233 Adperfs are shown correctly on WBS below. -WCB MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-22B PRUDHOE BAY UNIT S-22B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/01/2024 S-22B 50-029-22119-02-00 197-051-0 W SPT 6558 1970510 1640 2155 2155 2155 2155 162 283 283 280 4YRTST P Sully Sullivan 1/9/2024 tested with 120 deg diesel to 2933 psi for 500 psi differential 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 UNIT S-22B Inspection Date: Tubing OA Packer Depth 455 2933 2842 2824IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240110132622 BBL Pumped:6.2 BBL Returned:5.8 Friday, March 1, 2024 Page 1 of 1 9 99 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.03.01 15:22:30 -09'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-22B (PTD 197-051) WFL-TMD3D 03/15/2022 Report 3/16/2022 Please include current contact information if different from above. PTD:197-051 T36633 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.19 09:45:25 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/13/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-22B (PTD 197-051) TMD3D-WFL 2/17/2022 197-051 T36473 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.04.13 14:54:40 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: PBU S-22B (PTD 197-051) TMD3D-WFL 3/15/2022 Please include current contact information if different from above. 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: [EXTERNAL] RE: UNDER EVALUATION: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Date:Tuesday, April 5, 2022 8:22:09 AM Attachments:image001.png PBU_S-22B_22-Jan-22_InjectionProfile.pdf S-22B_WFL-TMD3D_17FEB21_Report.pdf S-22B_WFL-TMD3D_15MAR21_Report.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 2, 2022 12:38 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] RE: UNDER EVALUATION: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Mr. Wallace, Logs as requested. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, April 1, 2022 4:45 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: [EXTERNAL] RE: UNDER EVALUATION: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Andy, Your request to place S-22B back on injection is approved. Please send us a digital copy of the logs and temperature overlay for our records. 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, April 1, 2022 3:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: UNDER EVALUATION: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Mr. Wallace, Injector S-22B (PTD# 1970510) diagnostic logging has been completed. The water flow log looking for down flow behind pipe was completed on 3/15/2022. Downflow was seen in one of the three impulse tests taken at the 7261’ (MD) station with the well on injection at ~5000 BWPD. This downflow correlates with the injection profile temperature overlay from 1/22/2022 which shows all injection fluid entering the perforations from 7120’-7180’ MD, but indicates that some injection fluid is moving down the backside before entering the injection interval down to ~7300’ MD. These logs are evidence that there is no out of zone injection from the Kuparuk perforation zone. We request permission to place S-22B back on injection as an OPERABLE well. Please call with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 14, 2022 5:28 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, Injector S-22B (PTD# 197051) water flow logging is scheduled on 03/15/22 to determine possible out of zone injection. The well is now classified as UNDER EVALUATION and can be put on injection during logging operations. 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: Wednesday, February 23, 2022 8:14 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 02/17/2022, an incomplete water flow log was run to assess out of zone water injection. No up flow was observed behind pipe and the well was shut in. The well is now classified as NOT OPERABLE for tracking purposes until logging tools and equipment are available to log down flow behind pipe. 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: Friday, January 28, 2022 1:02 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 1/22/2022 an injection profile was completed in well S-22B (PTD #197-051) to investigate the possible failure of the plug at 9197’ MD isolating the Ivishak from the Kuparuk. The log shows the plug is holding and all of the injection is entering the Kuparuk perfs between 7120-7180’ MD. A shut-in MIT-IA passed to 2658 psi proving the competency of the PC, tubing and associated jewelry above the packer at 6985’ MD. The increased injection rate and the competency of the plug isolating the Ivishak leads us to the possibility that a conduit for out of zone injection was established from the Kuparuk perforation zone. The well will now be placed UNDER EVALUATION for tracking purposes until the reason for the increased injection rate can be suitably resolved. Plan forward: 1. WFL to determine if there is movement of fluid behind the 7” liner with the well on injection. Please respond with any questions. 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 havereceived 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 thismessage. 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. 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 anintended 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 thismessage 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 virusand 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: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Date:Friday, April 1, 2022 4:45:23 PM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Friday, April 1, 2022 4:45 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: UNDER EVALUATION: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Andy, Your request to place S-22B back on injection is approved. Please send us a digital copy of the logs and temperature overlay for our records. 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, April 1, 2022 3:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: UNDER EVALUATION: S-22B (PTD #1970510) Injection Rate Increase in Commingled Injector Mr. Wallace, Injector S-22B (PTD# 1970510) diagnostic logging has been completed. The water flow log looking for down flow behind pipe was completed on 3/15/2022. Downflow was seen in one of the three impulse tests taken at the 7261’ (MD) station with the well on injection at ~5000 BWPD. This downflow correlates with the injection profile temperature overlay from 1/22/2022 which shows all injection fluid entering the perforations from 7120’-7180’ MD, but indicates that some injection fluid is moving down the backside before entering the injection interval down to ~7300’ MD. These logs are evidence that there is no out of zone injection from the Kuparuk perforation zone. We request permission to place S-22B back on injection as an OPERABLE well. Please call with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 14, 2022 5:28 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, Injector S-22B (PTD# 197051) water flow logging is scheduled on 03/15/22 to determine possible out of zone injection. The well is now classified as UNDER EVALUATION and can be put on injection during logging operations. 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: Wednesday, February 23, 2022 8:14 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 02/17/2022, an incomplete water flow log was run to assess out of zone water injection. No up flow was observed behind pipe and the well was shut in. The well is now classified as NOT OPERABLE for tracking purposes until logging tools and equipment are available to log down flow behind pipe. 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: Friday, January 28, 2022 1:02 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 1/22/2022 an injection profile was completed in well S-22B (PTD #197-051) to investigate the possible failure of the plug at 9197’ MD isolating the Ivishak from the Kuparuk. The log shows the plug is holding and all of the injection is entering the Kuparuk perfs between 7120-7180’ MD. A shut-in MIT-IA passed to 2658 psi proving the competency of the PC, tubing and associated jewelry above the packer at 6985’ MD. The increased injection rate and the competency of the plug isolating the Ivishak leads us to the possibility that a conduit for out of zone injection was established from the Kuparuk perforation zone. The well will now be placed UNDER EVALUATION for tracking purposes until the reason for the increased injection rate can be suitably resolved. Plan forward: 1. WFL to determine if there is movement of fluid behind the 7” liner with the well on injection. Please respond with any questions. 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 havereceived 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 thismessage. 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. 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: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Date:Tuesday, March 15, 2022 8:05:52 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 14, 2022 5:28 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, Injector S-22B (PTD# 197051) water flow logging is scheduled on 03/15/22 to determine possible out of zone injection. The well is now classified as UNDER EVALUATION and can be put on injection during logging operations. 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: Wednesday, February 23, 2022 8:14 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 02/17/2022, an incomplete water flow log was run to assess out of zone water injection. No up flow was observed behind pipe and the well was shut in. The well is now classified as NOT OPERABLE for tracking purposes until logging tools and equipment are available to log down flow behind pipe. 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: Friday, January 28, 2022 1:02 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 1/22/2022 an injection profile was completed in well S-22B (PTD #197-051) to investigate the possible failure of the plug at 9197’ MD isolating the Ivishak from the Kuparuk. The log shows the plug is holding and all of the injection is entering the Kuparuk perfs between 7120-7180’ MD. A shut- in MIT-IA passed to 2658 psi proving the competency of the PC, tubing and associated jewelry above the packer at 6985’ MD. The increased injection rate and the competency of the plug isolating the Ivishak leads us to the possibility that a conduit for out of zone injection was established from the Kuparuk perforation zone. The well will now be placed UNDER EVALUATION for tracking purposes until the reason for the increased injection rate can be suitably resolved. Plan forward: 1. WFL to determine if there is movement of fluid behind the 7” liner with the well on injection. Please respond with any questions. 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 herebynotified 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. 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: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Date:Wednesday, February 23, 2022 10:20:10 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 23, 2022 8:14 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: NOT OPERABLE: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 02/17/2022, an incomplete water flow log was run to assess out of zone water injection. No up flow was observed behind pipe and the well was shut in. The well is now classified as NOT OPERABLE for tracking purposes until logging tools and equipment are available to log down flow behind pipe. 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: Friday, January 28, 2022 1:02 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 1/22/2022 an injection profile was completed in well S-22B (PTD #197-051) to investigate the possible failure of the plug at 9197’ MD isolating the Ivishak from the Kuparuk. The log shows the plug is holding and all of the injection is entering the Kuparuk perfs between 7120-7180’ MD. A shut- in MIT-IA passed to 2658 psi proving the competency of the PC, tubing and associated jewelry above the packer at 6985’ MD. The increased injection rate and the competency of the plug isolating the Ivishak leads us to the possibility that a conduit for out of zone injection was established from the Kuparuk perforation zone. The well will now be placed UNDER EVALUATION for tracking purposes until the reason for the increased injection rate can be suitably resolved. Plan forward: 1. WFL to determine if there is movement of fluid behind the 7” liner with the well on injection. Please respond with any questions. 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 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 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. 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: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Date:Monday, January 31, 2022 10:36:44 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 28, 2022 1:02 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Mr. Wallace, On 1/22/2022 an injection profile was completed in well S-22B (PTD #197-051) to investigate the possible failure of the plug at 9197’ MD isolating the Ivishak from the Kuparuk. The log shows the plug is holding and all of the injection is entering the Kuparuk perfs between 7120-7180’ MD. A shut-in MIT-IA passed to 2658 psi proving the competency of the PC, tubing and associated jewelry above the packer at 6985’ MD. The increased injection rate and the competency of the plug isolating the Ivishak leads us to the possibility that a conduit for out of zone injection was established from the Kuparuk perforation zone. The well will now be placed UNDER EVALUATION for tracking purposes until the reason for the increased injection rate can be suitably resolved. Plan forward: 1. WFL to determine if there is movement of fluid behind the 7” liner with the well on injection. Please respond with any questions. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/26/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-22B (PTD 197-051) Injection Profile 01/22/2022 Please include current contact information if different from above. Received By: 01/26/2022 37' (6HW By Abby Bell at 12:22 pm, Jan 26, 2022 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: [EXTERNAL] Re: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Date:Monday, January 24, 2022 3:29:40 PM From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, January 21, 2022 4:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: RE: [EXTERNAL] Re: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Hello Chris, We are working through the diagnostics on S-22B (PTD #197-051). The well had a passing MIT-IA to 2658 psi on 1/5/22 and has remained shut-in since 12/29/21. We began performing slickline diagnostics yesterday, drifting to the plug set at 9197’ MD that isolates the Ivishak from the Kuparuk. During the slickline drift, we noted a SI tubing pressure of ~650psi with a full column of fluid which is higher than what we would normally expect if the well was communicating with both the Kuparuk and Ivishak formations. For this reason, before we pull and reset XX plug at 9197’ MD, we plan to perform an injection profile. If the IPROF confirms that the plug is failed we will pull and reset it to reestablish isolation. Please let me know if you have any questions. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, January 3, 2022 1:54 PM To: Wyatt Rivard <wrivard@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: [EXTERNAL] Re: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Wyatt, We approve the planned path forward for this well. 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. Regards, Chris From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, December 30, 2021, 3:13 PM To: Wallace, Chris D (OGC); Roby, David S (OGC); PB Wells Integrity; John Condio - (C) Subject: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector All, Kuparuk/Ivishak injector S-22B (PTD # 197051) experienced an increase in injection rate on 12/29 going from ~500 BPD to ~5000 BPD and was shut-in. IA/OA pressures showed a thermal response due to the increased injection rate but did not show any form of communication. Rate increase corresponds to a likely loss of isolation between Kuparuk and Ivishak injection zones but there is no indication of an integrity issue. Since the well’s workover and conversion to commingled injector in 2019 the well has only been on Kuparuk injection with the Ivishak isolated by a plug set in the X profile at 9197’ MD (schematic attached). Increased injection rate correlates to previous Ivishak injection of over 4,000+ bwpd with the addition ~500 bwpd of Kuparuk injection. At this time, it is desirable to maintain injection to the Kuparuk only for reservoir management and there is no near term plan to commingle with the Ivishak. Going forward SL will pull and reset the retrievable plug to reestablish isolation. Path Forward MIT-IA to 2500 psi. SL to pull and reset XX plug at 9197’ MD. Return well injection. Perform IPROF if injection rate stabilizes above ~500 bpd at similar injection pressures. Please let me know if you have any questions, Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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, pleaseimmediately 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. 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: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Date:Monday, January 3, 2022 2:47:58 PM Attachments:S-22B.pdf S-22B TIO 12-30-21.jpg From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, January 3, 2022 1:54 PM To: Wyatt Rivard <wrivard@hilcorp.com>; Roby, David S (OGC) <dave.roby@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: Re: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector Wyatt, We approve the planned path forward for this well. Regards, Chris From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, December 30, 2021, 3:13 PM To: Wallace, Chris D (OGC); Roby, David S (OGC); PB Wells Integrity; John Condio - (C) Subject: S-22B (PTD #197-051) Injection Rate Increase in Commingled Injector All, Kuparuk/Ivishak injector S-22B (PTD # 197051) experienced an increase in injection rate on 12/29 going from ~500 BPD to ~5000 BPD and was shut-in. IA/OA pressures showed a thermal response due to the increased injection rate but did not show any form of communication. Rate increase corresponds to a likely loss of isolation between Kuparuk and Ivishak injection zones but there is no indication of an integrity issue. Since the well’s workover and conversion to commingled injector in 2019 the well has only been on Kuparuk injection with the Ivishak isolated by a plug set in the X profile at 9197’ MD (schematic attached). Increased injection rate correlates to previous Ivishak injection of over 4,000+ bwpd with the addition ~500 bwpd of Kuparuk injection. At this time, it is desirable to maintain injection to the Kuparuk only for reservoir management and there is no near term plan to commingle with the Ivishak. Going forward SL will pull and reset the retrievable plug to reestablish isolation. Path Forward MIT-IA to 2500 psi. SL to pull and reset XX plug at 9197’ MD. Return well injection. Perform IPROF if injection rate stabilizes above ~500 bpd at similar injection pressures. Please let me know if you have any questions, Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, R, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 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 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. 1 Winston, Hugh E (CED) From:Rixse, Melvin G (CED) Sent:Friday, August 21, 2020 4:45 PM To:Winston, Hugh E (CED) Subject:FW: S-22B (PTD #197-051) plug Attachments:S-22B.PDF Hugh, I have the following correction that should be added to the file. Can this email be scanned in and the schematic updated in Laserfiche without additional forms? Mekl From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Friday, August 21, 2020 4:34 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: S‐22B (PTD #197‐051) plug Mel, We did a rig workover and added perforations in a new pool late 2019. Unfortunately, an existing plug (9197’) was removed from the schematic and our database between the 10‐403 and 10‐404 submittals so it wasn’t included in the post rig workover / perforations 10‐404’s. Please see attached for the updated schematic which has the plug with the original date set. If you have any questions, please don’t hesitate to let me know. Thanks! Thanks, Joe 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. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operation t ,,[[��n^^'.�.11�� {{//�� (� ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change ppPrdrliMT V ❑ Plug for Reddll ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Sus Well ❑ Commingle Kuparuk & Other: p Ivishak Pools 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 197-051 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ ServiceO 6. API Number: 50-029-22779-02-00 7 Property Designation (Lease Number): ADL 028257 & 028258 8. Well Name and Number: PBU 5-22B 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL/PRUDHOE BAY, AURORA OIL 11. Present Well Condition Summary: Total Depth: measured 12221 feet Plugs measured 11700 feet true vertical 8819 feet Junk measured 12218 feet Effective Depth: measured 11700 feet Packer measured 6985, sass. 9187. 921a feet true vertical 8858 feet Packer true vertical 6559.8440.8552. 8580 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 79 20" 35-114 35-114 1490 470 Surface 2651 13-3/8" 34-2685 34-2685 5020 2260 Intermediate 5372 9-5/8" 30-5402 30-5167 6870 4760 Liner 4248 7" 5204-9452 5006-8795 7240 5410 Liner 2948 4-1/2" 9273-12221 8630-8819 7430 7500 Perforation Depth: Measured depth: 7120-12219 feet True vertical depth: 6679-9007 feet Tubing (size, grace, measured and We vertical depth) 4-1/2" 12.6# L-80 28-9275 28-8632 4-1/2" HES TNT Perm Packer 6985 65594-1/2" Packers and SSSV (type, measured and HES TNT Perm Packer 9066 8440 true vertical depth) 4-1/2" Baker S-3 Perm Packer 9187 8552 4-1/2" Baker Hydro Set Packer 9218 8580 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: 605 950 1700 14. Attachments (required per 20 nac 25.07026.07,&25.253) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319502 Authorized Name: Lastufka, Joseph N Contact Name: Allely, Josh Authorized Title: M Spe lis Contact Email: Josh.Allely@bp.com Authodzed Signature: Date: ?j2 Contact Phone: +1 907 564 5732 Form 70-404 Revised 04/2017 „�^ 'l3DMS!±'"y JAN 2 d 2020 Submit Original Only Daily Report of Well Operations PBU S -22B ACTIVITVDATF e" RARAAMv ***WELL S/I UPON ARRIVAL*** (Post RWO) STANDBY FOR LRS TO COMPLETE WORK & RDMO. R/U SLICKLINE SWCP #4522 FOR POST RWO. 11/12/2019 ***JOB CONTINUED ON 13-NOV-2019*** *** WSR continued from 11/11/19 *** (LRS Unit 46 - Circ Well / Drop Ball & Rod / Set Packer / MIT- T / MIT -IA) Pumped the following down the IA, taking returns up the Tubing, to J -19's Flowline: 5 BBLS 60/40 Meth Spear 217 BBLS Corrosion Inhibited I% KCL 355 BBLS 130*F Diesel U-tube Tx IA for 1 hour. Freeze Protect Outlet Well S -19's Flowline with 25 bbls 60/40 meth. ****Drop Ball & Rod**** MIT -T **PASSED ** to 3624 psi. Max applied = 3850 psi. Target = 3600 psi. Pumped 2.39 bbls dsl down tbg to set packers and reach test pressure. Test # 1 15 min T lost 141 psi 30 min T lost 49 psi. Bled TP back to 1500 psi. Bled back 1.1 bbls. MIT -IA** PASSED** to 3701 psi Max Applied 3850 psi Target=3600 psi. Pressured IA to 3818 psi with 7.1 bbls of diesel. MIT -IA lost 81 psi in the 1st 15 min and 36 psi in the 2nd 15 min for a total of 117 psi during a 30 minute test. Bled T/IA to 0/0 psi recovering —7.9 bbls SV/SSV/= Closed MV=Open CV's= OTG HLV's=Closed tags Hung on well. Pad -op notified of well status upon LRS departure. 11/12/2019 FWHP's=0/0/20 ****CONT. JOB FROM 11/12/19**** (Post RWO) PULLED B&R FROM RHC @ 9,086' SLM / 9,101' MD PULLED STA #2 BK-DGLV FROM 5,502' SLM / 5,513' MD PULLED STA #3 BKP-SHEAR FROM 3,507' SLM / 3„523' MD SET STA #3 BK-LGLV & STA #2 BK-OGLV PULLED 4-1/2" RHC -M FROM 9,086' SLM / 9,101' MD DRIFTED W/ 20'x 2-7/8" DUMMY PERF GUNS, 2.75" LIB, S/D @ 9,181' SLM (No issues) 11/13/2019 ****WELL LEFT S/I & PAD -OP NOTIFIEDOF STATUS UPON DEPARTURE**** ***WELL SHUT IN ON ARRIVAL*** (SLB ELINE JEWELRY LOG/PERF/SBHPS) RIG UP ELINE. ATTEMPT TO PT LUBE. UNABLE TO ACHIEVE PASSING PT. GREASE CREW SERVICE VALVES AND APPLY HEAT. DAY CREW ONLY. RIG DOWN ELINE PCE. HAND WELL OVER TO GREASE CREW TO INVESTIGATE TREE. 11/15/2019 ***JOB CONTINUED ON 16 -NOVEMBER -2019*** ***JOB CONTINUED FROM 15 -NOVEMBER -2019*** (SLB ELINE JEWELRY LOG/PERF) PERFORATE 7,149'- 7,180' ELMD WITH 2-7/8" POWERJET OMEGA, 6 SPF, 180 SHOTS, 60 DEG PHASED. 11/16/2019 ***JOB CONTINUED ON 16 -NOVEMBER -2019' ***JOB CONTINUED FROM 16 -NOVEMBER -2019*** (SLB ELINE PERF/SBHPS) PERFORATE 7,120'- 7 149' EL WITH H 2_975"-P OWERJET OMEGA, 6 SPF, 169 SHOTS, 60 DEG PHASED. LOG SBHPS. PERFORM 15 MIN STATION STOPS AT 7,329' MD (6,800' TVD), 7,217' MD (6,700' TVD), 7,105' MD (6,600' TVD), AND 6,993' MD (6,500' TVD). MAX BHP = 2,500 PSI, MAX BHT = 144 DEGF, PRESSURE GRADIENT = 0.37 PSI/FT. 11/17/2019 ***JOB COMPLETE ON 17 -NOVEMBER -2019' LRS Well Test Unit 6. Post Rig Injector Flowback/ Rate Verification/ Well Test. Begin WSR 12/14/19. Initial TI00, 0, 0, Begin Unit Move, SB for Dirt Work on S -Pad Long Row, Spot Unit, Rig Up, PT, POP, Flow/ Stabilize Well. Inlet Well S-22, Outlet Well S-19. Job in Progress, Continued on 12/14/2019 WSR 12/15/19. Daily Report of Well Operations PBU S -22B LRS Well Test Unit 6. Post Rig Injector Flowback/ Rate Verification/ Well Test. Continued from WSR 12/14/19. Continue to Flow/ Stabilize Well, Well Began U -Tubing Gas, Shut-in GL & Let Well Die off, Divert to Tanks/ Flow to Atmosphere, DHD Called Out, Cont. to Flow to Atmosphere, Shut-in Well & Begin Stacking Out w/ Gas, POP Well, Surge Well to Test Separator. Inlet Well S-22, Outlet 12/15/2019 Well S-19. Job in Progress, Continued on WSR 12/16/19. LRS Well Test Unit 6. Post Rig Injector Flowback/ Rate Verification/ Well Test. Continued from WSR 12/15/19. Continue to Surge Well to Test Separator, Shut-in Well & Stack Out w/ Gas, Surge Well To Test Separator, Divert to FB Tank & Flow to Atmosphere, Shut-in Well & Stack Out & Hold before POP, POP Well, Shut-in Well & Stack Out. Inlet Well S-22, Outlet Well S-19. Job in 12/16/2019 Progress, Continued on WSR 12/17/19. LRS Well Test Unit 6. Post Rig Injector Flowback/ Rate Verification/ Well Test. Continued from WSR 12/16/19. Continue to Surge Well to Test Separator, Shut-in Well & Stack Out w/ Gas, Surge Well To Test Separator, Divert to FB Tank & Flow to Atmosphere, Shut-in Well & Stack Out & Hold before POP, POP Well, Shut-in Well & Secure Wells & Test UNit due to Phase Weather. Inlet Well 12/17/2019 S-22, Outlet Well S-19. Job in Progress, Continued on WSR 12/18/19 LRS Well Test Unit 6. Post Rig Injector Flowback/ Rate Verification/ Well Test. Continued from 12/18/2019 WSR 12/17/19. RDMO. Inlet Well S-22, Outlet Well S-19. Job Complete/ End WSR. ***WELL S/I ON ARRIVAL***(rwo capital) SET 4 1/2" X -CATCHER IN X -NIPPLE @ 6,956' MD PULLED BK-S/O FROM STA #2 @ 5,513' MD PULLED BK-LGLV AND SET BK-DGLV IN STA #3 @ 3,523' MD 12/21/2019 ***CONT WSR ON 12/22/19*** ***CONT WSR FROM 12/21/19*** (rwo capital) LRS LOADED IA W/ 340bbls DIESEL SET BK-DGLV IN STA #2 @ 5,513' MD PULLED EMPTY 41/2" X -CATCHER FROM X -NIPPLE @ 6,956' MD LRS PERFORMED PASSING MIT -IA TO 2645psi 12/22/2019 ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED UPON DEPARTURE*** T/I/O = 640/772/0. Temp = SI. AOGCC MIT -IA PASSED to 2674 psi. Max Applied Pressure = 2750 psi, Target pressure = 2500 psi (Waived by AOGCC Brian Bixby). IA FL @ surface. Used 4.5 bbl of diesel to pressure IA to 2750 psi. IAP lost 59 psi in 1st 15 min and 17 psi in 2nd 15 min for a total loss of 76 psi in 30 min. Bled IAP from 2674 psi to 770 psi in 8 min (3.7 bbls). Continued to bleed IAP to 200 psi. Monitored for 30 min. IAP increased 100 psi Tags hung. Final WHPs = 638/300/0. 12/24/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 T/I/O = 610/240/50. Temp = SI. POI Watch (Assist Ops). IA FL @ surface, OA FL @ near surface. Monitor WHPs after well P01, bleed IAP & OAP as necessary (2.6 bbis). 1/4/2020 ***Job continued on 1/5/20*** ***Continued from 1/4/20*** T/I/O = 1190/460/280. Temp = 124. POI Watch (Assist Ops). IA & OA FL's @ surface. Monitor WHPs after well P01, bleed IAP & OAP as necessary (3.5 bbls total). FWHPs = 1290/320/100. 1/5/2020 SV = C. WV, SSV, MV = O. IA, OA = OTG. 06:00. T/I/O = 1251/0/63. Temp = 122°. AOGCC MIT -IA PASSED to 2658 psi, MaxPressure = 2750 psi, Target Pressure = 2500 psi. State witnessed by Bob Noble. IA su ace. sed 6.5 bbls o DSL to pressure up IAP from 0 psi to 2748 psi. IAP lost 71 psi in the 1st 15 minutes & 19 psi in the 2nd 15 minutes for a total loss of 90 psi in 30 minutes. Bled IAP from 2658 psi to 200 psi (5.2 bbls). Monitored while rigging down, IAP increased 100 psi. Hung tags. Final WHPs = 1250/300/60. 1/10/2020 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:00 TREE = 4-1/16" GE WELLHEAD= FMC-GEN2 ACTUATOR= MACH OKS. ELEV = 65.5' REF ELEV = 65.5' BF. ELEV = 35.92' KOP = 3350' Max Angle = 99' 99 11877 Datum MD = 9529' Datum TVD= 8800'SS 9-5/8' X 7" BKR ZXP PKR W/ TIEBACK, D = 7.50" 5204' SAFETY NOTES: H25 READINGS AVERAGE 125 ppm 011991 S WHEN ON M1. IOVELL REQWRESA SSSYWN NON MI 9-5/8" X 7" BKR HMC LNR HGR ID = 625" _2 WELL> 70" @ 9778'. _ 1126/19 MSS/JMD GLV CAO 11/13/19 9-58" CSG, 47#, L-80, D = 8.681' 6402' 6985' 2208' 4-12' HES X NP, D = 3.613' t_:_ N-0DR2 RWO 1226119 JPK/JMD GLV C/O 1222119 13-3/8'CSG, 2685' 4-12'HESX NP,D=3.813' GAS LIFT MANDRELS 5402'-5418' (OFF WHPSTOCK) 9039' V TWE VLV LATCH TVD713 PORT DATE^ 389, L80, 7' X 4-12' HES TNT PKR, D = 3956° 3 3523 3518 DCK-2 DMY BK 0 1222/19 HES X NP, D = 3.813' 4-12" TBG,12.6#, L-00 VAM TOP, .0152 bpf, ID = 3.958' 912W cMD 5513 5256 KBG DMY BK 0 1222119 9-5/8' X 7" BKR ZXP PKR W/ TIEBACK, D = 7.50" 5204' I 011991 N -18E ORIGINAL COMPLETION 11/14/19 JLS/JMD TREE C/0(11/05119) 6956' 4-12' HES X NP, D = 3.813' 9-5/8" X 7" BKR HMC LNR HGR ID = 625" 6218' SIDETRACK(S-22B) 1126/19 MSS/JMD GLV CAO 11/13/19 9-58" CSG, 47#, L-80, D = 8.681' 6402' 6985' 7'X4-12' HES TNT PKR, D = 3.856° N-0DR2 RWO 1226119 JPK/JMD GLV C/O 1222119 7019' 4-12'HESX NP,D=3.813' 9-518" MLLOUFVM DOW 5402'-5418' (OFF WHPSTOCK) 9039' 4-12' HES X NP, D =3.813' 9067' 7' X 4-12' HES TNT PKR, D = 3956° 9101'4-12' HES X NP, D = 3.813' 4-12" TBG,12.6#, L-00 VAM TOP, .0152 bpf, ID = 3.958' 912W 14-1/2' RCT TBG CUT(08H 3/18) 9130' 91 44' T X 4-12' UNQUE OVERSHOT Minimum ID = 3.726" @ 9263' z 9184' 7" X 4-12' BKR S-3 PKR D = 3.875' 4-1/2" HES XN NIPPLE 9197' 4-12" H6X NP, D=3.813" 4-1/2" TBG, 12.6#. L-80 NSCT, .0152 bpf, D = 3.958" 9208' 9208' 4-12" HES X NP, D = 3.813" j 9214' 7"X4-12" UNIQUE OVERSHOT 9218' 7" X 4-12' BKR S-3 PKR D = 3.850" 7'X 5- BKRZXP PKR W/TIEBACK, ID = 5.250' 9273' 9241' 4-12" FES X NP, D = 3.813" 4-1/2' TBG, 12.6#, L -8D, .01522 bpf, D = 3.958" 9276' 7" LNR 269, L-80-0383 bpf, D = 6276" 9462' IX I9283' 4-12" FES XN NP, D = 3.725' 9276' a-vz^1ALEG,D=a.00^ PERFORATION SUMMARY REF LOG: CDRIARC5AMPULSE ON 0626-07/0887 9283' ELMD TR ANGLE AT TOP PERF: 27'@ 7120' Nate: Referto Pmdwbon DB fpr listorical i erfdate SIZE SPF INTERVAL OprUSqz DATE 2-78" 6 7120-7149 O 11/17/19 2-78" 6 7149-7180 O 11/16/19 11700'[4-1/2^wFT CBP (o1l17/15) 338" 6 9456-9476 O 9121109 2-78" 6 9584-9594 O 102Po9 11889' BKR CTC ECP PKR 2-78" 6 9594-9604 O 10/1109 2-78" 6 9614-9634 O 10/1109 -12219' HFISH:CIBPPUSHED 2-78" 1 9630-9650 O 122487 DH (01/17/15) 2-7B' 6 9642-9662 O 10/1/09 2-78" 6 9700-9710 O 1011/09 PBTD12219' 2-78" 6 9710-9740 O 9/30/09 2-78" 1 9720-9740 O 1280197 2-71B" 1 11070-11090 O 128087 2-78" 1 11120-11140 O 12130/97 2-78" 1 11170-11190 0 1213a97 SLT 11927-12219 SLTD 4-12" LNR 12.6#, L-80,.0152, .0152 bpf, D = 3.958^ j 11927' TOP OF 4-12" SLOTTED LNR D = 3.958^11927' 4-1/2' SLOTTED LNR, 12.6#, .0752, .0152 bpf, D= 3.958' 12221' DATE REV BY COMMENTS DATE REV BY COMMENTS 011991 N -18E ORIGINAL COMPLETION 11/14/19 JLS/JMD TREE C/0(11/05119) 068993 SIDETRACK (S -22A) 1126/19 RC/JMD FINAL ODE APPROVAL 0711297 SIDETRACK(S-22B) 1126/19 MSS/JMD GLV CAO 11/13/19 062791 RWO 1126119 BTNIJMD ADPERFS (11116-17/19) 1195119 N-0DR2 RWO 1226119 JPK/JMD GLV C/O 1222119 11/14/19 JLS/JMD TREE C/O (11M5/19) f 15"kY PRUDHOE BAY UNIT WELL: S -22B PERMIT No: '1970510 API No: 50-029-22119-02 BP Expbra6on (Alaska) WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: S -22B Run Date: 11/2/2019 19705; 3 194 7 January 2, 2020 The technical data Iisted below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 S -22B Data in LAS format, Digital Log Image files 50-029-22119-02 RECEIVRED JAN 2 2 2020 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and Date: OhV20 Wallace, Chris D (CED) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Friday, January 10, 2020 3:01 PM To: AK, GWO Well Integrity Engineer; Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW, AK, OPS WELL PAD W,' AK, OPS Well Pad Z, Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Draughon, Austin; Duong, Lea; Peru, Cale, Rupert, C. Ryan; Wellman, Julie; Youngmun, Alex Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; O'connor, Katherine; Roma, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector S -22B (PTD #1970510) Post initial injection AOGCC MIT -IA Passed All, Wag Injector S -22B (PTD #1970510) recently was put on initial injection and AOGCC witnessed MIT -IA Passed on 01/10/20. The passing MIT confirm two competent barriers to formation and the well is now classified as OPERABLE. Plan forward: 1. Slickline/Fullbore —Drop Ball and Rod/Set Packers— Done 2. Slickline —Set LGLVs, pull TTP— Done 3. Eline—Add Perforations -Done 4. Portable Well Test Unit—Temporary Flowback -Done 5. Slickline/Fullbore: Set DGLVs, Perform pre injection AOGCC witnessed MIT -IA- Done 6. Operations: Put on Injection- Done 7. DHD: Perform post injection AOGCC witnessed MIT -IA- Done Please respond with any questions. Ryan Holt Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-5102 From: AK, GW ell Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, Decem 3, 2019 6:50 AM To: AK, GWO Well Integrity neer<AKGWOWellSiteEnginee@bp.com>;'chris.wallace@alaska.gov' <chris.waIlace @alaska.gov>; AK, O Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 <AKOPSGC20SM@bp.com>; AK, OPS GJ Wellpad Lead <AKOPSGC2WeIIpadLead @bp.com>; AK, OPS PCC Ops Le KOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AK IIPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@b >; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; A , S WELL PAD S MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector Well Name PRUDHOE BAY UNIT S -22B Insp Num: mitRCN200111145929 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Thursday, February 6, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. S -22B PRUDHOE BAY UNIT S -22B Src: Inspector Reviewed By: P.I. Suprv�y--Rlr— Comm API Well Number 50-029-22119-02-00 Inspector Name: Bob Noble Permit Number: 197-051-0 Inspection Date: 1/10/2020 Packer Well S -22B Type Inj w TVD PTD 1970510 Type Testj SPT Test psi BBL Pumped: 6.5 BBL Returned: Interval INITAL IP/F Notes: initial MIT -IA, Post RWO lepth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6558 Tubing' 1251 L'?' 1253 1251 ' 1640 IA 0 2778 2677 2658 OA 63 131 131- 131' P Thursday, February 6, 2020 Page I of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Friday, December 13, 2019 8:50 AM To: AK, GWO Well Integrity Engineer; Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW, AK, OPS WELL PAD W; AK, OPS Well Pad Z, Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Pipeline Compl Specialist; AKOpsProdEOCTL; Draughon, Austin; Duong, Lea; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Wellman, Julie; Youngmun, Alex Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector S -22B (PTD #1970510) Post rig flowback Em Wag Injector S -22B (PTD #1970510) recently had a rig workover on 11/04/19 with new completion string. On 11/12/19 after CDR2 ran the new completion, Slickline and Fullbore set the packers and performed a passing MIT -T to 3,624 psi and passing MIT -IA to 3,701 psi. The passing MITs confirm two competent barriers to formation and the well is now classified as UNDER EVALUATION. Prior to putting the well on injection, the plan is to flow the well through a portable test unit to clean the perforation zone. Plan forward: 1. Slickline/Fullbore — Drop Ball and Rod/Set Packers — Done 2. Slickline— SetLGLVs,pullTTP — Done 3. Eline—Add Perforations - Done 4. Portable Well Test Unit—Temporary Flowback 5. Slickline/Fullbore: Set DGLVs, Perform pre injection AOGCC witnessed MIT -IA 6. Operations: Put on Injection 7. DHD: Perform post injection AOGCC witnessed MIT -IA Please respond with any questions. Ryan Holt Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-5102 From: AK, Well Integrity Engineer <AKGWOWelISiteEnginee@bp.com> Sent: Tuesday, Augus 018 6:56 AM To:'chris.wa[lace@alaska.gov �wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FaclftYCL L@bp.com>; AK, OPS GC2 Field 0&M TL <AKOPSGC2Fie IdOMTL1@bp.com>; AK, OPS GC2 <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lea PSPCCOpsLead@bp.com>; AK, OPS Prod Controllers STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ; M 7 7 9M0 ;r. 1. Operations Performed -- - Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 op epJ,@�ti((9911��)9ss��pptly--11.4tltll1ppaamm,- Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Ch9n�el4¢pfbbad'PQ ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 197-051 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 6API Number 50-029-22119-02-00 T Property Designation (Lease Number): ADL 028257 & 028258 8. Well Name and Number: PBU S -22B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071j: 10. Field/Po)ls: Cement Evaluation PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 12221 feet Plugs measured 11700 feet true vertical 6819 feet Junk measured 12219 feet Effective Depth: measured 11700 feet Packer measured 6998, 9066, 9187, 9218 feet true vertical 8858 feet Packer true vertical 6570, 8440, 8552, 8580 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 35-114 35-114 1490 470 Surface 2651 13-3/8" 34-2685 34-2685 5020 2260 Intermediate 5372 9-5/8" 30-5402 30-5167 6870 4760 Liner 4248 7" 5204-9452 5006-8795 7240 5410 Liner 2948 4-1/2" 9173-12221 8630-8819 7430 7500 Perforation Depth: Measured depth: 7120-12219 feet True vertical depth: 6679-8819 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 28-9275 28-8632 4-1/2" HES TNT Perm Packer 6998 6570 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 9066 8440 true vertical depth) 4-1/2" Baker S-3 Perm Packer 9187 8552 4-1/2" Baker Hydro Set Packer 9218 8580 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: 0 0 0 0 14. Attachments: (required per 20 MC 25.070.25.071, s 25203) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: OiI ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-176 Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: S Special t Contact Email: Ryan.Ciolkosz@bp.com K, Authorized Signature: z2Date: b ,9 Contact Phone: +1 907 564 5977 Form 10-404 Revised 04/2017 .1"1 /7Mlr" m&tWA 12 -AgDMS - Lfft'NOV 2 6 2019 Submit Original Only T/1/0= Vac/190/70 Temp= S/I (LRS Unit 72 - Assist Slickline: OA Integrity Test, CMIT) OA Integrity Test PASSED Pumped 6.4 bbls crude down OA to reach pressure of 1159 psi, OA lost 41 psi in 1st 15 min and 11 psi in 2nd 15 min for a total loss of 52 psi, Bleed OAP, Bled back 1.5 bbls, Pumped 5 bbls 50/50 spear followed with 203 bbls 120* 1% KCL, 1 bbls 50/50, 38 bbls diesel down TBG to load and FP, CMIT-TxIA- PASSED at 2709/2723 psi, (2750 psi Max, 2500 psi target) Pumped 18.7 bbls diesel down T/IA to reach test pressure, T/IA lost 8/4 psi in 1 st 15 min and 5/3 psi in 2nd 15 min for a total loss of 13/7 psi in 30 min test, Bleed T/IA pressure, Bled back — 5 bbls, AFE sign and tags hung on well, SSL in control of well at departure- 8/10/2018 FWHP= 495/498/82 ***WSR CONTINUED FROM 8/9118*** (RWO) LRS PERFORMS PASSING OA INTEGRITY TEST. B&F TBG w/ 4-1/2" BRUSH, 3.80" G-RING TO TAG XN-NIP @ 9,263' MD. LRS LOADED TBG w/ 203 bbl 1% KCL & 38 bbls DIESEL. SET 4-1/2" PX-PLUG @ 9,197' MD. (Check Set sheared) LRS PERFORMED PASSING 2,500 psi CMIT. (Made 3 attempts before pass) ***JOB COMPLETE, WELL LEFT S/I*** 8/10/2018 ***DRIFTED TO 3,000'w/ 20'x 3.70" FOR SUBSIDENCE SURVEILLANCE*** ***WELL 9/1 ON ARRIVAL*** (SLB ELINE TUBING PUNCH / RCT CUT) INITIAL T/1/0 = 400/500/50. RUN 1: PUNCH TUBING 9118'- 9123' W/ 1.56", 4 SPF, 0 DEG PHASE, SMALL CHARGE PUNCHER. MPD AND BOW SPRING. CCL TO TOP SHOT = 5.6', CCL STOP DEPTH = 9112.4' RUN 2: RIH W/ 2.5" POLLARD RCT & CUT TBG AT 9130'. POOH & BEGIN R/D. CCL TO CUTTER = 135, CCL STOP DEPTH = 9116.5' ALL LOGS CORRELATED TO SLB PERFORATION RECORD DATED 12-SEPT-2009 8/13/2018 ***JOB CONTINUED ON 14-AUG-2018*** ***JOB CONTINUED FROM 13-AUG-2018*** COMPLETE R/D. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 240/150/50. 8/14/2018 ***JOB COMPLETE 14-AUG-2018*** (LRS Unit 70 - CMIT, Circ Out) Travel to location and stage eguipment. ***WSR continued 8/14/2018 on 08-15-18*** ***WSR continued from 08-14-18*** T/1/0= 230/173/88 Temp= S/I (CMIT-TxIA / Circ-Out) CMIT-TxIA PASSED to 2698/2702 psi. Target pressure = 2500 psi, Max Applied Pressure = 2750 psi. Pumped 6.4 bbls 60* crude to reach 2740/2745 psi. TxIA lost 30/30 psi in the 1st 15 minutes and lost 12/13 psi in the 2nd 15 minutes for a total loss of 42/43 psi. Bled TxIA pressure down S-01 flowline. Pumped 5 bbls 50/50 meth followed 712 bbls 1 % kcl down tbg and up IA to S-01 to circ. Pumped 172 bbls diesel down IA and up tbg to FP. U-tube TxIA for 1 hr. Freeze protected F/L of S-01 with 10 bbls 50/50 10 bbls crude and 13 bbls diesel. Bled TxIA to 100 psi. Final WHP's 90/97/59 SV,WV ,SSV=closed MV,IA,OA=open SV,WV,SSV=closed on S-01 All 8/1512018 Itags hung AFE sign on well FP tag on S-01 Pad op notified Daily Report of Well Operations PBU S -22B T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL), pre pulling unit. PPPOT-T: Stung into test port (100 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely, torqued to 450 Ib/ft. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (300 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely, torqued to 450 Ib/ft. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 600 psi in 15 8/17/2018 min, lost 400 psi in second 15 min (FAIL). Bled void to 0 psi. PPPOT-IC: Stung into IC test port (0 psi). Monitored for 10 min, no change in pressure. Torqued LDS to 600 Ib/ft (as per FMC Keith). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 75 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 5/4/2019 TWO = SSVNAC/80. Temp = SI. Assist Cameron (LPE-I(;). Assisted Cameron tech with torquing of LDS and performing PPPOT on IC void. 5/4/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 T/1/0= 0/5/77 Temp=Sl LRS unit 76 CMIT-TxIA (RWO CAPITAL) CMIT TxIA **PASSED** to 3713/3741 psi Max Applied Pressure=3850 Target Pressure= 3600. Pressured T/IA to 3757/3783 psi with 8.6 bbls diesel. CMIT-TxIA lost 26/24 psi in 1st 15 minutes and 18/18 psi in 2nd 15 minutes for a total of 44/42 psi during a 30 minute test. Bled T/IA to 0/14 psi 5/19/2019 recovering — 7.68 bbls. WSL/ Pad op notified of well status. WV/SV/SSV=C MV=O T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS), pre rig. PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi PPPOT-IC: Stung into test port (100 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely re -torqued to 600 Ib/ft. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in 7/22/2019 isecond 15 min (PASS). Bled void to 0 psi Printed 11/26/2019 10:44:32AM North America - ALASKA- SP Page 1 of 5 Operation Summary Report Common Well Name: 5-22 AFE No Event Type: WORKOVER(WO) Start Date: 10/31/2019 End Date: H-S4DW001951-EX-D1-WO-(1,304,448.00) Project: PBU-Site: S Rig Name/No.: CDR -2 Spud Date/Time: 12/21/1990 12:00:OOAM Rig Release: rug Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000195 Active datum: KB @65.50ustt (above Mean Sea Level) _ Date _ From - To I ttHhhrrrs�' Task Code NPT Total Depth usit) Phase Description of Operations 10/31/2019 :113:00 - 1430 1.50 RIGU PT PRE MOVE RIG OFF Z-25 -JACK UP, MOVE PIT MODULE TO CENTER i OF PAD AND. I NSTALL JEEPS -INSTALL STOP SILL, JACK UP RIG MODULE, MOVE OFF WELL TO CENTER OF PAD AND — — INSTALLJEEPS 114:30 - 18:30 4.00 RIGU P_ PRE MOVE RIG FROM Z-25 TO S PAD 18:30 - 00:00 5.50 RIGU P PRE MOVE RIG OVER S -22B JEEPS FROM SUB AND PIT (REMOVE MODULE -MOVE DRILLING SUB ONTO MATS AND —FI- JOCKEY INTO POSITION 11/1/2019 1,00:00 - 03:30 3.50 RIGU P T PRE MOVE RIG OVER S-228 MOVE DRILLING SUB ONTO MATS AND JOCKEY IN TO POSITION SPOT DRILLING SUB OVER WELL WITH WALKING FOOT. 'I. '';- SPOT PIT MODULE NEXTTO DRILLING SUB AND SET DOWN ---.----._ "`ACCEPT_ RIG AT 0330 HRS" 03:30 - 05:33302.00 RIGU P—R—I E RIG UP .05 :30 - T0730 07:30 —' 2.00 BOPSUR P H WORK ON RIG UP CHECKLISTS. r PRE. NIPPLE UP BOPS - 11:00 1 3.50 eOPSUR P PRE PREPARE TO TEST BOPE - BRING XO AND HANDLING EQUIPMENT TO RIG FLOOR. j 4 - GREASE STACKAND CHOKE. '.-INSTALL RISER. :- INSTALLAIR BOOT ON RISER AND ENERGIZE. - GET RKB MEASUREMENT ! FLUID FLUID PACK LINES _ 11:00 - 12:00 1.00 BOPSUR _ P pRE SH ELL TEST BOPS AND SUR FACE LINES TO 21 00 - 712.00 16.30 4.50_BOPSUR _ 13500 PSI P PRE INITIAL ROPE TEST PER BPANDAOGCC STANDARD. TEST WITNESS WAIVED BY AOGCC GUY COOK !I - PJSM AND REVIEW PRESSURE CROSSCHECK LIST -13-5/8" ANNULAR, BLIND, MUD X, 4-1/2"x7" VARIABLE. -ANNULAR PREVENTERAND VBRS TESTED WITH 4-1/2" TEST JOINT - ANNULAR TESTED TO 250 PSI LOW/3500 PSI HIGH FOR 5 MIN EACH RAMS/ VALVES TESTED 250 PSI LOW/ 3500 PSI HIGH FOR 5 MIN EACH - PERFORM ACCUMULATOR DRAWDOWN 13000 PSI START, 30 SEC TO 200 PSI / 100 SEC TO FULL RECHARGE ALL TEST PASSED Printed 11/26/2019 10:44:32AM North America - ALASKA - BP Page 2 of 5 Operation Summary Report Common Well Name: 5-22 AFE No Event Type: WORKOVER (WO) Start Date: 10/31/2019 End Date: H-S4DW001951-EX-D1-WO- (1,304.448.00) Project: PBU---- Sitl e: g - - —-- Rig Name/No.: CDR -2 Spud Date/Time: 12/21/1990 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ;BPUOI: USA00000195 Active datum: KB @65.50usft (above Mean Sea Level) Date I From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr)(usft) 16:30 - 20:00 3.50 SOPSUR P I PRE -UD TEST JOINT -CLEAR FLOOR, PREP TO CIRC OUT DIESEL. -EVACUATE STACK. SII -VERIFY 0 PSI / FLOW AT IA. -SPOTAND HOOK UP DOYON EQUIPMENT. -MAKE UP LANDING JOINT XO. HOLD PRE SPUD MEETING AND H2S / RIG j'EVACUATION DRILL WITH RYAN BEARDS CREW. jPULL HP DART FROM BPV WITH DRY ROD, I PULLHPBPV WITH DRY ROD 000 - 2300 3.00 - PULL P _ DECOMP (CIRCULATE WELL TO 8.4 PPG HEATED 120 (DEGREE 1% KCL HOLD PJSM WITH CREW -LINE UP DOWN TUBING TAKING RETURNS THROUGH THE OUTSIDE CHOKE SKID TO THE TIGER TANK WITH THE BLINDS CLOSED -CHECK LINE UPS WITH WSLAND RIG MANAGER - -PUMP 20 BBL H2S SCAVENGER PILL AT BPM AT 300 PSI, PUMP 555 BBL HEATED 8.4 PPG IN KCL BRINE 5BPM AT 950 PSI � -FLOW CHECK WELL BOTH TUBING AND IA I ARESTATIC. 2300 - 0000 1 1.00 PULL P DEC IMP �PULLHANGER -MAKE UP LANDING JOINT -PULL ROTARY BUSHINGS -MAKE UP LANDING JOINT TO HANGER -MAKE UP TOP DRIVE TO LANDING JOINT. -PULL HANGER OFF SEAT AT 205K, P/U _ WEIGHT 170K 11/2/2019 1100:00 - 01:30 1.50 PULL P 9,130.00 DECOMP PULLHANGER -HOLD PRE SPUD MEETING AND H2S/ RIG I EVACUATION DRILL WITH MICAH BUSH'S CREW. -ISOLATE AND STRIP DUAL CONTROL LINES III AND FITTINGS OFF HANGER. -CUT I BAND AND SECURE DUAL CONTROL LINES TO TUBING. -HOLD PJSM WITH CREW FOR PULLING TUBING WITH DUAL CONTROL LINES. FINISH RIGGING UP RIG FLOOR WITH j SPOOLING UNIT AND HYDRAULIC POWER - iTONG& -LAYDOWN LANDING JOINTAND CROSSOVER -BREAKOUT TUBING HANGER AND LAY DOWN. x- { _ 101:30 - 0430 3.00 PULL P 9,130.00 DECOMP LAY DOWN 4.5 COMPLETION -CHANGE OUT ELEVATORS TO 4.5" MYC 125 TON ELEVATORS -POOH AND LAY DOWN 44/2", L-80, 12.6PPF, RANGE III NSCTTUBING WITH DUAL CONTROLLINETO F/9130MDT/6931"MD NOTE: 58 STAINLESS CONTROL LINE BANDS RECOVERED Printed 11/26/2019 10:44:32AM NorthAmerica-ALASKA -BP Page 3of5' Operation Summary Report Common Well Name: 5-22 AFE No Event Type: WORKOVER(WO) I Start Dale: 10/31/2019 End Date: H-S4DW001951-EX-01-WO-(1,304,448.00) Project: PBU Site: S Rig Name/No.: CDR-2 Spud Date/Time: 12/21/1990 12:00 OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000195 Active datum: KB @65.50usft (above. Mean Sea Level Date From - To Him Task Code NPT j Total Depth Phase Description of Operations .. __....... y__ (hr) (usft 04:30 - 11:00 6.50 PULL P 9,130.00 DECOMP LAY DOWN 4.5 COMPLETION j -POOH AND LAY DOWN 4-1/2", L-80, 12.6PPF, RANGE III NSCT TUBING HOLD A KAT DRILL, DRILLER SIMULATED THE WELL WAS FLOWING, WELL SECURED IN 1:27 FOLLOWING THE STANDING ORDERS RWO, HOLD AAR' 'IFOR -CONTINUE PULLING PIPE - TUBING PULLED, 223 JT +5' CUT JT '- BO CUT JOINTAND INSPECT CUT - CUT&DRIFTARE CLEAN INSTALL WEAR RING _ 9,130.00 OTHCMP CLEAR RIG FLOOR 11:00 - 13:00 2.00 EVAL P - REMOVE ALL DECOMPLETE EQUIPMENT FROM THE RIG - HES ON LOCATION, GIVE CREW RIG ORIENTATION VIDEO. WHILE BRINGING IN PIPE 8,130.00 OTHCMP !ELINE OPS ',, 13:00 - 00:00 11.00 EVAL p - SPOT ELINE UNIT, RU SHEAVES AND VERIFYALIGNMENT HOLD A P SM WITH HES AND NABORS ,CREWS, DISCUSS WELL CONTROL, POLICIES & PROCEDURES AND RED ZONES - RU ELINE & RIH WITH DRIFT RING & JUNK BASKET ON ELINE, TAG AT 9120' ELMD '(SUSPECT 41/2"TUBING STUB.) - MAKE UP CBL BHA ON ELINE AND RIH - PERFORM CEMENT LOG FROM 9142' ELMD TO SURFACE 11/3/2019 0000 - 01:15 125 - 12 --, P EVAL 9,130.00 L-OTHCMP ELINE OPS - PERFORM CEMENT LOG FROM 9100 TO ! SURFACE -RIG DOWN ELINE 01 15 02:00 0.75 EVAL I N NOTE:SEND RESULTS TO ODE AND PETRO _ PHYSICIST FOR INTERPRETATION. 00319 ! OTHCMP ELINE OPS RIG ELINE BACK UP FOR 95/8"CALIPER LOG_ 02:00 - 03:00 1.00 EVAL N 9,130.00 OTHCMP MOBILISE 9 5/8" CALIPER LOGGING TOOLS FROM DEADHORSE NOTE: ADD EXTRA HOUR FOR DAY LIGHT SAVINGS TIME. j _ ! NOTE: LOAD TUBING INTO PIPE SHED WHILE MOBILIZING TOOLS 00 - 07:30 4.50 EVAL P - 9,130.00 j OTHCMP ELINE OPS ! -MAKE UP 9 5/8" CASING CALIPER TOOLS j-TROUBLE SHOOT TOOLS AT SURFACE ! -RIH WITH 9 5/8" CASING CALIPER TOOLS AT 0400 HOURS TO 5260' ELMD -POOH PERFORMING 9 5/8" CALIPER LOG FROM 5260' ELMD AT 0445 HOURS OOH WITH LOGGING TOOLS RD HES Printed 11/26/2019 10:44:32AM North America - ALASKA - BP Page 4 of 5 Operation Summary Report Common Well Name: S-22 AFE No Event Type: WORKOVER(WO) Start Date: 10/31/2019 End Date: H-S4DW001951-EX-DI-WO-(1,304,448.00) Project: PBU Site: S Rig Name/No.. CDR-2 Spud Daterrime: 12/21/1990 12:ao:ooAM Rig Release: Rig Contractor. NABORSALASKA DRILLING INC. I BPUOI: USA00000195 Active datum: KB @65.50us@ (above Mean Sea. Level) Date From -To His Task Code NPT Total Depth Phase Description of Operations ....... _ (hr) (hr) (usft) X0730 - 00:00 18.50 RUNCOM P 9,130.00 RUNCMP 14-1/2 COMPLETION OPS -PULL WEAR RING -BRING IN SUBS BELOWTHE PACKER AND j CLEAN THREADS FOR BAKER-LOK - LOAD GEM'S LOAD REMAINING 2 ROWS OF TUBING, (STRAP AND TALLY VERIFY TALLY WITH HES REP - VERIFIED SHEAR PINS AT 4'& 12' AND RHC PLUG IS INSTALLED - WALK THROUGH COMPLETION JEWELRY AND JOINT COUNT WITH HES, NAD TP & DRILLER AND WSL I- HOLD A Pi DISCUSS FOLLOWING P & P, WELL CONTROL, R & R. H2S PAD AND MUSTER AREA, TORQUE TURN MU TORQUE OF 4440 FT/LBS BAKER-LOK PUP JOINTS BETWEEN OVERSHOT & ASSY #1 X-NIPPLE AND CONNECTION BELOWTHE PACKER - MU COMPLETION AS PER APPROVED SUMMARY, MAX RIH SPEED FOR PACKERS IS 90 FPM -TAG AT TOP OF 7" LINER AT, 9258' MD, j MAKE UP TOP DRIVE AND ROTATE STRING 45 DEGREES AND PASS THROUGH CLEAN. - RUN COMPLETION TO JOINT 0150. HOLD KICK WHILE TRIPPING DRILL, DRILLER - SIMULATED THE WELL WAS FLOWING, WELL . SECURED IN 1 MINUTE 25 SECONDS. FOLLOWING THE STANDING ORDERS FOR RWO, HOLD AAR"` - LOAD REST OF 4.5" VAM TOP TUBING INTO PIPE SHED, STRAP AND TALLY SAME. -RUN COMPLETION TO JOINT #194 x 9,130.00 RUNCMP 1.50 RUNCOM Pp 12.6# - 11/4/2019 00:00 - 01:30 L80 VAMTOP COMPLETION ASSEMBLY -DRIFTTUBING WITH 3.833" DRIFT WHILE PICKING UP FROM PIPE SKATE -TORQUE—TURN ALL CONNECTIONS TO 4400 FT/ LBS --PUW =163K, SOW = 137KAT 8850' MD -OBSERVE 5K BOBBLE AT 9134' MD (FIRST '.. SET OF SHEAR PINS) -OBSERVE 5K BOBBLE AT 9142'MD(SECOND SET OF SHEAR PINS) 01:30 - 02:30 -OBSERVE SET DOWN I0KAT 9145.22'MD (NOG0 ON OVERSHOT) 1.00 RUNCOM P 9,138.99 RUNCMP SPACE OUT -LAY DOWN JOINTS 212,211 AND 210 j I-PICK UP 12.8#, L-80 VAMTOP SPACE OUTPUP JOINTS (13,35,5.85'. D RIH (-PICK UP JOINT NUMBER 210 AND RIH -PICK UP TUBING HANGER W/PUPAND LANDING JOINT EVACUATE STACK DOWN TO IA Printed 11/26/2019 10:44:32AM North America - ALASKA - BP Page 5 of 5 Operation Summary Report Common Well Name'. 5-22 'AFE No Event Type'. WORKOVER(WO) 1Start Date: 10/31/2019 End Date. H-S4DWO01951-EX-Di-WO-(1,304,448.00) Project: PBU Site: S Rig Name/No.. CDR -2 j Spud Date/Time: 12/21/1980 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI' USA00000195 Active datum: KB @65.50usft (above Mean Sea Level) Date From - To Hrs Task ! Code NPT Total Depth I Phase Description of Operations (hr) (usft) i 02:30 - 04:00 1.50 RUNCOM P _ 9,138.98 RUNCMP LAND COMPLETIONS -I -LAND TUBING STRING IN 8.4 PPG 1% KCL -FINAL PUW =170K, SOW = 135K WITH 8.4PPG SEAWATER Ali-RILDSAFTER lill WELLHEAD REP CONFIRM MARK ON PUP BELOW HANGER THROUGH IA VALVES -FINAL DEPTH OF END OF GUIDE SHOE ON OVERSHOT AT 9,138.99', 8.37' OF SWALLOW j OVER TUBING STUB AT 9130' I -LAY DOWN LANDING JOINT _ 04,nn 19.nn 8.00—WHSUR P 8138.99 P -- OST FREEZE PROTECT I -RIG UP LITTLE RED SERVICES HOLD PJSMWITH CREWS -PRESSURE TEST LRS TO 3500 PSI -PUMP 1 BBL OF NEAT MEOH FOLLOWED BY -210 BBLS OF DIESEL: DOWN IA TAKING RETURNS THROUGH TUBING HANGER AGAINST CLOSED BLINDS TO RIG CHOKE BACK TO PITS PUMPING AT 3 BPM AT <800 PSI. - DIESEL PUMPED, RU TO UTUBE DIESEL (IAAND TUBING PRESSURES AT O PSI, CLOSE IN IA, RD LANDING JOINTAND PUMP IN SUB -DRY ROD TWC - PT TWC TO 3500 PSI AS PER THE WELL PLAN AND CHART_ 12:00 - 17:00 5.00 RIGD P 9,138.99 POST RDMO OPS -GOOD PT - BLOW DOWN TEST PUMP AND ALL 'SURFACE LINES �- START RDMO CHECKLIST AND SIMOPS START NIPPLE DOWN PROCESS TO SWAP BACK TO CTD STACK '.- REMOVE FLUIDS FROM �- REMOVE CHOKE AND KILL LINES - BLOW DOWN STEAM LINES 17:00 - 18:00 1.00 RIGD P 9,138.99 POST PREP TO MOVE OFF WELL 18:00 - 19:30 1.50 RIGD P T 9,138.99 POST MOVE OFF S -22B -HOLD PJSM WITH NABORS AND PEAK -USE STOMPER FOOT TO MOVE PIT MODULE OUT TO HOOK UP SOW ! -HOOK UP SOWAND MOVE PIT MODULE DOWN THE PAD -INSTALL STOMPER ON DRILLING SUB AND MOVE OFF 5-228 AND POSITION ON MATS TO I! _�_ — RIG DOWN CELLAR 19:30-00-:00 4.50 RIGD P 9,138.99 9,138.99 { POST RIG DOWN FROM WORKOVER OPERATION _ __-START 10000 SII + -NIPPLE DOWN 13 5/8" BOPS TO INSTALL MPD LINE 11/5/2019 07:00 7.00 RIGD P 9,138.99 POST -REMOVE FLOW BOX j �-FINISH INSTALLING MPD LINE �-REMOVE BOLTS, FLANGES AND EQUIPMENT j ASSOCIATED WITH WORKOVER CAMPAIGN ! -INSTALL 71/16" BOPS AND CONNECT LINES BOP SW AP COMPLETED -"'RELEASERIGAT07:00... Printed 11/26/2019 10:44:32AM INITIAL T/IA/OA= 10/10/0. PRE CDR2. RU LUB & PT TO 350/3500 (PASS). PUMPED UP TBG TO 200psi. RD & SET 4" CIW HP-BPV #HP4-2 THRU PRODUCTION TREE @ 125". RD LUB. REMOVE SCAFFOLDING. REMOVE UPPER TREE. INSTALL TEMP VLV #36. TORQ TO API SPEC. PT TO 350/5000 (PASS). PT TO 350/3500 TOP MV GATE (PASS). PT TO 350/3500 (PASS) TOP OF SV GATE. RDMO *******JOB COMPLETE******** SEE 10/9/2019 LOG FOR DETAILS. BPV SIGN HUNG ON MV. FINAL T/1/0= BPV/0/0 removed. Dry hole tree. IA FL @ surface, OA FL @ near surface. Bled OAP to BT from 80 psi to 0 psi in 25 min (all gas). Bled IAP to BT from 50 psi to 0 psi in 2 min (all fluid, approx 5 gallons). Monitored for 30 min. IAP unchanged, OAP increased 10 psi. Final WHPs BPV/0/10. SV = C. MV = O. IA, OA = OTG. 09:45 10/30/2019 T/I/O=BPV/0/0. Pre CDR2 Test backside of BPV to 300/ 3500 psi. LTT on BPV Passed. 10/30/2019 Bled IA to 0 psi. ***Job Complete*** See log. Final WHP's BPV/0/0. T/I/O=BPV/0/0. Removed FMC THA and 4" Dryhole tree pre CDR2. Job Complete. See log. 10/31/2019 Final WHP's BPV/0/0. ***CDU62 ON LOCATION AT ARRIVAL*** RIG UP E -LINE RUN 5.7" JUNK BASKET TO TBG STUB AT 9130 FT BEGIN LOGGING HES RBT CEMENT BOND LOG FROM 9142 FT. 11/2/2019 ***JOB CONTINUES ON 03-NOV-19*** ***JOB CONTINUES FROM 02-NOV-19 WSR*** FINISH RADIAL CEMENT BOND LOG FROM 9142' TO SURFACE 11/3/2019 ***DAYLIGHT SAVINGS ENDS*** ***JOB CONTINUES FROM 03-NOV-19 WSR*** LOG READ CALIPER FROM 5260' TO SURFACE 11/3/2019 ***JOB COMPLETE**** T/I/O=TWC/0/0. Post CDR2. RU THA with FMC tec. Torqued to API spes. RU 4" GE new tree. Torqued to API spec. PT to low 300psi and high 5000psi. Passed. Pull 4" H TWC #430 @135". PT tree cap to 500psi. Passed. Job Complete. See log. Final WHP's 0/0/0. 11/5/2019 I/A,O/A=OTG SSV,WV,SV=C,MV=O. T/1/0=0/0/0 temp = SI (LRS Unit 46 - Circ well /Drop B&R/MIT-T, MIT -IA) Pumped 4 bbls 11/11/2019 60/40 down FL for freeze protect. *** WSR continued on 11/12/19 *** Daily Report of Well Operations PBU S -22B *** WSR continued from 11/11/19 *** (LRS Unit 46 -Circ Well/ Drop Ball & Rod/ Set Packer / MIT -T / MIT -IA) Pumped the following down the IA, taking returns up the Tubing, to J -19's Flowline: 5 BBLS 60/40 Meth Spear 217 BBLS Corrosion Inhibited 1% KCL 355 BBLS 130*F Diesel U-tube Tx IA for 1 hour. Freeze Protect Outlet Well S-1 9's Flowline with 25 bbls 60/40 meth. ****Drop Ball & Rod**** MIT -T **PASSED ** to 3624 psi. Max applied = 3850 psi. Target = 3600 psi. Pumped 2.39 bbls dsl down tbg to set packers and reach test pressure. Test # 1 15 min T lost 141 psi 30 min T lost 49 psi. Bled TP back to 1500 psi. Bled back 1.1 bbls. MIT -IA** PASSED** to 3701 psi Max Applied 3850 psi Target=3600 psi. Pressured IA to 3818 psi with 7.1 bbls of diesel. MIT -IA lost 81 psi in the 1 st 15 min and 36 psi in the 2nd 15 min for a total of 117 psi during a 30 minute test. Bled VIA to 0/0 psi recovering —7.9 bbls SV/SSV/= Closed MV=Open CV's= OTG HLV's=Closed tags Hung on well. Pad -op notified of well status upon LRS departure. 11/12/2019 FWHP's=0/0/20 ***WELL S/1 UPON ARRIVAL*** (Post RWO) STANDBY FOR LRS TO COMPLETE WORK & RDMO. R/U SLICKLINE SWCP #4522 FOR POST RWO. 11/12/2019 ***JOB CONTINUED ON 13-NOV-2019*** ****CONT. JOB FROM 11/12/19**** (Post RWO) PULLED B&R FROM RHC @ 9,086' SLM / 9,101' MD PULLED STA #2 BK-DGLV FROM 5,502' SLM / 5,513' MD PULLED STA#3 BKP-SHEAR FROM 3,507' SLM / 3,523' MD SET STA #3 BK-LGLV & STA #2 BK-DGLV PULLED 4-1/2" RHC -M FROM 9,086' SLM / 9,101' MD DRIFTED W/ 20'x 2-7/8" DUMMY PERF GUNS, 2.75" LIB, S/D @ 9,181' SLM (No issues) 11/13/2019 ****WELL LEFT S/1 & PAD -OP NOTIFIEDOF STATUS UPON DEPARTURE**** TREE = 41/16' GE WELLHEAD= FMC-GEN2 ACTUATOR= MACH OKB. ELEV = 65.5' REF ELEV = 65.5' BF. ELEV = 35.92' KOP = 3350' Max Angle, = 99" Q 1187 Dahim MD = 952 Datum TVD= 8800'S ( 7' BKR ZXP PKR W/ 9-5/8' X 7' BKR HMC 7 13-318• C6G, 8, 68#, LA0, S ID =12.415• SACK, D = 7.50' 5204' IR HGP, D = 6.25' 62118- !, L-80, D = 8.681' 6462• 9-5/8" MILLOUT V4A)OW 5402'-5418' (OFF V*UWR)CK) TBG, 12.6#, LA0 VAM TOP, .0152 bp( ID = 3.958' - 412'RCT TBG CUi(08/13A8) - Minimum ID = 3.725" @ 9263- 4-1/2" HES XN NIPPLE BG, 12.6#. L-80 NSCT..0152 bnf. D = 3 959" 7"X5"BKRZXPPKRW/TIEBACK,ID=52509273' 4-12' TBG, 12.6#, L-80, .01522 bpf, D = 3.958"9276' 7' LNR, 26#, L-80, .0383 bpf, D = 6.276' 9462' PERFORATION SUMMARY REF LOG: CDR/ARC5/MPULSE ON 062607/08/97 ANGLE AT TOP PERF: 27' @ 7120' Note: Refer lo Production DB for tistorical perfdato S� SPF INTERVAL rVS z DATE 2-7/8' 6 7120-7149 O 11/17/19 2-718' 6 7149-7180 O 11/16/19 3A/8" 6 9456-9476 O 921/09 2-7/8' 6 9584-9594 O 102/09 2-718' 6 9594-9604 O 10/1/09 2-7B' 6 9614-9634 O 10/1/09 2-78' 1 9630-9650 O 1224197 2-718' 6 9642-9662 O 10/1109 2-718' 6 9700-9710 O 1011/09 2-718' 6 9710-9740 O 900/09 2-7/8• 1 9720-9740 O 120087 2-78• 1 11070-11090 O 12/30/97 2-718' 1 11120-11140 O 1200/97 2-718' 1 11170-11190 O 12/3087 SLT 11927-12219 SLTD [SAFETY HENN Mi. W H25 READINGS AVERAGE 125 ppmHEN ON T W R Q DI A VWH 26 N RL ppmELL > 70' @ 9778'.. 11 2208' 412' HES X NIP, ID = 3.813• nnc i FTuer DE e D = 3.958' 0 LNP, D = X 442• HES TNT PKR, ID = 12' HES X NP, ID = 3.813' 12' HES X W. 1D = 3.813- X 4-12' HES TNT PKR, ID 12' HES X NP, ID = 3.813 X 412' UNIQUE OVERSHO' X 4-1/2' BKR S-3 PK?, D = 12' HES X NP, D = 3.813- 1/2' HES .813'1/2'HES X NIP. D=3.813' 1 9274' ��TX4-i/2'UNDUE OVf32SHC 9218'T X 4-112' BKR S-3 PKR,D = 9241 4-1/2'HF�XNP,D=3.813' 9293' 4-1/2' HES XN NP, D = 3.725' 9276' 4-12' WLEG, D=4.00' 9283' ELMDTn DATE REVBY COMMENTS DATE REVBY COMMENTS 018981 MD TVD DEV TYPE VI -V LATCH P T TE MSS/JMD GLV C/O (11/13119) 082781 RWO 1126/19 BTNIJMD ADPERFS (11/16-17/19) 118519 N-CDR2 RWO 22553ZI3 11/14/19 III DKBGfSO BK 16 19 26 111/13/191 6508 BK 00 110,30119 D = 3.958' 0 LNP, D = X 442• HES TNT PKR, ID = 12' HES X NP, ID = 3.813' 12' HES X W. 1D = 3.813- X 4-12' HES TNT PKR, ID 12' HES X NP, ID = 3.813 X 412' UNIQUE OVERSHO' X 4-1/2' BKR S-3 PK?, D = 12' HES X NP, D = 3.813- 1/2' HES .813'1/2'HES X NIP. D=3.813' 1 9274' ��TX4-i/2'UNDUE OVf32SHC 9218'T X 4-112' BKR S-3 PKR,D = 9241 4-1/2'HF�XNP,D=3.813' 9293' 4-1/2' HES XN NP, D = 3.725' 9276' 4-12' WLEG, D=4.00' 9283' ELMDTn DATE REVBY COMMENTS DATE REVBY COMMENTS 018981 N48E ORIG9IAL COMPLETION 11/14/19 JLS/JMD TREE CIO (11/05/19) 0510983 SIDETRACK (S -22A) 1126119 RC(JMD FINAL ODE APPROVAL 07/1287 SIDETRACK (S -22B)1126/19 MSS/JMD GLV C/O (11/13119) 082781 RWO 1126/19 BTNIJMD ADPERFS (11/16-17/19) 118519 N-CDR2 RWO 11/14/19 JLS/JMD TREE C/O 11/05119) Jy BKR CTC ECP PI(R -1221WFISH:(C PPUSHED DH (01/17115) PBTD 12219' PRUDHOE BAY UNIT WELL: S -22B PERMITNo: '1970510 API No: 50-029-22119-02 VL & 793' EWL, See -35, T12N, BP Exploration (Alaska) S _� THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Josh Allely Well Intervention Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -22B Permit to Drill Number: 197-051 Sundry Number: 319-502 Dear Mr. Allely: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jeremy rice Chair DATED this\aday of November, 2019. RBDMSff'uN0V 1 41019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 htuhlvEu NOV 0 5 ?rig 1. Type of Request: Abandon ❑ Plug Perforations p Fracture Stimulate ❑ Repair Well ❑ yOperations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool El - Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 197-051 - 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service [a 6. API Number: 50-029-22119-02-00 - 7. If perforating: CO 341E What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes No PBU 8-22B 9. Property Designation (Lease Number): ty 10. Field/Pools: ADL 026257'& 028258 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft)t Effective Depth MD: Effective Depth TVD: 1 MPSP (psi): Plugs (MD): Junk (MD): 12221 8819 9197 8561 9197.11700 12219 Casing Length Size MD TVD Buret Collapse Structural Conductor 79 20" 35-114 35-114 1490 470 Surface 2650 13-3/8" 34-2685 34-2685 5020 2260 Intermediate 1 5372 9-5/8" 30-5402 30-5167 6870 4760 Liner 4248 7' 5204-9452 5006-8795 7240 5410 Liner 2948 4-1/2' 9273-1221 8630-8819 1 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9456-1 8799 - 8819 4-1/2' 12.6# L-80 28-9275 Packers and SSSV Type: 4-1/2' HES TNT Perm Packer Packers and SSSV MD (ft) and TVD (ft): 6998 / 6570 4-1/2" HES TNT Perm Packer 9066 / 8440 4-1/2" Baker S-3 Perm Packer 9187/8552 4-1/2" Baker Hydro Set Packer 9218/8580 12. Attachments: Proposal Summary 21 Wellbore Schematic Rl 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 21 14. Estimated Date for Commencing Operations: November,�1199 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Allely, Josh be deviated from without prior written approval. Contact Email: Josh.Allely@bp.com Authorized Name: Allely, Josh Contact Phone: +1 907 564 5732 Authorized Title: Well Intervention Engineer Authorized Signature: ��/� �— Date: 11 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31q-5b2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test W/Location Clearance ❑ Other: RBDMS NOV 14 2019// Post Initial Injection MIT Req'd? Yes I/No❑ Spacing Exception Required? Yes ❑ No 114 Subsequent Form Required: ®_ c,/ a APPROVED BYTHE y \ 1 `ZI Approved by: i; COMMISSIONER COMMISSION Dale: { 1 I Form 10403 Revised 04/2017 INZ, 1 ORIGINAL ,l,yl� Approved application is valid for 12 months from the date of approval. (t� S bmit Farm and antl Attachments in Duplicate Wellwork Procedure Request To: Well Intervention Superintendents Date: 11/04/19 F Circ Fluid. Drop B&R and Set Packers. MIT -T. MIT -IA 3. VER1 From: Alex Youngmun - ResDev AFE: H-S4DW001951-EX-D1-WO-01 5. Josh Allely — Intervention Engineer Sundry: 319-176 S Set DGLVs. 7. F Subject: S -22B Post-RWO Procedure Please Derform the following stens 1. V Post RWO Tree Work. Pull TWC. 2. F Circ Fluid. Drop B&R and Set Packers. MIT -T. MIT -IA 3. S Pull B&R. Install LGLVs. Pull RHC. Drift for Perf Guns. 4. E Perforate. SBHPS. 5. T Flowback for 10 days. 6. S Set DGLVs. 7. F A/SL: Load IA. MIT -IA. 8. F Pre Injection AOGCC Witnessed MIT -IA 9. F Post Injection AOGCC Witnessed MIT -IA Current Status Minimum Tubing ID: 3.725" at 9263' MD. XN Nipple. Max Deviation: 99deg at 11877' MD Max Tubing DLS: 31.2deg/100' at 9796' MD PBTD: 12,219' MD Last TD Tag: 09/21/14: SL tag soft bottom (schmoo) at 9640' SLMD. Last Downhole Op: 11/05/19: CDR2 RWO SBHP: Estimated 3600 psi and 190 degF at 8800' TVD -SS. Latest H2S: NA: Injector AKIMS Status: Post RWO (Operability awaiting MITs) Program Contacts Page 11 of 4 Contact Phone - Work Phone - Mobile / Home Interventions Engineer Josh Allely 907-564-5732 907-350-7362 Pad Engineer Alex Youngmun 907-564-4864 907-250-1228 Page 11 of 4 Notes > Post RWO Injection Well Fullbore Circ Fluid. Drop B&R and Set Packers. MIT -T. MIT -IA Note: This can be performed with SL and using the SL lubricator to drop the B&R. 1. See attached detailed procedure for pump plan. Slickline Pull B&R. Install LGLVs. Pull RHC. Drift for Perf Guns. 2. Pull B&R. 3. Install generic KO GLV design. 4. Pull RHC. 5. Drift to top of TTP with 20' of 2-7/8" dummy guns. E -Line Perforate 6. Perforate per attached SOR pert sheet. 1. TBG pressure should be bled to zero psi prior to firing to obtain required underbalance. 2. Please record pre perf and post pert TBG pressures. 7. SBHPS per SOR request form. Test Separator Flowback 8. Flowback for 10 days per SOR request form. Slickline Set DGLVs. 9. Pull LGVs from top two stations. 10. Set DGLVs in top 2 stations. 11. Prior to setting last valve, load IA with 1.2x the volume to the bottom open pocket with diesel. 12. Set last DGLV 13. Perform a MIT -IA to 2500 psi target pressure. Max applied of 2750 psi Fullbore Pre Injection AOGCC Witnessed MIT -IA 14. Perform a AOGCC witnessed MIT -IA to a target pressure of 2500 psi with diesel. Max applied pressure of 2750 psi. Fullbore Post Injection AOGCC Witnessed MIT -IA Page 12 of 4 15. Perform a post injection AOGCC witnessed MIT4A to a target pressure of 2500 psi (while injecting) with diesel. Max applied pressure of 2750 psi. Page 13 of 4 S -22B Post RWO Josh Allely 907-350-7362 Objective: • Perform post RWO well work to set dual packers. • Depths are based on proposed completion. • Please confer with HES completion representative to verify parameters are correct. Fullbore: 1. B&R should be preinstalled on top of tree with pump -in -sub and riser section above pump -in -sub to cover the B&R. a. Or SL can be on location to utilize their lubricator for dropping B&R. 2. Rig up fullbore to circulate heated packer fluid and freeze protect. Plan to circulate down the IA, taking returns up the TBG to either an adjacent well, or open top tanks. • The maximum rate is 4 bpm (packer limitation). • The packer will begin to set with 800 psi differential from TBG to IA. • Verify all packer setting details with HES completions rep. • Circulation will be around the overshot stabbed over the tubing stub. • It is best practice to have the packer set while the TBG is still warm from circulating in packer fluid. 3. Pump the following at 4 bpm max rate (per HES). • 5 bbl meth spear • 175 bbls of 120 deg diesel. • 225 bbls of 120 degF 1% KCL with MI corrosion inhibitor package o Volumes based on cut tubing stub depth of 9130' MD. o Minimize shut down time when finished and swapping to last diesel stage. Swapping on the fly is preferred. • 134 bbls of 80-100 deg F diesel freeze protect. Volumes will freeze protect TBG and IA down to 2500' MD. 4. Freeze protect will already be in place. Do not U-tube. 5. Drop B&R, to land in RHC -M located in x -nipple below packers. 6. Pressure up on TBG and set packer as per HES Rep. MIT -T to a target pressure 3600 psi (3850 max applied) with diesel. If MIT -T fails, estimate LLR and discuss options with town. 7. Bleed down TBG pressure to 1500 psi. 8. Rig up to pump down IA. MIT -IA to a target pressure of 3600 psi (3850psi max applied). If MIT - IA fails, estimate LLR and discuss options with Intervention Engineer. 9. Bleed down TBG and IA to zero. Page 14 of 4 IKLF= 4-1/16" (.TW SPF VYaLFEAD= FMC -GEN 2 DATE ACTiN.TOA-- BAKER 9456- 9476 OKB ELEV - 65.5' 2-718" REF ELEV .. ._ 659' O BF. ELEV = 35.92' 6 KOP= 3350' 1011/09 Max Angle 99" @ 11877 9614-9634 Datum MD 9529' CA -S -22B t 113-3/8• CSG, 68#, L-80, D = 12.415" 1 - Minimum ID = 3"725" @ 9263' 4-1/2" HES XN NIPPLE X 7' BKR ZXP PKR W/ TE6ACK. D = 7 50" X 7" BKR HMC f2.tP-F�/ L 12.6#, L-80 17' X 5" BKR ZXP PKR W/ TEBACK, D = 5250- 14-1/2' TBG, 12.6#, L-80..01522 bar. D = 3.958' LNK ZW , L-UU, . W 63 I 9273' I PERFORATION SUMMARY REF LOG: CMARC5/NF LSE ON 0606-07/08197 ANGLEATTOPPERR 23"@9456' Note: Refer to Production DB for histarkal pert data SIZE SPF I INTERVAL Opn/Sgz DATE 3-318" 6 9456- 9476 O 9/21109 2-718" 6 9584-9594 O 10/2/09 2-78' 6 9594- 9604 O 1011/09 2-718" 6 9614-9634 O 10/1109 2-7/8" 1 9630-9650 0 12/24/97 2-718" 6 9642-9662 0 10/1/09 2-7/8" 6 9700-9710 O 10/1109 2-718" 6 9710- 9740 O 9/30109 2-718" 1 9720-9740 0 12130/97 2-718' 1 11070-11090 0 12/30/97 2-78" 1 11120-11140 O 12130197 2-718" 1 11170-11190 0 12/30/97 SLT 11927- 12219 SLTD 12.69, L-80,-0152,,0152 6pf, D= 3.958" TOP OF 4-1/2• SLOTTED UK D = SAFETY NOTES: H23 READINGS AVERAGE 125 ppm WIB1 ON ML WELL REQ UIRESA SSSV WHEN ON Ml. WELL >70"@9778'. PRE-surw WELLBORE NOT SHDWN ON DIAGRAM TOW 9-518" M ILLOUT WINDOW. 2210' 4-tr2"HFS KKOBVN,D=3.813" GAS LIFT MANDRELS 9.58" MLLOUr WINDOW 5402' - 5418' (OFF V 50STOCK) I Age; TNT PK.rL "_"J 4-112"TBG CUi(08/73/18) 84' I--{ 7" X 4-1/2" BKR S-3 PKR D - 3.875" s� 4-vz" Px PLUG(o6nat6) ,� 08'� a-vz^H�xNv. D=3s13" j 9214' 1�7"X4-1/2"UNIQUE OV6tSH( 9218' T X 4-7Y1' BKR S-3 PI(R D = 8241' 4-112" HES X NP, D= 3.873" 9263' a -t/2' HES XN Np, D = 3.725• 9276' 4-1/2• WLEG, D= 4.00^ 9283' LLMD TTL DATE REV BY COMNB�fI9 DATE REV BY COIeNON NNS M91 N -18E ORIGINAL COMPLE ION 09/22/16 AMD MINOR WBS CLEAN tP 09193 SIDETRACK(S-22A) 10/11116 BO/JMD VVBSCLEAN UP 12197 SIOETRACK(&226) 08+13/18 LLGJJ SET PX PLLIG(08/'IONB) 27/07 RWO 0&14/18 MB/JAD TBGCUT&RINWii (08/13118) 06/25714 PJC CSG/ TBG/ LNR (PER TALLIES) 09/19/18 JNJJMD ADO REF&$F, SLTD LNR TO PEW SUM"V 01!20115 CJS/JMD RESET CBFISET FISH (01/17/15) -1-I BKR CTC ECP PKR ^12219' FISH: CBP PUSHED OH (01/17115) WEILL: S-226 PERMITNo: '1970510 API No: 50-029-22119-02 1629' SNL & 793' EARL, Sec.35, T12K R12E RY BP Exploration (Alaska) ALASKA WELL AC77VITYSTA7EMENT OFREOUIREMEN7S (V3.0, DBR, LHD, EAZ BPG 04/04/2019 General Information Well Name: S -22B Date Created: 10/29/2019 API Number: Well Type: 50-029-22119-02 WAG Injection Well Program Description: Well Activity Past RWO Conventional 4 Classification: AURORA H-S4DW001951-EX-DI-WO-01 Field/ Reservoir Cost Code/AFE: AWGRS Job Scope: 12 Month Avg [OR, RWO CAPITAL 500 bopd: POST RWO $295,000 WEIL Category: Estimated Cost, $K; WETS Job Type: Other regulatory Add Pert requirements? Refer to BOD Primary Secondary Relief Well Plan? Primary Contact: Alex Youngmun Contact Numbers: (907) 564-4864 (907) 250-1228 Well Intervention Engineer: Contact Numbers: Josh Allely (907) 564-5732 (907) 350-7362 Lead Engineer: Contact Numbers: Bernhard Stechauner (907)564-4594 (907)360-7485 Revisions (date, who, what changed): Current Well Status Information Date Oil Rate Water Rate or Int Rate IbwpdL Gas Rate or Gas Injection GOR Gas Lift Rate FTP or Injection (6opd) Water Cut (%) Rate (scf/stbo) Choke Setting (Mscf/day) Pressure (Mscf/day) (psi) 10/27/2019 0 0 0 Current Status: Not Operable Offline Inclination >70°at Depth (it) 9,778'MD Recent H2S (date, ppm) 11/6/2019 125Maximum Deviation ppm (Angle and De th) 99° 11,877' MD Datum Depth, ft TVDss 6,700' TVDss Dogleg Severity 31, 9,795' MD (Angle and Depth) Reservoir Pressure (date, psig) Est. Kup 1,915 psi Minimum ID and Depth 3.725" XN Nipple Reservoir Temp, °F Est. Kup: 145 degF Shut-in Wellhead Pressure n/a Known Mach. Integrity problems (specifics) SH leak repaired with weld. MIT -OA failed due to a suspected open shoe. Last downhole operation (date, operation) Most recent TO tag (date, depth, toolstring OD) Surface Kit Fit -for -Service? VES If No, Why? Comments, well history, S -22B is a Ivishak WAG injector. The Kuparuk penetration of 5-22B is in a location expected to provide much / background information etc: needed injection support to S -42A. A RWO to recomplete S -22B into the Kuparuk is planned to be conducted in November 2019. The RWO will setup S -22B for commingled Kuparuk and Ivishak WAG injection. Well Intervention Details Please contact the SOR author if: 1. There is a change in work scope to the approved SOR 2. For well worker $100K estimated total cost, as soon as it is reasonably anticipated that the actual cast will exceed the estimated cost by 20%. 3. Does the Planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice, GP 100220 (AKA 10-50), by either being documented as Legas Equipment or having the required design assurance work completed? hftps://gwo.bpglobal.com/sites/gwo2/Globa)Library/100220.pdf Suspected Well Problem: None Specific Intervention or Well Objectives: 1 Complete post rig work and perforate Kuparuk interval. 2 Flowback well prior to placing on injection to clean-up perforations. 3 Prepare well for injection. Key Risks, critical issues: Mitigation Plan: Is equipment AND proposed rig -up included in the Standard HAZOPs? 1 Unable to get to target depth for SBHP. If target depth cannot be achieved, obtain readings 100' TVDss higher as necessary. Based on estimated Kuparuk pressures, unlikely to be able to get well in an underbalanced state in a fluid packed system. 2 Low Kupamk reservoir pressure (est. 1915 psi at 6700' TVDss). Still want to load well with diesel to minimize amount of overbalance. Follow RP for balanced / underbalance perforating as a precaution. Summary Ste # Service Line Activit y Activity Description 403? 4047 1 4077 1 See detailed program Performance Expectations (may be N/A if no change anticipated due to the intervention) BOPD: MMSCFPD: BWPD: Expected Production Rates: FTP: Choke Setting: PI (bfpd/psi dp): Post job POP instructions: Portable test unit to POP and flowback well. Once flowback, proceeding wellwork and WTI is completed, the well will be handed over to Operations to POI. Attachments - include in separate excel worksheets. Required attachments: Current Wellbore Schematic. As needed: Pert Form, logging form, welitest chart, annotated mini log, annotated log section, tubing/casing tallies, Wellhead info, etc. Im= 4-vifi qW - - D- F1-GEN2SAFEIY )11= BAKER NOTE6:112S READINGS AVERAGE 129ppm SS -22 B WHEN ON MI. WELL REOUWES ASSSVWHEN ON V---- - __.SSS Y W. WELL>TO'09776'. Pf3rSCrRI(W1ILBONL NOI = 36.05 SHDWN ON DIAGRAM BELOW 9.616" MILLOUT ._7350' WINDOW. •= 99'77677 9-W PAI (All VVH)OW 5402'-5418' (OFT WHIPS!OLX) 9S29r 2200" 412' F1EA %, 10.3 8I s' _ -'- --• _- ' _ _-, _ ._..._ .o SIZE SPF -4800'12.6# L-80 TCI( Mirtim(ml iD = 3.726" @ 8263' 3 -NO' 6 — 4-112" HES XN NPPLE 2-718' 6 9-W PAI (All VVH)OW 5402'-5418' (OFT WHIPS!OLX) K 7- BKRZXPPI+R YW T�ApL U= 7.50' 5204' 9-51CX7'8KRHNCLNRtIGR.D-6.25' 6219' 6 -_ o"o. --I4 i12'fKnX wn, 10.3a+s' 9.518' CSG. 471, L-80,1) 6.661' 6402' 2-70W 60 70* —r n �-vr nca rm rnn ProposedperfsinKuparuk-e O 1011109 7000 {iix^�nx141P.w•s.ata—( 7,120'-7,180' 9690 - 9850 O 1224197 z -7w 6 j 99rw^r•_I LVE"! k;Ox NP,rp -1afY� O 10/1109 2-716' _ Baas' +2'+z9at-0o Vamtop_ 0 1011109 9130• 6 9710-9740 O 9130109 � If -.Ft RrT(]ll Wt311S �`.-i 9199' - 9720-9740 - - 9115' I^j4-1XHES%NP ID=3.8+3" �T'r4-tR•CntMN 8149: �-"" 1 11010-11090 3164' r na-irc "nna-a rnrt,u=c.87S' 2-7IC 1 11120-11140 9197' - 4.1R"HE3XNP.0"3.67J" I G,12.60, L-80 N5C7, .0152 bpi, 4= 3956" 8208' 1 1 11170-11190 1 O 1 12130/97 9214' 7" X 41R' ldJlglEOV 67.SFX+T ter- 8208' F1R'14135X 1rP.0e1813' 8218' TX442'81U+S-9 PKti, ID'=9.850' pelvOi+ATION SUNWRY REE LOG: CDPJARCS&PA.SE ON 0626-07108197 ANGLEATTOPPOW.- 23'Q9456' Note: PLO" to Pmdwfion DB for hiabdcal pert data SIZE SPF I NIERVAL Opn15<R DATE 3 -NO' 6 9456-9476 O 9121109 2-718' 6 9564 - 9594 O 102/09 2-718' 6 9594-9604 O 10!1/09 2-70W 8 9614-9634 O 1011109 2-718' 1 9690 - 9850 O 1224197 z -7w 6 9642.9662 O 10/1109 2-716' a $700-9710 0 1011109 2-71W 6 9710-9740 O 9130109 2-118- 1 9720-9740 O 12/30/97 2-718' 1 11010-11090 O 12/30197 2-7IC 1 11120-11140 O 12130197 2-718' 1 1 11170-11190 1 O 1 12130/97 L-80. r 9285• aAnTa DATE FEV BY CONANM PATE REV BY CObWENM 011OW N -16E ORIGINAL COMPLETION 0323116'.SET FOC PLUG(03121116) 05109!93 SIDETRACK (S -27A) 05/02116 JLS/JND RLL PX PLUG (0426118) 07112W SIDETR1%CK4S-22R) WERE AVAl40RWBS aEANIP OW27M1 RWO-- 10111Ft6 BOUND VAi5 QB1NUP 0512.6rt4 PJC CSG! TBG& LNR (FER TALL) 0112W16 CtSIJND RESETCIBR'SEFFM4(01/17/15) 12219' � F6H: CBP PUSHF-D OH (01117115) \` PBTO +2218' PRIJOFi7EBAY UNIT WELL S -22B PERI r No: ' 1970518 ARlb: 50-029-22119-02 SP StpTorASM (ATuka) global wells prMwiaat{pn Well: 5-228 API #: Data: 10/29/2019 Prod Engineer: CC or ARE: PENDING PERFORATING PROCEDURE 50-029-22119-02 Primary Ph: (90])564-4864 H25L= Alex Youngmun Secondary Ph: (907)25b1228 125 rn Reference Log Tie -In Log Add #REFI feet CDR/ARC5/IMPU CDR/ARC5/IMPULSE to the tie -In log to be on depth with the LOG: BE reference log DATE: 7/8/1997 ]/8/199] Company: SLB SLB Depths(from - to) Depths(from - to) Feet SPF__ Orientation Phasing Zone PERFTYPE 7,148' 7,180' 7,148' 7,180' 32' _ 6 Rand_ 50. _ KupC NEWPOOL 120_ _7, _ 7,148' ],120'__ 7,148' _ 28' ____6 Rand_ _ 60 _ Kup C NEW POOL Requested Gun Size 2.875" Chante PJ O_ga Min Wellbore ID: 3.73" _ Max Swell In Liquid: 3.16" Max Swell In Gas: 3.32' Is Drawdown Necessary/Desired/Unnecessary During Perforating __Yes_, wellbore to be loaded with diesel Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Lan Drift: 0 ft MD on 1/0/1900 Est Res. Pressure @ 6_700' NDss MD is 1915 psi Perforation Summary Summary Dirt Well: __5.228__ Prod Engr: own Date: _ API k: 50-029-22119-02 PBTD Anch Prod Engr General Comments: Depths Gun Dia Orientatlon SPF Phasing Zane Adperf/Reperf Balance Referenced to BHCS O/B/U 0 / B / U O / B / U 0 / B / U O / B / U O / B / U O/B/U O/B/U--_— Reference log: CDR/ARCS/IMPULSE log dated 7/8/97 Perf interval: 7120'- 7180' MD 0 Well:_ S -22B Date: 1.0/29/2019 Cost Est: CC or AFE: HH-S4DW061951-EX-D1-W0-01 API#: 50-029-22119-02 Primary#: (907)564.4864 H2SLevel: Prod Engr:. Alen Youngmun Secondary#:_(907)250-1228 125 m� WBL Entries step Type I Work Description Comments 1 S SBHP Tie-in to the base flange. Well Data Procedure Tag: MD Tag Date: 1/0/1900 Deviation 99° _ Depth: 11,877' MD reass iu mm pressure stop in lubricator Drop belowthe first pressure -stop requested. Pull up to specified depth. E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold gauges at depth fortime specified E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold gauges at depth for time specified E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold gauges at depth fortime specified ._.._.._..5.„22B, ..._..._, API#: 50-029-22119-02 PE ..................................... ... _.... ..................... _... _.............. _... _. ..... _......... New Tag: 'MD Prod Engr Upper Lower Time MD SS Gauge Gauge Temperature Test Gauge Pr"ob Lubricator Pressure 7,329' ....._. 6,800' ------ ......._...._.._ 1217' 13,700' ... _.... ... ..._._6,00_..._...._ ___. .. .. 6993' 6,5500' Pos[Job Lubricator Pressure of Pressure Tool (tubing) SICP (9-5/8"I: and Time: Total Shut-in Time fhrs) MD TVDss Time First 7,329' 6,800' 15 min Second 1,217' _ 6,700_ 15 min Third _ _ ],105' 6,600' 15 min Fourth 6,993' _ 6,500 15 min reass iu mm pressure stop in lubricator Drop belowthe first pressure -stop requested. Pull up to specified depth. E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold gauges at depth fortime specified E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold gauges at depth for time specified E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold gauges at depth fortime specified ._.._.._..5.„22B, ..._..._, API#: 50-029-22119-02 PE ..................................... ... _.... ..................... _... _.............. _... _. ..... _......... New Tag: 'MD Prod Engr Upper Lower Time MD SS Gauge Gauge Temperature Test Gauge Pr"ob Lubricator Pressure 7,329' ....._. 6,800' ------ ......._...._.._ 1217' 13,700' ... _.... ... ..._._6,00_..._...._ ___. .. .. 6993' 6,5500' Pos[Job Lubricator Pressure of Pressure Tool (tubing) SICP (9-5/8"I: and Time: Total Shut-in Time fhrs) Portable Test Separator Work Request Date 10/29/2019 AFE: H-S4DW001951-EX-DI-WO-01 Not Operable Name Alex Youngmun Contact Number 1 (907) 564-4864 Contact Number 2 (907) 250-1228 Well S -22B 125 Current Status: Latest H2S Value: Field/Horizon (for PVT): Welltest (or expected rates): Base Case High rate case (if applicable) #1 Well IOR HP/LP Return Well preference S-19 I0 Lp Well Clean/Raw PBGL sourcel #1 1 S-19 E Clean #2 well IOR HP/LP S-01 I110 LP Well Clean/Raw #2 S-01 I Clean Key Risk, Critical issues Not Operable Ensure proper HSE equipment is warn. A HS2 11/6/2019 measurement of 63 ppm was taken during the pre -rig 125 H2S during flowback. injector flowback on 1/30/16 in S-112. The lateral drilled was placed within the same fault block with no major compositional changes expected with the fluids produced Oil Water Fgas GL I FTP I FGOR I WC (bopd) (bwpd) (MMCFD) (MMSCFD) (psi) (scf/stb) M 600 100 0.2 1 2.5 300 333 14.29% 1200 200 0.4 2.5 300 333 14.29% #1 Well IOR HP/LP Return Well preference S-19 I0 Lp Well Clean/Raw PBGL sourcel #1 1 S-19 E Clean #2 well IOR HP/LP S-01 I110 LP Well Clean/Raw #2 S-01 I Clean Solids potential Low Pad Separator piggyback? If possible Background unique to this operation (Only if required, beyond SoR background) Prior to permanent injection, a temporary flowback will be conducted through a portable test unit. Past Kuparuk injectors have shown significant benefitfor pre -producing injectors. to younak@bp.com. ***If at any point in time the FTP is greater than 2000 psi, the WHT is less than 50F, or the fluid rate is < 200 bbls/da please open the choke to achieve a WHP< 2000 psi, WHT>50 F and Q>200 bbls/day, and then resume the procedure. *** 1. POP well to the portable test separator taking returns to the LP system via RP: Well Testing - Generic Unloading Pump 5 bbls methanol into the IA to prevent from forming hydrates while the well is unloading and warming up. Ensure at least 530 bbls of fluid have been recovered before proceeding with any drawdown optimization (two and one IA volume). - Estimated IA volume to ST#1 is 310 bbls. - Estimated tubing volume to top pert is 110 bbls. Once IA has been evacuated, target a GL rate of 2.5 mmscfd and wide open choke. Please note any solids seen in shakeout samples. . Obtain a 12 hour well test once 530 bbls of fluid are recovered and the well is stable. Consult with APE to determi ptimal GL rate. Pump methanol as necessary for hydrate mitigation. Key Risk, Critical issues Mitigation Plan Ensure proper HSE equipment is warn. A HS2 measurement of 63 ppm was taken during the pre -rig 1 H2S during flowback. injector flowback on 1/30/16 in S-112. The lateral drilled was placed within the same fault block with no major compositional changes expected with the fluids produced back. 2 Hydrate formation if low fluid rates are Be prepared to pump methanol down the IA as encountered. necessary. Solids potential Low Pad Separator piggyback? If possible Background unique to this operation (Only if required, beyond SoR background) Prior to permanent injection, a temporary flowback will be conducted through a portable test unit. Past Kuparuk injectors have shown significant benefitfor pre -producing injectors. to younak@bp.com. ***If at any point in time the FTP is greater than 2000 psi, the WHT is less than 50F, or the fluid rate is < 200 bbls/da please open the choke to achieve a WHP< 2000 psi, WHT>50 F and Q>200 bbls/day, and then resume the procedure. *** 1. POP well to the portable test separator taking returns to the LP system via RP: Well Testing - Generic Unloading Pump 5 bbls methanol into the IA to prevent from forming hydrates while the well is unloading and warming up. Ensure at least 530 bbls of fluid have been recovered before proceeding with any drawdown optimization (two and one IA volume). - Estimated IA volume to ST#1 is 310 bbls. - Estimated tubing volume to top pert is 110 bbls. Once IA has been evacuated, target a GL rate of 2.5 mmscfd and wide open choke. Please note any solids seen in shakeout samples. . Obtain a 12 hour well test once 530 bbls of fluid are recovered and the well is stable. Consult with APE to determi ptimal GL rate. Pump methanol as necessary for hydrate mitigation. If stable flow rates or flowing temperatures above 50 degF cannot be achieved, contact APE to discuss path forward. its will likely result in RDMO as well cannot be flowed without risk of hydrate formation. . Continue flowing back well until at least 1000 bbls of reservoir fluids have been recovered. Obtain 1 6 hour well test per day. RDMO after 1000 We of fluid is recovered. Ensure solids are <0.2% prior to RDMO to ensure wellbore is clean prior mmencing injection. Notes: Well will be POP'd via "RP: Generic Unloading Procedure using GL" unless otherwise specified Target solids will be <0.2%upon RDMO, unless otherwise specified Target PH will be 6.5 - 7 per RP upon RDMO unless otherwise specified Davies, Stephen F (CED) From: Allely, Josh <Josh.Allely@bp.com> Sent: Friday, November 8, 2019 1:28 PM To: Davies, Stephen F (CED) Subject: FW: PBU 5-22 (PTD 197-051; Sundry 319-502) - Questions Steve See below. Thanks Josh From: King, Sarah <Sarah.King@bp.com> Sent: Thursday, November 7, 2019, 11:23 To: Stechauner, Bernhard; Huber, Kenneth J; Becia, Sierra Cc: Youngmun, Alex Subject: RE: PBU S-22 (PTD 197-051; Sundry 319-502) - Questions Hello, Here is a map with the faults and nearby wells to S -22B displayed. Dots are placed along the S -22B wellbore at the depths of the perfs. The circles represent a 750ft (40 acre spacing) radius around the well perforations. There are no other wells within that acreage. Additionally, the closest well to S -22B (S-1121-1) is across a sealing fault. C Please let me know if you need additional information. Thank you, Sarah King From: Davies, Stephen F (CED) <steve.daviesCa alaska.aov> Sent: Thursday, November 07, 2019 8:51 AM To: Allely, Josh <Josh.Allely@bp.com> Subject: RE: PBU 5-22 (PTD 197-051; Sundry 319-502) - Questions Thank you Josh. One more question: Will recompleting PBU 5-22 within the Aurora Oil Pool conform with the spacing requirements of Conservation Order 45713? That order states: Rule 1. Well Spacing (CO457, 9/7/01) Spacing units within the pool shall be a minimum of 40 acres. 20 AAC 25.055(a)(1) and (2) shall not apply to property lines within the external boundaries of the Aurora Participating Area. Thanks again for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.daviesPalaska gov. From: Allely, Josh <JOsh.Allely@bp.com> Sent: Wednesday, November 6, 2019 3:02 PM To: Davies, Stephen F (CED) <steve.daviesPalaska.aov> Subject: RE: PBU 5-22 (PTD 197-051; Sundry 319-502) - Questions Steve Apologies, seems we overlooked sending the SOR form to you. See attached. It should answer your questions below. Thanks Josh Josh Allely Well Intervention Engineer BP Alaska 907-564-5732 (office) 907-350-7362 (mobile) From: Davies, Stephen F (CED) <steve.daviesCtaalaska.aov> Sent: Wednesday, November 06, 2019 2:35 PM To: Allely, Josh <JOsh.AllelvC@bp.com> Subject: PBU S-22 (PTD 197-051; Sundry 319-502) - Questions Josh, I'm reviewing BP'S Sundry Application to perforate PBU S-22. The "Type of Request" box at the top of the application form indicates that BP intends to perforate a new pool. But in the application, I don't see a list of planned perforation depths or any discussion in the work plan to confirm this (there is no attached SOR pert sheet). The application contains a current wellbore schematic drawing, but it does not contain a schematic drawing depicting the condition of the well after the proposed operations. Or have I overlooked something? If not, please provide a list of perforations, an indication of which pool is being perforated, and a proposed schematic drawing. Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 dkclosure 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 Steve Davies at 907-793-1224 or steve.davies(Malaska gov. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S -22B Permit to Drill Number: 197-051 Sundry Number: 319-176 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JreL.mielowski Commissioner DATED this 19 day of April, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C MISSION APPLICATION FOR SUNDRY APPKOVALS 20 AAC 25.280 APR Q 4 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operation Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Ap�dkad.PiDgPa L Plug for Redrill ❑ Pertorete New Pool Re-enter Susp Well ❑ Alter Casing ❑ Other Commingle Kuparuk & y�r Ivishak Pools 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 197-051 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-8612 Stretigrephic ❑ Service 0• 6. API Number: 50-029-22119-02-00 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU S -22B - 9. Property Designa0on (Lease Number): • 10. Fieltl/Pools: ADL 028257 & 028258 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth ND:MPSP (psi): Plugs (MD): Junk (MD): 12221 8819 9197 8561 2470 9197.11700 12219 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 35-114 35-114 1490 470 Surface 2651 13-3/8" 34-2685 34-2685 5020 2260 Intermediate 1 5372 9-5/8" 30-5402 30-5167 1 6870 4760 Liner 1 4248 7" 5204-9452 5006-8795 7240 5410 Liner 1 2948 4-1/2" 9273- 12221 1 8630-8819 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 1 9456 -' 8799 - 8819 4-1/2" 12.6# L-80 28-8568 Packers and SSSV Type: 4-12" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 9187/8552 4-12" Baker S-3 Hydro Set Packer 9218 / 8580 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q' 14. Estimated Date for Commencing Operations: April 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true antl the procedureapproved herein will not Contact Name: Ciolkosz, Ryan R be deviated from without prior written approval. Contact Email: Ryan.CtoIkosz0bp.com Authorized Name: MGaughlin, Sean M Contact Phone: +1 907 564 5977 Authorized Title: Engineenng Team Lead - CTD Authorized Signature: /M ter I � Date: /341 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31�-h1� — Plug Integrity ❑ BOP Test Ldp/ Mechanical Integrity Test ❑ Location Clearance ❑ Other e�'J6-e c.Bt..-T-r> 6DGtL �,`hs vaw.o, c��io Zol¢AC 2S 5�/Z�6� 1L Post Initial Injection MIT Req'd? Yes ❑ No ❑/ C-41 r r,�I Lo{� ai9/ G,g� ai Spacing Exception Required? Yes ❑ No Subsequent FortT Required: r ) APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ' ) ORIGINAL 1)1C 171, r /;I' Submit Form antl Form 10-003 Revised 04/2017 Approved application is valid for 12 months from the date of approvalAttachments in Duplicate Le" 121179 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Z by RWO/CTD Engineer oWe Date: April 3, 2019 Re: S-22Bi Sundry Approval Sundry approval is requested to perform a tubing swap on S-22Bi to restore integrity to the well. History and current status: S -22B was sidetracked to its current location in 07/97 and POP'd initially as a pre -produced injector in 199& S - 22B failed an MIT prior to the well conversion from a producer to injector. A RWO to replace corroded tubing was performed in 06/01 and the well was subsequently converted to injection. A� �A Ct U , 7X The proposed RWO is to allow for commingled injection into both the Kuparuk and Ivishak reservoirs. A RWO is A needed because S-22B's current production packer is below the Kuparuk interval. /S' t? Prior attempts to provide injection support to S -42A involved an unsuccessful coil tubing sidetrack of S-112 in 04/16. Unfortunately, it was not possible to complete the S-112 sidetrack as planned due to unanticipated faults. Commingled injection into S -22B is an alternative to the unsuccessful S-112 sidetrack. Proposed plan: All American Oilfield 111 pulling unit will perform a tubing swap on or around June 21th, 2019. The MASP is 2470 psi. A cement evaluation log will be run after the tubing has been pulled and prior to running new tubing to show competent cement between the Kuparuk Reservoir and Ivishak Reservoir. Thic .`'i inrinr rn are n wniuor roni reef fnr eeffinn fke Le. _.Ann' AArI bpm 1Mn n..:nH nn C OODi h Perforation"). — We are unable to set the packer lower because the (272' MD from the top of the perforations). MID The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to operable status. Pre -Rig Prep Work: 1. V: PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS. i 2. F: OA Integrity Test, CMIT TxIA _7�0 3600 3. E: RCT Cut tubing 4. V: Set BPV. Pre RWO Tree Work Proposed RWO Procedure: / '4G�c- 1. MIRU. ND tree. NU and test BOPE. 2 y ifo-.�/' 4&Ae_e_ r, 2. Pull 4'/z" L-80 tubing from RCT cut. 3. Run Cement Evaluation Log fi.6 LTo � 4. Run 4'/�', 12.6#, L-80 VamTop tubing with straddle packer and Unique Overshot. 5. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work 1 Pull TWC. Drop B&R. Set packers. MIT -IA. (circ in hot fluids - trapped volume between packers (and perforate soon)) \ 2. Pull B&R. Install live GLV's. Pull RHC. ADt�Dan o V..S (�O VLAAr 3. Underbalance perfthe Kuparuk from 7120' 7180 MD. D e r. _ ew_vW 4. Post -rig surface reconnect. 5. Flowback to clean up perfs. Preferred option is to flow back through pad separator, but if that cannot be accomplished, portable test separator will be used. 6. SBHPS. Dummy GLV's. 7. POI to PWI. Establish injection into the Kuparuk for a minimum of 2 weeks. 8 Pull TTP. Set RMX body with WFRV / orifice to allow for Ivishak injection. Ryan Ciolkosz RWO/CTD Engineer 564-5977 CC: Well File Joe Lastufka Q.-_ U_') Sullihky TREE= 4-1/16' QW WB1 AD= FMGGB12 ACRIATOR= BAKER OIB. ELEV = 65.5' BF. ED/ = 36.(15' KOP= 3350' Max Angle = 99' b$11877 Datum MD= 9529' Oalun WD= SSW SS I13 -3/n- x G, 66#, L-60. D = 12.415- Il ZSB6- Mirumum ID = 3.726" @ 9263' 4-1/2" HES XN NIPPLE X 7' BKR ZXP F#2 W/ TACK. D = 7.50• 6204' 9-518" X 7- BKR HMC LNR HGF. D = 625• H 6218' SPF S —2 SAFETY NOTES: HCS READINGS AV 9L1GE 125 ppm WHEN ON ML WELL REQUIRES A SSSV WHEN ON ML WELL> 70' 09778'. PRES13TRKWELLBORE NOT SHOWN ON DIAGRAM BELOW 9-518' MILLOUT WINDOW. O2210' 4- 12'HFS HXO BVI LL GAS LIFT MANDRELS 9.5/8" &CLOUT WMDW 5407 - 5418' (OFF WFPSTOCK) TBG CUT 9187' 1-14-1/2- FES X NP. D=3.813" 9197' 41/2" PX PLUG (08/10/18) 412' TBG. 12.6#. L -BO NSCT..0152 bot, D = 3.958' 9208'8208' 41/2" HES X NP, D = 3.813' T X 5' BKR ZXP PKR W/ IEBACK D = 5250'9273' .0383 bof. D = 6276' PERFORATION SIBMMARV REF LOG: CDRARC5/F PLLSE ON 0 6/2 6-0 7 /0 619 7 ANGLE AT TOP PERF: 23'@9456* Note: Refer to Production DB for historical pert data SEE SPF WERVAL Opn/Sgz 647E 3-3/6' 6 9,156 - 9476 O 921/09 2-71W 6 9584-9594 O 10/2/09 2-71W 6 9594-9604 O 10/1109 2-71W 6 9614-9634 O 1011109 2-71W 1 9630-9650 O 12/24/97 2-7/8' 6 9642- 9682 O 10/1109 2-7/6' 6 9700-9710 O 10/1/09 2-719• 6 9710-9740 O 9730/09 2-718" 1 9720-9740 O 12/30/97 2-7/9' 1 11070-11090 O 12/30/97 2-7/B' 1 11120-11140 O 12!30/97 2-718' 1 11170-11190 O 1213097 1/2' LNR 1 .12' BKR 5-3 PKK D - I XNP. D=3.813' ( 9275' r14-12- WLEG, D- 8283' F3_MD TTL .0152 bpf. D - 3.958• -t 'SLOTTED LNR D = 3.958' DATE FiE'V BY COLMENTS 647E REV BY COMMEI T" 01109191 1418E ORIGINALCOMPLETION 09/22(161 JMD IINORWBSCLEANUP 0510993 SIOETRACK(S-22A) 10/11116 BOJJFYD WBSCLEANLP 0711297 SIDETRACK(S-228) 08/13/18 LLG/JMD SET PX PLUG (08/10/18) 06127/01 RWO 08/14/18 WJM4D TBG Ct1F 8 p R4CH (=13/18) 06125/14 PJC CSGI TBG/ LNR(PER TALLIES) 0120115 CS/JMD RES0 CBFfSET FISH (01117115) J_�BKR CTC BCP PKR -12219' FISH: CBP PUS HED DH(01/17/15) PTID B 12219' PRUDHOE BAY UNFr WELL: S -22B PHMR No: '1970510 ARM" 50-029-22119-02 1629' SNL 8 793' EWI, Sec.35, T12K R12E SP Exploration (Alaska) TT4m= 4-1/16' CNV V191FfAD- FMGGE42 ACTUATOR= BF. ELB/ = BAKER 36.05 Opn/SgZ 3350' Atex Angle = Datum AD = 99' @ 11877 9529 Datum TVD-- 88W SS Minimum D = 3.726" @ 9263' 4-1/2" HES XN NPPLE X T BKR ZXP PKR IN/ TACK D=750'- 35/8' CSG. 47#. L-80. D = 8-681' S _2 SAFETY NOTES: 1125 READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSS V WHEN ON M1. WELL > 70' @ 9778'. PRE-SOTRK WELLBORE NOT SHOWN ON DIAGRAM BELOW 9-518" MILLOIIT WINDOW. � la -v` vk -7/80 4 trz 12s# Leo Vamtop 9130' — JEirc RCT CU 8/13116 9130' 7' x 4-1/2' 0vcrshot_ I 9140' 4-1/2' TBG, 12.6#, L-80 NSCT, .0152 bpf, D= 3.958' 8208' .0383 bpf, D = 6.276" PERFORATION SUMMARY REF LOG: CDP/ARC5/NPl1LSE ON 0626-07/08197 ANGLE AT TOP PERF: 23' @ 9456' Note: Refer to Production DB for historical peri data SIZE SPF INTERVAL Opn/SgZ DATE 3-3/8" 6 9456- 9476 O 921/09 2-7/8' 6 9584-9594 O 102/09 2-7/8' 6 9594-9604, O 10/1/09 2-7/8' 6 9614 - 9634' O 10/1/09 2-718' 1 9630-9650. O 12/24/97 2-718' 6 9642- 9662 O 1011109 2-718" 6 9700-9710 O 10/1109 2-718' 6 9710-9740, O 9130109 2-7/8' 1 9720-9740. O 12/30/97 2-718' 1 11070-11090 • 0 12/30/97 2-7/8" 1 11120-11140 - O 12/30/97 2-7/8' 1 11170-11190- O 12/30/97 (4)KBG-2 4-1/2" X 1" GLM —4800' - 4-1/2" 12.6# L-80 TCII 35/8' MLLOUT ArtoOW. 5402' - 5418' (OFF WFPSTOCK) 6940' 1-+112-HESX NIP, ID 3813- 6970' 1-X 4 112-1 its INR PKU ]DDD' 41/2'HESX NIP, ID 3.813' 9055' J-4-1/2-HESX NP, ID=3813- 9086' J-+-x41/J'III S TNI PK2 9115'-41/2-HLSX NIP. ID =3813' 7'X 4-1/2' BKR S3 PKR 10 = 3.875' 9197' H4-12• HES X NP, — 9209' 4-12- HES X NP, D = 3.813' 9218' 7• X 4-12' BKR S3 RRR. IO = 3.958' 14- 12' Flu X NP, D=3.813' 1 9276' I--14-12' 1NLEG, D= 4.00' 9283' anorn DATE REV BY CORNAN S DATE REV BY 0OANB4TS 01109191 M10E ORIGINAL COMPLETION 03/23/16VWJ SET PX PLUG (03121/16) 05109193 SIDETRACK (S -22A) 05/02116 JLS/JND RAL PX PLUG (0428116) 07112/97 SIDETRACKS -22B) 09122116 JNU MTJOR WBS CLEANUP 06/27101 RWO 10/11116 B0/JND WBS CLEAN LP 0625/14 PJC CSG/ TBG/ LNR(PER TALLIES) 0120/15 CJS/JMD RLSETCIBRSET FISH (01117/15) I BKR CTC BCP PKR I ^12219' FISH' CBP PUSHED DH (01/17/15) \ PBTD 12219' PR DHOE BAY UNIT WELL 5-228 PEATT No: '1970510 AR No: 50-02322119-02 1629 SPL 8 793' EAC. Sec.35. T12R R12E BP Exploration (Alaska) S-228 Area of Review The following wellbores are within the '% mile radius for review in preparation for the S -22B conversation to a commingled injector. The primary cement iobs for each of the wellbores and the current well status are provided. Top of Pool Top of Oil Pool Top of Top of Top of Cement Reservoir Chit Ops Mechanical Well Name Status (KuVpIDa)uk (Kuparuk, Cmt (MD) Determined By Status Zonal Isolation Summary Integrity (TVDss) TVDss S 226 New Injection ' 7 118' 6,612' 6,119' 5,722' Calculated, No losses noted in Ivishak Paris open Estimated TOC • 169 bbls G 08-15-18: CMIT-TxIA into Kuparuk report for injection behind 7". Passed to 2698 psi Estimated TOC behind 9-5/8". Dklnot 308 bbls Calculated, No complete lateral to in cement plug from 13.5 ppg Cement Plug S -22A Abandoned 7,182' 6,607' 6,572' 6,078' losses noted in Abandoned 9348'— 10,070 with Lead and 51 tested to report 300 sxs Class G and bbls 15.8 2000psi 8253'— 8603' with ppg 130 sxs Class G Estimated TOC behind 9-5/8". Abandoned wellbore Doyon 14 pumped 308 bbls Doyon 14 Calculated, No 33bbls cement plug 185' cult Class G 13.5 ppg Tagged TOC S-22 Abandoned 7,182' 6,607' 6,572' 6,077' losses noted in Abandoned squeezed into perfs at Lead and 51 at 9348 report 1700 psi top at 8456' bbls 15.8 w/20KLBS. MD/CIBP at 8660" ppg MD/115 cult Class G Cement Plug top at 9644' 267 bbls 1/9/16: MIT -IA Calculated, No Paris open Estimated TOC and 13.5 ppg passed to S-21 Producer 7,348' 6,600' 6,641' 6,027' losses noted in for packer set @ 9,559' Lead, 103 2500 report production MO bbls 15.8 pq tail psi 333 bbls Calculated, No Peds open Estimated TOC and 12.0 ppg G lead cement, 01/09/16: 5-34 Injector 6,623' 6,623' 6657' 5,983' losses noted in for injection packer set at 9656' 15 8 ppg G MIT -IA Passed report MD 61 bbls tail to 2467 psi cement Calculated, no Estimated TOC P&A 1 cult Obtained a squeeze S-25 Abandoned 6,793' 6,609' 6,341' - 6,202 mention of losses Abandoned Cement 112 cult class las G pressure in report 9162-9650' MD 2238 psi Calculated, no Pers open Estimated TOC. 1865 cult 05/11/17 MIT--- S-25A Injector 6,793' - 6,609' 6,341' • 6,202' mention of losses for Packer set at 8824' class G IA passed to in report production MD 2464 psi S-105 X z� S-03, \\ 5-108 X.> MLT 5-15 S -31A S -42A ,- S-31 X� X S-16 S-21 Y \ X S -22B S-115 -__.� S-22 'alp _ X -zsf S -112 l - X -01X (L4 \� I _ 'II,. V' S.42P81 •�[__—�-c— S -01B > - X O, S-42 S-117. `�'� ( )( i'v� S-118 X At" a N S 116 S-116 A 820 0 by S -22B Injection Conversion 820 9 S-22 Injection Location TKUP Fault Polygons Data Sources: Wells, Units, Coastline maintained by BPXA Feet X TKUP TKUD Depth (ft TVDss) Cartography. S -22B - Deviation Survey High. -6492.26 --- Wells within 1/4 mile of S -22B Low -6796.9 S-22BTKUP 1/4 Mile Buffer MAP 1 1 2 3 4 4'-2" o ° D o A A 31-816/1611 SHENKAI SL 13-5M ANNULAR 6'-103/ 6 SHENKAI SL 13-5M DOUBLE RAM B � B $_5 4'_611/16" 4' 1'-41/16" C 1'-93/4" o ° ° O ilk°°CID°G C ° D o D o + 0 0-4„ 10-4- 1-41/2 ZMAINPEN 5.31/2" CLOSING / OPENNING VOLUME (GAL) ITEMS CLOSING VOL OPENNING VOL 30° ANNULAR 23.59 17.41 RAM 4.39 3.91 D D HCR 0.40 0.40 TES THE CONTENTS OF THIS CRANING PROJECT TITLE ROP NOFORMATION NTH$ ANY ARE THE PROPERTY OF NESTERN�AERO DAG NO 13-5M BOP STACK CRANING IS FOR REPROOLICTONOFENETHiSCOW A-U6O-16-6U2 REFERENCE ONLY ANOISNOTFOR ORAYxrvc wrXOLn THE EXPRESS PERMISSION OF MSTERN -""'" uA �^^C^ CRAM TY DATE sCAtf 28/Feb/2018 N.T.S. NeIGXr REv 0 IMTI&RELEASf TY MJP 01/MVQ01L CONSTRUCTION. ENERGY SERVICE8 CORP IS APPROVED WTE SIZE SXEET O REV DESCRIPTION BY APPO WTE STRICTLY PROHIBITED. MJP C1/M8N2018 A 1 OF1 1 1 2 1 3 1 4 Rixse, Melvin G (DOA) From: Ciolkosz, Ryan R <Ryan.Ciolkosz@bp.com> Sent: Tuesday, April 16, 2019 2:50 PM To: Rixse, Melvin G (DOA) Cc: Lastufka, Joseph N Subject: RE: PTD197-051, PBU S-2213, Sundry 319-176 Questions What is CMITTxIA test pressure on step 2 of pre -rig? 3600 psi based on a planned maximum injection pressure of 3270 psi. Please send final schematic with perfs and approximate GLM location. The GLM locations have not been determined yet. We will make sure they are correct on the completion report. The perforating will be a part of a separate Sundry Note: that AOGCC will require a review of the CBL before POI. What interval do you plan to log? From the tubing stub to at least 6618' MD Regarding Post Rig step #3: Provide a description how you plan to underbalance perforate, ie, Eline, displacement method etc. E -line will perform the perforating. The perforating will be a part of a separate Sundry, however, the perforating will most likely not be underbalanced due to low pore pressure, but the well will be swapped to diesel before perforating. Ryan Ciolkosz Drilling Engineer BP Exploration Alaska Office: (907)564-5977 Cell: (907)244-4357 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.eov> Sent: Thursday, April 11, 2019 3:50 PM To: Ciolkosz, Ryan R <Rvan.Ciolkosz@bp.com> Subject: PTD197-051, PBU S -22B, Sundry 319-176 Questions Ryan, What is CMITTxIA test pressure on step 2 of pre -rig? Please send final schematic with perfs and approximate GLM location. Note: that AOGCC will require a review of the CBL before POI. What interval do you plan to log? Regarding Post Rig step #3: Provide a description how you plan to underbalance perforate, ie, Eline, displacement method etc. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin.Rixse@alaska.zov). BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT S -22B (197-051) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 100 10 Jan -1995 1,000,000 100,000 L C 0 10,000 a 1,000 LL u 100 10 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Monthly Injection Rates 10 0 B - — - ---e— Injected Gas (MCFM) o Injected Water (BOPM) _— Cum. Inj Gas (mcf): 8,793,022 Cum. Inj Liquid (bbls): 11,797,959 Jan -2000 Jan -2005 Jan -2010 Jan -2015 1,000,000 100,000 w N 10,000 N 1,000 O 3 100 S 10 Jan -2020 1,000,000 07 0l 100,000 N N O 10,000 d CD of 1,000 m 100 3 S 30 Jan -2020 SPREADSH EET_1970510_PBU_S-22B_Prod-Inject_Cu wes_W ell_Oil_V 120_20190405.xlsx 4/5/2019 1,000,000 100,000 _ t Y C _ cO C 10,000 _ L d a y„ 1,000 V 100 10 Jan -1995 1,000,000 100,000 L C 0 10,000 a 1,000 LL u 100 10 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Monthly Injection Rates 10 0 B - — - ---e— Injected Gas (MCFM) o Injected Water (BOPM) _— Cum. Inj Gas (mcf): 8,793,022 Cum. Inj Liquid (bbls): 11,797,959 Jan -2000 Jan -2005 Jan -2010 Jan -2015 1,000,000 100,000 w N 10,000 N 1,000 O 3 100 S 10 Jan -2020 1,000,000 07 0l 100,000 N N O 10,000 d CD of 1,000 m 100 3 S 30 Jan -2020 SPREADSH EET_1970510_PBU_S-22B_Prod-Inject_Cu wes_W ell_Oil_V 120_20190405.xlsx 4/5/2019 y of tot �� THE STAT III , Alaska Oil and as F'' sKA ��, of L /\ Conservation C® miss n 1� - � �� 333 West Seventh Avenue " ^M., t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -.. Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Engineering Team Leader—CTD &RWO BP Exploration(Alaska), Inc. eco JUN 1 ,V LO1" P.O Box 199612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Oil Pool,PBU S-22B Permit to Drill Number: 197-051 Sundry Number: 318-231 Dear Mr. Egbejimba: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6,0).S" --- , Hollis S. French k� Chair DATED this 13 day of June, 2018. RBDM9� -�-- JUN 13 201 R u . ° � "° pSTATE OF ALASKA 1 faALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPR SAY 28 20 AAC 25.280 /�M 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 , ns u Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change, • - Sa Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 197-051 " 3_ Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 6. API Number: 50-029-22119-02-00 , 99519-6612 Stratigraphic 0 Service EL 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU S-22B • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028257&028258' PRUDHOE BAY.PRUDHOE OIL " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12221. 8819 • 11700 8858 2470 11700 12219 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 35-114 35-114 1490 470 Surface 2650 13-3/8" 34-2685 34-2685 5020 2260 Intermediate 5372 9-5/8" 30-5402 30-5167 6870 4760 Liner 4248 7" 5204-9452 5006-8795 7240 5410 Liner 2948 4-1/2" 9273-12221 8630-8819 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9456-11190 8799-8918 4-1/2"12.6# L-80 28-9275 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 9187/8552 4-1/2"Baker S-3 Hydro Set Packer 9218/8580 12.Attachments: Proposal Summary LI Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch p Exploratory 0 Stratigraphic 0 Development 0 Service IZ • . 14.Estimated Date for Commencing Operations: July 1,2018 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG I I " GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Leemhuis,Jacob be deviated from without prior written approval. Contact Email: Jacob.Leemhuisi bp.com Authorized Name: Egbejimba,John Contact Phone: +1 907 564 4989 Authorized Title: Engineering Team Leader-CTD&RWO Authorized Signature: _/ �. Date: 5/ri / te 2Q "✓ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 V$ Gn 3I Plug Integrity 0 BOP Test Mechanical Integrity Test Location Clearance 0 f✓' Other: 13UP tz'5I y o 071 ` r9'Y),yl ✓1 a r-p rf►moi.-r4-"G�- 71--e- / tr, Z 5 p Sr 5 a C lam'' ''� ¢UD l Post Initial Injection MIT Req Yes No ❑ / I�4a Y 0�� 1A-r. rve-G got•A., 2 S, .�f�bJ Spacing Exception Required? Yes 0 No Lr7/ Subsequent Form Required:/ /D T--d o 4 APPROVED BYTHE I ? Approved by: 6iC31 COMMISSIONER COMMISSION Date: ` 7 VTL G//2/'r ,�� RBDM� /UN 13 2018 �,`,, ,C/l' ORIGINAL S' ubmit Form a d Attachments in Duplica e Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • To: Alaska Oil &Gas Conservation Commission From. Jacob Leemhuism (40)huiRWO/CTD Engineer Date: May 30, 2018 Re: S-22Bi Sundry Approval Sundry approval is requested to perform a tubing swap on S-22Bi to restore integrity to the well. - History and current status: S-22B was sidetracked to its current location in 07/97 and POP'd initially as a pre-produced injector in 1998. S- 22B failed an MIT prior to the well conversion from a producer to injector. A RWO to replace corroded tubing was performed in 06/01 and the well was subsequently converted to injection. The proposed RWO is to allow for commingled injection into both the Kuparuk and Ivishak reservoirs. A RWO is needed because S-22B's current production packer is below the Kuparuk interval. Prior attempts to provide injection support to S-42A involved an unsuccessful coil tubing sidetrack of S-112 in 04/16. Unfortunately, it was not possible to complete the S-112 sidetrack as planned due to unanticipated faults. Commingled injection into S-22B is a fall back alternative to the unsuccessful S-112 sidetrack. Proposed plan: All American Oilfield 111 pulling unit will perform a tubing swap on or around June 15th, 2018. The MASP is 2470 psi. A cement evaluation log will be run after the tubing has been pulled and prior to running new tubing to show competent cement between the Kuparuk Reservoir and Ivishak Reservoir. This Sundry covers a waiver request for setting the new production packer—400' MD from the existing S-22Bi perforations (waiver request for 20 AAC 25.412(b) "packer must be placed within 200' MD above the top perforation"). —We are unable to set the packer lower because the existing production packer is at 9184' MD (272' MD from the top of the perforations). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. • • Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to operable status. Pre-Rig Prep Work: 1. V: PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS. 2. F: OA Integrity Test 3. S: B&F to 9400' MD. Subsidence drift. Set PX plug in X Profile at 9197' MD. CMIT-TxIA 4. F: A/SL: B&F. Load tubing with 1% KCI. 5. E: RCT Cut tubing 6. F: CMIT-TxIA. Circulate in 8.6 ppg fluid and freeze protect to 2500' MD. 7. V: Set TWC. Pre RWO Tree Work Proposed RWO Procedure: 1. MIRU. ND tree. NU and test BOPE. 2. Pull 4W L-80 tubing from jet cut. 3. Run Cement Evaluation Log 4. Run 4W, 12.6#, L-80 VamTop tubing with straddle packer and Unique Overshot. 5. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work vv(1)( 1. Set Packers. MIT-IA 2. Pull Ball & Rod. Install GLVs. Pull RHC. 3. Perf Kuparuk 4. Surface reconnect 5. Flow back to clean up perforations 6. SBHPS. Dummy GLVs 7. Put on injection to PWI. Establish injection into Kuparuk for a minimum of 2 weeks 8. Pull TTP. Set RMX body with WFRV/orifice to allow for Ivishak injection Jacob Leemhuis ROW/CTD Engineer 564-4989 CC: Well File Joe Lastufka • • Loepp, Victoria T (DOA) From: Leemhuis,Jacob <Jacob.Leemhuis@bp.com> Sent: Tuesday,June 12, 2018 10:09 AM To: Loepp,Victoria T(DOA) Cc: Browning, Zachary H Subject: RE:AAO#111: BOP Stack Victoria, Apologies for not providing the ram configuration with the Sundry. The All American Oilfield 111 rig will have blind rams. The BOP configuration will be as follows: • One Annular Preventer • One Blind Ram-type preventer • Mud Cross with outlets for choke and kill lines • One ram-type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP Policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low test for all components. Thanks, Jacob C. Leemhuis From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Tuesday,June 12, 2018 9:06 AM To: Browning,Zachary H <Zachary.Browning@bp.com>; Leemhuis,Jacob<Jacob.Leemhuis@bp.com> Subject:AAO#111: BOP Stack Jacob,Zach, Several Sundries have been submitted using this WO rig. Will there be blind shears or blind rams in the BOP stack to meet BPs internal policy? What will be the ram configuration? Please forward a copy of the BOP test procedure. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(c�alaska.clov 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 Victoria Loepp at(907)793-1247 or Viclo s oee c task v 1 'TREE= 4-1/16 aw V48.LtEAC FMC-GEN 2 • NOTE'S:H2S READINGS AVERAGE 125 ppm ACitJAT V S-2 2 B litYON ML WELL REQUIRESL WELL 70'(9778.PRE--SDTRK WELLBORE NOT OKB.aEV= 65.5' BE ELEV= 36.05 SHOWN ON DIAGRAM BELOW 9-5/8"MILLOUT WINDOW. KOP= 3350' Max Angle= 99'©11877 Datum MD= 9529' 0 2210' --I 4-1/2'HES HXO BV N,ID=3.813" Datum TVD= 8800'SS GAS LET MANDRELS 13-3/8"CSG,68#,L-80,0=12.415" 1.--L 2686' ST MD TVD DEV VLV TYPE LATCH SIZE DATE ___ 1 3001 2933 0 RP MING RK 06/27/01 Minimum ID = 3.726" @ 9263' 4-1/2" HES XN NIPPLE [8-5/8"X 7"BKR ZXP RCR WI TIEBACK D=7.50" '— 6204' t 1 9-5/8'MLLOUT WINDOW:5442"-5418' (OFF PHPSTOCK) 19-5/8"X 7"BKR HMCLIVR HGR D=6.25' —{ 6218' 9-5/8"CSG,47#,L-80,D=8.681" —1 6402' Z E [ 9184' —17"X4-1/2"BKR S-3PKRD=3.875" 9197' H4-112"HESXNP,D=3.813" 4-1/2"TBG,12.6#,L-80 NSCT,.0152 bpf,D=3.958" --j 9208' J 9208' I-14 112'F X tom,D=5.813"} L 9214 H r X 4-1/2"UNK2UE OV ERSHOT, gi E 9218' —17"X 4-1/2"BKR S-3 PKR D=3.850' ' 9241' —{4-1/2"HES X ice.D=3.813" 7"X 5'BKR ZXP PKR WI TIEBACK,D=5.250' —{ 9273' ' 9263' --€4-1/2"FES XN NE,D=3.725' 4-1/2"TBG,12.6#,L-80,.01522 bpf,D=3.958" —1 9276' `t „/ 9276' N4-1/2"WLEG,D=4,00" 9283' ^l—�ELMD TTL A 7"LNR 26#,L-80,.0383 bpf,D=6.276" f—{ 9452' ---_ NA PERFORATION SUMMARY ' REF LOG: COR/ARC5/NIPULSE ON 06/26-07/08/97 ANGLE AT TOP PERF: 23'a 9456' ' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 11700' H4-1/2"WFTCUP(01/17/15) 3-3/8' 6 9456-9476 0 9/21/09 % 2-7/8" 6 9584-9594 0 1012109 % 11889' H BKR CTC ECP PKR 2-7/8" 6 9594-9604 0 10/1/09 % 2-7/8" 6 9614-9634 O 10/1109 2-7/8" 1 9630-9650 O 12/24197 —12219' FISH:CEP PUSHED // 2-7/8" 6 9642-9662 0 10/1/09 A: DH(01/17/15) 2-7/8" 6 9700-9710 0 10/1/09 PBTD --1 12219' 2-7/8" 6 9710-9740 0 9/30/09 2-7/8" 1 9720-9740 0 12/30/97 "r• , / 2-7/8' 1 11070-11090 0 12/30/97 •;, 2-7/8" 1 11120-11140 0 12/30/97 0;.' 2-7/8" 1 11170-11190 0 12/30/97 •• I4-1/2"LNR,12.6#,L-80_0152,.0152 bpf,D=3.958" J-1 11927' TOP OF 4-1/2"SLOTTED LNR,0=3.958" — 11927' 4-1/2"SLOT itil LNR,12.6#,.0152_0152 bpf,D=3.958" H 12218' DATE REV BY COMvENTS DATE REV BY COMIl.ENTS FFU)HOE BAY UNIT 01/09/91 N-18E ORIGINAL COMPLETION 03/23/16 SWOJNC/SET PX RUG(03/21/16) WELL: S-22B 05/09/93 SIDETRACK(S-22A) 05/02/16 JLS/JMO FULL FX RUG(04/28/16) PERMIT No: '1970510 07/12/97 SIDETRACK(S-22B) 09/22116 AO MINOR WBS CLEANUP API No: 50-029-22119-02 06/27/01 MO 10/11/16 BO/JM)'WBS CLEAN UP 1629'SM.&793'EPL,Sec.35,T12N,R12E 06/25/14 PJC CSG/TBG!LNR(PER TALLES) 01/20/15 CJS.JMD RESET CBR'SET FISH(01/17/15) BP Exploration(Alaska) 'TREE= 4-1/16" CNV WELLFEAD= FVC-GEN 2III0 NOTES:1125 READINGS AVERAGE 125 ppm ACTUATOR- BAKE S-22 VRtB�ON MI.WELL REQUIRES A SSSV WHEN ON OKB.RET/= 65.5' MI. WELL>70°@ 9778'.PRE SDTRK WELLBORE NOT ELEV= �, SHOWN ON DIAGRAM BELOW 9-518"MILLOUT BEKOP= 3350' WINDOW. Max Angle= 99°@ 11877 11 1. L H Datum ND= 9529' 4-112"HES X,ID=3.813" Datum TVD' 8800'SS 13-3/8"CSG,68#,L-80,D=12.415" H 2685' Minimum ID = 3.725" @ 9263' 9-5/8"MLLOUT WNJOVV: 4-1/2" HES XN NIPPLE 5402'-5418' (OFFWHPSTOCK) 9-5/8"X 7"BKR ZXP PKR WI TIEBACK,D=7.50" H 6204' t 9-5/8"X 7"BKR WC LNR HGR,D=6.25" - 5218' " 1 I ] ' -14-1/2"HES X NP,D=3.813" 9-5/8"CSG,47#,L-80,D=8.681" H 5402' I------ -17"X 4-1/2"HES TNT PKR I -14-1/T FES X NP,D=3.813" 4-1/2"TBG,12.6#,L-80 V amTop,.0152 bpf,D= - 3.958" H4-1/2"HES X NP,ID=3.813" '0-_-I I-7 X 4-1/2"FES TNT PKR I H4-1/2"HES X NP,D=3.813" , I 7"x 4-1/2"Overshot - - z 9184' --17"X 4-1/2"BKR S-3 PKR,ID=3.875" CI ' 9197' -I4-1/2"HES X NP,D=3.813" 4-1/2"TBG, 12.6#,L-80 NSCT,.0152 bpf,ID=3.958" -I 9208' r9214' -17"X 4-1/2"UNIQUE OVERSHOT I 9208' H4-1/2"FDS X NP,D=3.813" Z W 9218' -17"X 4-1/2"BKR S-3 PKR,D=3.850" I 9241' -14-1/2"HES X NP,D=3.813" 7"X 5"BKR ZXP PKR W/TIEBACK,ID=5.250" H 9273' ' I 9263' -14-1/2"HES XN P,ID=3.725" 4-1/2"TBG,12.6#,L-80,.01522 bpf,D=3.958" -I 9275' I INP, 9276' �4-1/2"vvLEG,ID=4.00" F�f 7"LNR,26#,L-80,.0383 bpf,D=6.276" -I 9452' 9283' ELMD TTL NA PERFORATION SUMMARY I REF LOG: CDR/ARC5/IMPULSE ON 06/26-07/08/97 ANGLE AT TOP PERF: 23"@ 9456' I Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 11700' -14-1/2"WFf CEP(01/17/15) II 3-3/8" 6 9456-9476 0 9/21/09 % 2-7/8" 6 9584-9594 0 10/2/09 % 11889' -I BKR CTC ECP PKR 2-7/8" 6 9594-9604 0 10/1/09 718" % 2 6 9614 9634 0 10/1/09 2-7/8" 1 9630-9650 0 12/24/97 // 12219' 1DH FISH:COP PUSHED 2-7/8" 6 9642-9662 O 10/1/09 (01/17/15) 2-7/8" 6 9700-9710 0 10/1/09 PBTD -{ 12219' 2-7/8" 6 9710-9740 0 9/30/09 Av. 2-7/8" 1 9720-9740 0 12/30/97 "V ./ 2-7/8" 1 11070-11090 0 12/30/97 / . p; 2-7/8" 1 11120-11140 0 12/30/97 ", i:0'.' 2-7/8" 1 11170-11190 0 12/30/97 1.4;1 4-1/2"LNR,12.6#,L-80,.0152,_0152 bpf,D=3.958" -1 11927' TOP OF 4-1/2"SLOTTED LNR,ID=3.958" 11927' 4-1/2"SLOTTED LNR,12.6#,.0152,.0152 bpf,D=3.958" 12218' DATE REV BY COMVENTS DATE REV BY COMVENTS PRUDHOE BAY UNIT 01/09/91 N-18E ORIGINAL COMPLETION 03/23/16 SWC/JIVE SET PX FLOG(03/21/16) WELL S-22B 05/09/93 SIDETRACK(S-22A) 05/02/16 JLS/JM) FULL PX RUG(04/28/16) PEWIT Na '1970510 07/12/97 SIDETRACK(S-22B) 09/22/16 JM) MNOR WBS CLEAN UP AR No: 50-029-22119-02 06/27/01 RWO 10/11/16 BO/JM) WBS CLEAN UP 1629'SIAL&793'EWL,Sec.35,T121*R12E 06/25/14 PJC CSG/TBG/LNR(PER TALLIES) 01/20/15 CJS/JND RESET CIBR'SET FISH(01/17/15) BP Exploration(Alaska) . • a • CO 0• o CD > Y U a Z � ° 0 0 Z ri o a .- %-0z o w '&2 m LL A J ai N 0 J z ill! 74/ Z � cr, alir 'i Z iZ+ MMc! aoao' En lii d O N o m FN FO =Nor 8O0 LI 44 mmii4+b Z a o a mI- 2 I. Pi U) (J) W ¢ 1 wgEo n ¢ U g S n ► a ci. 5.0 ce M W 8 M Q1 baa tg [7 Z N 10›-C N x N O W N LL K N W w C =p 0==r 0 0 r U�-�NU W u W oF� � Z 1 LL m O ro>o o o to .- w�' a— r www. U i Co wwwaagrcaz Co ,-a w ,a q H o o NR- io a a M NF g:1 N 17 111111111" I- 11111 Iii I I p - ..ft,,, 0.1 oG u fi=t It © o1._ DCDCC_ 0 0 s_ ( - - 0 - — II I I 4 co z y CO� w W 1 a o po Z M ► I N 0 rl Q 111. Tr a J Q J I: .111 ~ m Cn51 UJw _ 1- Z �' —Z Qm _� e `n YZ YD—i > CO Z< Mw0 tp) o r M Zu_p00 PUWF-U U Z55 W GQ CC W O>W 162§19E 2 D 19E 2?aKQU Q CO 1 0 0 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,October 12,2017 P.I.Supervisor j6 (of, (/7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-22B FROM: Lou Laubenstein PRUDHOE BAY UNIT S-22B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jf�� NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-22B API Well Number 50-029-22119-02-00 Inspector Name: Lou Laubenstein Permit Number: 197-051-0 Inspection Date: 10/12/2017 Insp Num: mitLOL171012141157 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-22B Type Inj ®TVD 8549 ' Tubing 469 471 - 468 - 462 - PTD 1970510 Type Test EllTest psi 2137 iIA 657 2302 2285 2279 i BBL Pumped: 5.6 'BBL Returned: 2.6 OA 147 • 162 - 166 - 167 Interval 4YRTST P/F P Notes: %AM #..} y Thursday,October 12,2017 Page 1 of 1 STATE OF ALASKA iKA OIL AND GAS CONSERVATION COMk. JION - REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate Other O Mill&ReSet Plug Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory 197-051-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-22119-02-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028258 PBU S-22B 9 Logs(List logs and submit electronic and printed data per 20AAC25.071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12221 feet Plugs measured 11700 R E C E I V E D true vertical 8819.26 feet Junk measured 12219 feet FEB 0 9 2015 Effective Depth measured 9775 feet Packer measured See Attachment feet true vertical 9019 65 feet true vertical See Attachment feet AOGCC Casing Length Size MD TVD Burst Collapse V Structural None None None None None None Conductor 80 20"91 5#H-40 30.55-110 55 30.55-110.55 1490 470 Surface 2651.81 13-3/8"68#NT-80 30 05-2681.86 30 05-2681 82 5020 2260 Intermediate 5374.25 9-5/8"47#L-80 25.25-5399 5 25.25-5164.6 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED r Lb 2 0 20)!,, True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"MCX I-SSSV 2210 2209 97 SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2622 0 0 2015 Subsequent to operation 0 0 3220 160 705 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service ll Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG 2 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 0 Exempt 314-390 Contact Garry Catron Email Garrv.Catron a7BP.Com Pnnted Name Garry Catron Title PDC PE Signature liPhone 564-4424 Date 2/9/2015 I 1/71-- Z/l//ic 17 #C Form 10-404 Revised 10/2012 my RBDMS14 F mitri lotO Packers and SSV's Attachment ADL0028258 SW Name Type MD TVD Depscription S-22B SSSV 2210 2209.97 4-1/2" MCX I-SSSV S-22B PACKER 5201.78 5004.63 7" Baker ZXP Top Packer S-22B PACKER 9175.77 8541.51 4-1/2" Baker S-3 Perm Packer S-22B PACKER 9215.77 8578.17 4-1/2" Baker S-3 Hydro Set Packer S-22B PACKER 9273 8630.44 5" Baker ZXP Top Packer S-22B PACKER 11886.91 8830.51 4.5" Baker CTC Packer m a o 0 0 0 0 0 0 50 O co O O I- V LO N O 14") CNN- N- 0 N o 0 0 0 0 0 0 O V co N CO CO 7 �f Co N 'Cr O ' CO <- C0 N- CO to CO CO (0 CO V M N LC) CO CO CO 'Cr O LO V N O O O CO o) oo Co co Imo- 00 CO 10 CO - 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O 41 U 3 a) c6 •. E I- 03V) w4-- D -•-. ... o 0 RS C W p TDw F" E Q.. m 2 E _amMN < O n 'D LU L LO O c ~ p > co 0 N or- J o o O-N- 0 0 Q+�_ V J p) C J M N 2 Q 2 E ?� o a W O c o_ ;= o 0 U) m -00 - ( > a) 0 i > G _ 2 2 G _ - / 7 \ k ® DrG 7 ƒ f \ = r 9 O « I_ % /\ 5 e 3 E e > I \ \ - \ � 0_ ® i / \ c _ & b c n n c = 2 0 \ U) t 'a& CO cn » = _o ,- t e �/ / � § �\ / 5 O o \ ) / 0N- 0 ? 0 / 0 % a . $ \ § e u \ ¥ 2 m I - f \ a_ � / \ E _ »e - 0 0_ o) 0_b 0_ _I § \ / = E_ oc O 2 O o)0 CU O - 0 00 k J 2 � § k \ 1 - - • G $ E + / \ E 3 u ® 2 0 _J 7 C 7 % / 7 o ° _ e 2 R / [ /\ 9 / \ CI) § a - QUU3 Ti� 7 % o �� _ - _ - > / ƒ / $ G / / # .2 . 2 v ® - © § 06 co 1.- CU 0 \ / 0 \ � � ? / / $ $ _ D _Y = _ • 2 c _ mwo a 0 - m o I e a o * - » e as = 2 ® . e I lc e E a) E & * = _ - E E $ k § 4= % \ E § > > § („I E m g e m D .L i- 1 0 ? / / 11 _ .C7- oR 6 c _ R = 3 e 00cno_o 000a - e r \ \ $ & TREE= 4-1/16" CNV � D FMC-GEN2 S Y NOTE:H2S READINGS AVERAGE 125 ppm ACTUATOR BAKER -2 MW L WELLON M 70 °t 97L WELL UIRES A SSSV WHEN ON PIE-SDT WELLBORE NOT KB.REV= 68.34' BF.REV= 36.05' SHOWN ON DIAGRAM BELOW 9-518"MILLOUT KOP= 3350' WINDOW. Max Angle= 99"@11877 Datum MD= 9529' Datum ND= 8800'SS 0 2210' — 4-1/2"HES HXO BV N,D=3.813" 13-3/8"CSG,72#,L-80,D=12.347" H 2685' GAS LFT MANDRELS Minimum ID = 3.726" @ 9263' 0ST MD ND DEV VLV TYPE LATCH SIZE DATE 1.41,434-1/2" HES XN NIPPLE 1 3001 2933 0 RP G FE 06/27/01 9-5/8"X 7"BKR ZXP PKR VW TEBACK,D=7.50" -i 5204' 1 9-5/8"X 7"BKR HMC LNR HGR,D=6.25" H 5218' I 95!8"MLLOIJT WINDOW: 9-5/8"CSG,47#,L-80,D=8.681' H 5402' 5402'-5418' (OFF WHPSTOCK) z S 9184' H 7"X 4-1/2"BKR S-3 PKR,D=3.875" I I 9197' -1 4-1/2'HEM XN ',D=3.813" TOP OF UNIQUE OVERSHOT,D=3.937' H 9208' I--I 1 11 9208' H 4-112'HES X NP,D=3-813' z X 9218' H 7"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' 9242' H 4-1/2'HE5 X NP,D=3.813' 7"X 5'BKR ZXP PKR WI TEBACK,D=5.250' H 9273' k I I 9263' —I 4-1/2'HES XN NP,D=3.725' 4-1/2"TBG,12.6#,L-80,.01522 bpf,D=3.958" —4 9274' / t 9275' H 4-1/2"WLEG 7'LNR,26#,L-80,.0383 bpf,D=6.276' - 9452' C 9283' —4 ELK)Tn- PERFORATION SU M4RY REEF LOG: CDRIARC5/I FULSE ON 06/26-07/08/97 , ANGLE AT TOP FERE: 23°Q 9456' I Note:Refer to Ftoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 3-3/8" 6 9456-9476 0 9/21/09 2-7/8' 6 9584-9594 0 10/2/09 2-7/8" 6 9594-9604 0 10/1/09 , 11700' H4-1/2"WFT CEP(01117/15) 2-7/8" 6 9614-9634 0 10/1/09 2-7/8' 1 9630-9650 0 12/24/97 % 11889' —BKR CTC ECP R(R 2-7/8" 6 9642-9662 0 10/1/09 2-7/8' 6 9700-9710 0 10/1/09 // `. —12219' HF (o'E7 1PUSHED 2-7/8" 6 9710-9740 0 9/30/09 2-7/8" 1 9720-9740 0 12/30/97 PBTD H 12219' 2-7/8" 1 11070-11090 0 12/30/97 40. 2-7/8" 1 11120-11140 0 12/30/97 `V 2-7/8" 1 11170-11190 0 12/30/97 /. ;;, �:., 4-1/2"LNR,12.6#,L-80,.0152,.0152 bpf,ID=3.958" H 11927' TOP OF 4-1/2'SLOTTED LNR,D=3.958" 11927' 4-1/2'SLOTTED LNR,12.6#,.0152,.0152 bpf,ID=3.958" 12218' DATE REV BY COMMENTS DATE REV BY COIVIVENTS PRUDHOE BAY UNIT 01/09/91 N-18E ORIGINAL COMPLETION 02/15/11 M 3/JMD ADCEDSSSV SAFETY NOTE WF31: S-22B 05/09/93 SIDETRACK(S-22A) 01/18/12 T ANI'JMt)ADCF )H2S SAFETY NOTE PEM/No: 97-51 07/12197 SIDETRACK(S-22B) 06/25/14 PJC CSG/TBG/LNR(FM TALLIB) AR No: 50-029-22119-02 06/27/01 MO 01/20/15 CJS/J1.4) RESET CEP/SET FISH(01/17/15) 1629'SNL 8 793'EWL,Sec.35,T12N,R12E 10/04/09 ANSV SET CEP(09/17/09) 10/04/09 RRD/SV ADPERF(9/21,30,10/01-02/09) BP Exploration(Alaska) SchwMherger NO. 5180 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 t ' 4'; �. t:` Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 ? yJ� Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 9 Log Description Date BL Color CO OWDW -SW B3150 -00032 RST/WFL 11/07/09 1 1 L -223 8581 -00014 USIT 10121!09 1 1 S -218 BSJN -00018 USIT 10/21/09 1 1 L -222 B3SO.00031 USIT 11/07/09 1 1 11.2 -24 B148 -00079 RST 10/31/09 1 1 1-2 -32 8148 -00078 RST 10/30/08 1 1 1-1 -14 AVIW00029 RST 10/27/09 1 1 L2 -18A 8148 -00077 RST 10/30/09 1 t D -288 AXED -00053 MCNL 10102109 1 1 5 -228 BBKS -00008 RST ~ 1 10127!09 I 1 D AWL8-00038 RST I 09/27/09 1 1 18 -15B AYS4 -00107 RST 10131/09 1 1 04 -21 ANHY -00116 RST 1 10127109 1 1 L2 - 07A AY00 -00047 RST 10/29/09 1 1 OWDW -SW 83SO -00032 RST 11/07/09 1 12 - 05AP81 40015441 ON MWDlLWD EDIT _ 07/01/07 2 1 06 -218 OBAKA0016 ON MWD/LWD EDIT 07128/08 2 1 0-16A 09AKA0175 ON MWD/LWD EDIT 09/07/09 2 1 L -223 09AKA0081 ON MWD/LWD EDIT 10/10/09 2 1 L -223 B581-000114 CH EDIT PDC (USIT) 10/21/09 1 S -218 85JN -00018 CH EDIT PDC (USIT) 11012 1 L -222 8350 - 00031 CH EDIT PDC (USIT) 04 -33A 09AKA0075 OH MWD/LWD EDIT — 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suile 400 900 E. Benson Blvd. Anchorage, AK 99503.2838 us uas tons L omm Anchorage, AK 99503 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD MPI -13 AWJI -00055 IMOMIONINIMMEMMIIIIM, -VM.= 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE t1 Nip 10/24/09 1 1 04 -11A AWL8 -00040 INJECTION PROFILE e a 6 10/24109 1 1 V -220 AYS4 -00100 INJECTION PROFILE T 4 i i 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE (REVISED) Z. l A 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) .C...- 005 t /09 G 07/28/09 1 1 L -214A AP3O -00064 INJ PROFILE/RST 10/06/09 1 1 S -22B AYTU -00052 INJECTION PROFILE a 219 J If 10/27/09 1 1 14 -07 8581 -00016 PROD PROFILE i (n I /9 10/27/09 1 1 07 -05 AYS4 -00105 SCMT I'-t- -0 'S /'fJ 10/28/09 1 1 R -28 AWL8 -00041 USIT -a 10/26/09 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE Of $9 n' 10/30/09 1 1 PSI -05 B148 -00080 TEMP WARMBACK SURVEY (1To_ go 1 A c) Ice) o .i 11/03/09 1 1 C -12B B2WY -00030 MCNL r e 09/19/09 1 1 U -05A 09AKA0074 '1 J t A71A,101 gUr�� -D 4 =norm 08/19/09 2 1 01 -18A 09AKA0151 OH MWDILWD EDIT ZrfilialiNalliff., 08/27/09 4 1 H -09 ANHY -00110 RST .t j'- 470 I'- 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnica) Data Center LR2 -1 2525 Gambol! Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 t ,sf, o- I t 4 I MEMORANDUM 'ro: Jim Regg ~~i~ (L'~ ~'S ~ ~~( P.I. Supervisor ~ FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Thursday, October 15, 2009 SUBJECT: Mechanical lntegrity Tests BP EXPLORATION (ALASKA) INC S-22B PRUDHOE BAY IJNIT S-22B Src: Inspector NON-CONFIDENTIAL Reviewed Byy, P.I. Suprv •~~ Comm Well Name: PRUDHOE BAY IINIT S-22B API Well Number: 50-029-22119-02-00 Inspector Name: Chuck Scheve Insp Num: mitCSO91o13085924 Permit Number: 197-os1-0 Inspection Date: 10l1 ]/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ s-2zs ~%~TYpe InJ• ~, ~ TVD ~ - ssa9,, -T--IA -~ o~ zsoo ~ ~ -~--- ~ ~---- 2aso ~ zaao - -~--- - P.T.D~19~osio ypeTest ~ srT ~ ~ Test psi ' 2~3~ ~ I pA l~o i 200 -{----- - 20o i zoo =--- _ --- -- ---- -- r - ,~ Tubing~ s~ i szo~ r Interval a~TST p~F s~o sio __ 1 __ Notes: _ ~BtS~~w h~~-~ ~`, ~ ~` ~Ol)~ j" '" ' Y: e•.d ca b Thursday, October 15, 2009 Page 1 of 1 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ Performed: Alter Casing ~ Pull Tubing~ Pertorate New Pool ~ Waiver~ Time Extension~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. R~ermit to Drill Number: Name: Development ^ Exploratory ^ ~ 197-0510 3. Address: P.O. Box 196612 Stratigraphic^ Service ^Q ¢ I Number: Anchorage,AK 99519-6612 ~ 50-029-22119-02-00 8. Property Designation (Lease\mber) : 9. Well Name and Nu er: ~~ ADLO-028258 PBU S-226 10. Field/Pool(s): ,~ ~ C ~- ~ 2 ~QOg PRUDH OE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: ~laska Oil & Gas Cons. Corrunis ~ An ' chorage Total Depth measured 12221 feet Plugs (measured) 9766 9/17l09 feet true vertical 8819.26 feet Junk (measured) None feet Effective Depth measured 12219 feet Packer (measured) 5204' 9184' 9218' true vertical 8819 feet (true vertical) 5006' 8549' 8580' Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2665 13-3/8" 72# L-80 SURFACE - 2685 SURFACE - 2685 4930 2670 Intermediate 9696 9-5/8" 47# L-80 SURFACE - 5402 SURFACE - 5166 6870 4760 Production Liner 4248 7"26# L-80 5204 - 9452 5006 - 8795 7240 5410 Liner 2934 4-1/2" 12.6# L-80 9273 - 12221 8930 - 8819 8430 7500 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and Vue verticai depth) 4-1/2" 12.6# L-80 SURFACE - 9274' SURFACE - 8631' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X7" BKR 5204' 5006' 7"X4"-1l2" BKR S-3 PKR 9184' ~~ p~~ 8549' 7"X4"-1/2" BKR S-3 PKR 9218' 8580' 7"X5" BKR ZXP PKR 9273' 8630' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbi Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2325 471 Subsequent to operation: 3720 1217 14. Attachments: Well Class after work: / Copies of Logs and Surveys Run F~cploratory^ Development ^ Service Q Daily Report of Well Operations X . Well Status after work: Oil Gas WDSPL GSTOR ^ WAG Q~ GINJ [] WINJ ~ SPLUG ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-296 Contact Gary Preble Printed Name Gary Preble TiUe Data Management Engineer Signature Phone 564-4944 Date 10/9/2009 ion Form 10-404 t2evised 7/2009 w ~~d .~ ~ ~,(~ ,~j~~~ ~~~/~ ~~~ ~ Submit Original Only "7 j~, ~-.R J / S-226 197-051 PFRF ATTACHMENT ~ i Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-22B 7/12/97 SL 11,927. 12,219. 8,825.11 8,819.29 S-22B 12/25/97 APF 9,630. 9,640. 8,946.81 8,954.03 S-22B 12/25/97 APF 9,640. 9,650. 8,954.03 8,960.96 S-22B 12/28/97 APF 9,720. 9,740. 8,999.38 9,007.4 S-22B 12/28/97 APF 11,070. 11,090. 8,935.21 8,932.75 S-22B 12/28/97 APF 11,120. 11,140. 8,928.61 8,925.53 S-22B 12/28/97 APF 11,170. 11,190. 8,921.02 8,918.13 S-22B 12/14/00 BPS 9,248. 9,258. 8,607.61 8,616.74 S-22B 7/14/01 BPP 9,248. 9,258. 8,607.61 8,616.74 S-22B 9/17/09 BPS 9,766. 12,219. 9,016.69 8,819.29 S-22B 9/20/09 APF o' 9,476. 9,496. 8,817.23 8,835.38 S-22B 9/21/09 APF Z,' 9,456. 9,476. 8,798.84 8,817.23 S-22B 9/30/09 APF v 9,710. 9,740. 8,995.02 9,007.4 S-226 10/1/09 APF ~ 9,594. 9,604. 8,919.04 8,926.96 S-22B 10/1/09 APF ° o' 9,614. 9,634. 8,934.73 8,949.73 S-22B 10/1/09 APF Za' 9,642. 9,662. 8,955.44 8,968.86 S-22B 10/1/09 APF a' 9,700. 9,710. 8,990.29 8,995.02 S-22B 10/2/09 APF lo' 9,584. 9,594. 8,910.98 8,919.04 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 • • S-ZZB DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ~, ~ 9/16/2009 ""`WELL INJECTING ON ARRIVAL*** (peforating) ,~ ; LRS DID SCHMOO-B-GONE ' RAN 3.625" CENT, 3.625" CENT BARBELL TO DEV @ 9838'SLM ~ RIH W/ PDS 40 ARM CALIPER ;"**CONT WSR ON 9-17-09"" ~ 9/17/2009~**'CONT WSR FROM 9-16-09''*` (POI) ~~ ~ ~ ~ RAN PDS 40 ARM CALIPER FROM 9852'SLM/9848'ELMD TO SURFACE ; (GOOD DATA) ~ ;OBTAINED -4' DEPTH CORRECTION FROM CALIPER DATA 'SET 4 1/2" BAKER CIBP @ 9776' MD ~'""WELL LEFT S/I ON DEPARTURE"** ~ ________ ~__ __._ _____ ___ _____ ~ ~_ 9/19/2009""'WELL INJECTING ON ARRIVAL*"" (ELINE - ADPERF) SSV=O, MV=C, SV =C, WV = 0, IA/OA = OTG, INITIAL T/I/O = 350/0/200 IWELL SHUT-IN AFTER ARRIVAL, RU ELINE ~'""JOB IN PROGRESS CONTINUED ON 20-SEPTEMBER-2009*'`* ___ ___.__ ..~ _..._..__ ~ . _ . _ ~. 9/20/2009;T I%0=200/0/150, Temp=S/I, Assist E-line with Hot down Tubing (Perforating) ; Pumped 2 bbls 60/40 and 132 bbls 180"F diesel down Tbg. E-line has control of iwell upon departure. FWHP's=1500/0/150. ~ 9/20/2009'T/I/O = 640/Vac/140. Temp = SI. IA FL, note integrals (pre AOGCC MIT-IA). IA ~ FL near surface. No integrals installed. ! E-line in control of well. -~ x__ _ ______~- ------ --__._ _._____. _.__.___-----___.____ __ 9/20/2009~""*JOB CONTINUED FROM 19-SEPT-2009'''* (ELINE-ADPERF) ~RIH WITH 3-3/8" GUN STRING, MAX OD = 3.625", SAT DOWN AT 2210' ;(SSSV), PULLED MAX SAFE PULL TO GET FREE. LRS PUMPED 130 BBLS 'OF 180 DEGF DIESEL AT 1.5 BPM. RUN JUNK BASKET GAUGE RING, MAX 'OD = 3.63", STOP DUE TO DEVIATION AT 9756', NO INDICATION OF 'STICKING, ABLE TO PASS SSSV AT 2210' NO PROBLEM. RIH WITH 20', 3- ~ ;3/8" HSD POWERJET 3406, STOP AT 9600' DUE TO DEVIATION. 'P F RATE INTE 6'-9496', DEPTH REFERENCED TO SLB GR/CCL ~ DATED 24-DEG2997. STICKY W PULLING SHOT GUN THROUGH SSSV. ;CURRENTLY IN HOLE WITH 3.63" GAUGE RING/JUNK BASKET. ~"**JOB IN PROGRESS, CONTINUED ON 21-SEPT-2009**" -- __. ___ r ~~-~ 9~21/2009;*"*JOB CONTINUED FROM 20-SEPT-2009"'''(ELINE -ADPERF) j IN HOLE WITH 3.63" GAUGE RING/JUNK BASKET. TAGGED TD WITH JUNK ~ BASKET AT 9776', TIGHT SPOT AT 9615', MADE SEVERAL PASSES ~ACROSS TIGHT SPOT WITH JUNK BASKET, SPOT GOT BETTER AFTER MULTIPLE PASSES. WITH GUN #2 TAGGED AT 9600'5', 400 LBS OVERPULL ;TO GET FREE. PFRFORATED INTERVAL 9456'-9476', WITH 3-3/8" HSD :POWER JET 3406, 6 SPF, 60 DEG PHASING,-6E~T-~I REFERENCED TO SLB ~ iGR/CCL DATED 24-DEG2009. COULD NOT GET BELOW 9600'. GUN 3 jORDER CHANGED TO 2-7/8" 10' GUNS. 2-7/8" GUNS ALSO HUNG UP ON ;THE DOGLEG EVEN AFTER SEVERAL ATTEMPTS AT SLIDING IT ~~ ~THROUGH. JOB CANCELLED TO CLEAN OUT WELL AND GET SLICKLINE • ~ 1 ~ ;ON THE WELL.~POOH, RDMO. SSV=O, MV=O, WV=C, SV=C, IA/OA=OTG, ~ ~ ~ FINAL T/i/O = 300/0/100, WELL SHUT-IN ON DEPARTURE. DSO NOTIFIED ? ;*"*JOB POSTPONED FOR SLICKLINE TO CLEAN OUT DOG-LEG*** ~ ~ ~ I ; ; 3 ~ ~ 3 ~ ~ ~ ' ~ ~ ~_ ~~_ ~ 9/23/2009 T/I/0= 1,000/40/220 Freeze Protect Tbg and Flowline for Slickline. Pumped into ~ the Flowline with 40 bbls of 60/40 methanol and into the Tbg with 38 bbls of ~ 60/40 methanol. Final WHP's = 200/0/200 ~ jSlickline on the well at the time of departure ~ { ~ i ~ ` ~ ~ ~ ~ ~ _ _._~ _.._ ____ ~ 9/23/2009~**'`WELL INJECTING ON ARRIVAL*** (pre adperf) ~~ ~ TAG HARD @ 9,700' SLM W/ 12' x 3-3/8" DUMMY PERF GUN & 2.50" S- ~ E ~BAILER (small sample of shmoo) ~TAG TOP OF CIBP W/ 3.50" CENT & SAMPLE BAILER @ 9,766' SLM (NO ~ ~ ~SAMPLE) ~TAG TOP OF CIBP W/ 12' x 2-7/8" DUMMY PERF GUN @ 9,766' SLM ~ ~*'`"W ELL LEFT S/I, TURN OVER TO PAD OP**" ~ ( ~ ; a ; ~ , ~ ~ ~ 9/24/2009 T/I/O = 1160/40/200. Temp = 120*. IA FL (pre AOGCC MIT-IA). WAG (water). ~ ~ IA FL near surface. ***Needs integral installed**'. SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. i ~ ; ~ ~ ~ i [ ~ ~ ~ s ~~ ~ - -~ * ~ 9/28/2009,T/I/O- 1200/100/200, Temp- 120 . MITIA PASS to 2500 psi ( Pre- AOGCC ; ~test). MITIA; Pumped 4.6 bbls of inethanol down IA to pressure up. IA lost 20 i ~psi in 1st 15 minutes and 10 psi in 2nd 15 minutes for a total loss of 30 psi in 30 ~ ~minute test. Bled IAP to 100 psi. FWHP= 1200/100/200. ~ ~ WV,SSV,MV= Open. SV= Closed. IAV,OAV= OTG. I ~ ~ ~ ~ ~ i ~ ~_.r Y_,..____,..._.... ....___--___~_...._....--- _ . ~ ..._._ _ - --- ____.. . . ~ ~ ~ ~ 9/30/2009 "*"WELL FLOWING ON ARRIVAL*""(E-LINE ADPERF) ~1NITIAL WHP 400/0/150 ~ SSV-OPEN(FUSIBLE CAP INSTALLED) SWAB-CLOSED, IA/OA=OTG, ~ MASTER OPEN RIG UP E-LINE FOR PERFORATION, PERFORATE INTERVALS 9710'-9740' [ WITH 2.875" PJ HSD ~ ~***JOB IN PROGRESS CONTINUED ON 1-OCT-09 WSR"** l I ~ ~ ~___ _ ____~- _._ __ ~ _ 10/1/2009~***CONTINUED FROM 30-SEP-2009"**(E-LINE PERFORATION) , ~ ° PERFORATE INTERVALS 9700' - 9710', 9642~, ~~'!a'-A~34' 9594'-9604' ~ WITH 2 875" P i H~n ~ PENETRATION = 25.3", ENTRANCE HOLE DIAMETER = 0.38" ~ ***JOB IN PROGRESS CONTINUED ON 2-OCT-09 WSR"** ~ ~ i ~ i ~ j~ 10/2/2009~'`'`*LOG CONTINUED FROM 01-OCT-2009"** (E-LINE PERFORATION) ~ ~~ ~ ~ P.FBF~R~EJ,~ITERVALS 9584'-9594' W ITH 2.875" PJ HSD ~ ~ PENETRATION = 25.3", E E HOLE DIAMET =.38" ~WELL RETURNED TO INJECTION. SWAB CLOSED, WING OPEN, MASTER ~OPEN, VALVES OPEN TO GAUGES, SSV OPEN (FUSIBLE CAP RE- ~ ~ ~ INSTALLED). DSO NOTIFIED OF DEPARTURE i ~ FINAL T/I/O = 0/0/120 PSI ~ ~"*"JOB COMPLETE"** j ~ l 9 ~~. ~_ ~ w~,..,,... ..~ FLUIDS PUMPED BBLS 80 60/40 METH 26 METH 264 DIESEL 370 TOTAL • ~ ~ ~ ~_. ~ ..,. ~ ~~~ ~~~~~~~~ ~~ ~~ ~~~ ~~ ~` ~`,~~ ~ ~~-,; ~~ ~ ~; ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~ ~ ~;, .;_~ . ~, ~ ~~ ~ ~ ~'~ t~~-~ ~.~~~ ~ R ~ ~ ~~ ~.. ~ ~, ~~a ~~ ~ ~~ u _ ..~ ~~ ~~7~ ~iL ~ 1t~.7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSER'FA'1`I011T CODII-IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 , PHONE (907) 279-1433 ~ FAX (907) 276-7542 Ms. Danielle Ohms Production Engineer ,a BP Exploration (Alaska), Inc '`' ~~~ `" `~'~` ' ` ' ~ `'~ ~~ ``~' P.O. Box 196612 Anchorage, AK 99519-6612 O~~ ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, S-22B \ Sundry Number: 309-296 ~y Dear Ms. Ohms: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair w~ DATED this 3 day of September 2009 Encl. STATE OF ALASKA l i~ ~~ f~ALAS~IL AND GAS CONSERVATION COMMIS~ ~.v ~APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Pertorate Q~ Waiver~r Other^ ,,, ~. d~"." ; ° Alter casing ~ Repair well ^ Plug Perforations ^~ - Stimulate ^ Time Extension ~ Change approved program ~ Pull Tubing ^ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 197-0510 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~_ 6. API Number: Anchorage, AK 99519-6612 50-029-22119-02-00 - 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 ^ g_z2g - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADLO-028258 - 65 KB - Prudhoe Bay Fieid / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12221 - 8819.26 _ 12219 8819 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" Surtace 110 Surface 110 Surface 2665 13-3/8" 72# L-80 Surtace 2685 Surface 2685 4930 2670 Intermediate 9696 9-5/8" 47# L-80 Surtace 5402 Surface 5402 6870 4760 Liner 4248 7" 26# L-80 5204 9452 5006 8795 7240 5410 Liner 2934 4-1/2" 12.6# L-80 9273 12221 8930 8819 8430 7500 Pertoration Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATfACHED - - 4-1/2" 12.6# L-80 SURFACE - 9274' Packers and SSSV Type: 9-5/8"X7" BKR ZXP PKR 5204' 7"X4-1/2"BKR S-3 PKR 9184' 9218' 7"X5" BKR ZXP PKR 9273' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ~ Service Q' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 9/1/2009 Oil ~ Gas ~ Plugged ^ Abandoned ~ 17. Verbal Approval: Date: WAG Q. GINJ ~ WINJ ^ WDSPL ~ Commission Represenfative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Danielle Ohms Printed Name Danielle Ohms Title P E Signatu ° Phone Date 564-5759 8/26/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ~ ~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. ~ ~ _~• ~ ~ ~or4 rc ~ r'e- ti~r~ .~ ~'e ~..~ .,,f (~'~- ~ ° ~ . ~ Subsequent Form Required: /~ ~ APPROVED BY ~ ~ ~ ~ Approved by: R,.~ COMMISSIONER THE COMMISSION Date: ~ ~` ~~ ~,~.' ~ ~.~' ~ ~~~~~9 ~~jy;~ ~ ~.~ i3 Al . L ~ ~ ~ ° ~;ir~~ Form 10-403 Revised 06/2006 ~ ;. ., ~'3~~ Submit in Dup~cate o~ ~~ ~~:~ ~~~ _ R:~ ~ 2~~~ S-22B 197-051 PERF OTTACHMENT ~ Sw Name Operation Date PerF Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-22B 7/12/97 SL 11,927. 12,219. 8,825.11 8,819.29 S-22B 12/25/97 APF 9,630. 9,640. 8,946.81 8,954.03 S-22B 12/25/97 APF 9,640. 9,650. 8,954.03 8,960.96 S-226 12/28/97 APF 9,720. 9,740. 8,999.38 9,007.4 S-22B 12/28/97 APF 11,070. 11,090. 8,935.21 8,932.75 S-22B 12/28/97 APF 11,120. 11,140. 8,928.61 8,925.53 S-22B 12/28/97 APF 11,170. 11,190. 8,921.02 8,918.13 S-22B 12/14/00 BPS 9,248. 9,258. 8,607.61 8,616.74 S-22B 7/14/01 BPP 9,248. 9,258. 8,607.61 8,616.74 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 ~ bp ~ To: C. Olsen/J. Bixby GPB Well Ops Team Leaders From: Danielle Ohms, S Pad Engineer Whitney King, Wells Engineer Subject: S-22Bi Set CIBP; Caliper; ADPERF; IPROF/Borax log Please perform the following procedure(s): ~ Date: August 21, 2009 Code: PBSPDWL22-C IOR: 165 BOPD Est. Cost: $180,000 1 S Pull MCX. SBG. Drift as dee as ossible. Cali er. Set CIBP. 2 F SBG after SL ulls MCX 3 O POI to confirm CIBP holdin 4 E Ad erf 5 O POI 6 E Borax/IPROF lo ** PARTNER/AOGCC APPROVAL REQUIRED** Current Status PWI Last Rate/Pres: 3500 bwpd C 700 psi Max Deviation 99° at 11877 ft Min ID 3.725" C~ HES NX C~ 9263' MD Last Tag: 12,218' MD on 8/2/03 Last Downhole Op: Set MCX Q 2210' MD on 4/20/05 Latest H2S vafue: NA - watch out for H2S in returns SBHP/T: 3541 psi based on 5/28/03 FL Ref-in Log: SWS Anadrill/CDR Impulse Log 06/28/97-07/08/97 Ob jecti ves/Discussion The objectives of this procedure is to modify and improve the sweep to this active pattern; it will almost be like getting a new injector as injection should be shifted to an area 2000' away from current injection! All of the planned perfs are expected to be accessible with e-line (tagged up at 9871' MD with SL on 7/29/03). After perforating, the well should be placed on injection for 2 to 4 weeks to establish injection into the new perfs. Then a borax log along with an IPROF is needed to check containment to the Sag and Ivishak perfs and assess new injection splits among the new perfs. The section above the top Sag perf (behind 2 strings of pipe) will be the area of focus for the Borax log to ensure no injection is travelling out of zone along the wellbore. Well History/Background Well S-22B was sidetracked to its current location in 1997 and POP'd initially as a pre- producer injector in 1998. It initially produced from the slotted liner toe that was landed in the Sag formation. Total fluid rate from this section averaged 3000 bfpd and watercut increased from 30% to 75% watercut between 8/97 and 12/97. This high watercut is not indicative of typical Sag production and some commingled Ivishak production via a fault is suspected. Uphole Ivishak perfs (limited to 1 SPF) in the cased/cemented section were added in 12/97 and oil rate increased and watercut dropped initially, though oil rate declined to 300 bopd at 90% watercut by 10/99. 1/10 S-22B failed an MIT prior to well conversion from a producer to injector. A RWO to replace corroded tubing was ~formed in 6/01 and the well was su~quently converted to injection. Injectivity appears comparable to other S Pad Ivishak injectors, though an 8/03 IPROF indicated 94% of injection into the slotted liner toe section. Again, likely that the majority of injection into this "Sag" section is actuaUy entering a fault in this area, creating a pathway to the Ivishak. There was a 3600 bbl lost circulation event at 11700' MD and fracture/fault responses in the Sag on the resistivity log at 11920', 11993' and 12131' MD. Offsets to S-22B include S-33, S-36, S-01 B, S-17C, S-44L1, S-21 and S-35, 6 of which are operable wells and 4 of which are online regularly. With the majority of injection continuing to enter the same section there is little MI benefit left under the current configuration. Isolation of the horizontal section and slotted liner toe with a CIBP is recommended. This can be milled up in the future if deemed worth reaccessing. Increasing shot density in the heel perfs and adding perfs further uphole in the Ivishak and Sag are expected to change the sweep from this well and improve recovery from this pattern. The heel perfs in S-22B are not in the vicinity of the parent well nor original ST and thus have not experienced previous waterflood nor MI sweep. In addition to current clear support to S-01A and S-36, improved support to S-33, S- 35, S-21 and possibly S-38 is expected. Once injection has been established for a few weeks, a borax log needs to be obtained to f`~ confirm injection containment. There is no record of a cement bond log on this well. Previous temperature warmback passes associated with the 8/3/03 IPROF were only logged from 9600' -11925' MD, and while the limited section above perfs did not indicate any cooling, the planned adperfs will be above this depth. Because the Sag perfs will be immediately below the 7" liner at 9452' MD, any log used to confirm contained injection will need to read through 2 strings of pipe. Per input from Schlumberger, the Borax log was the only one they recommended for this particular wells' situation. While no problems are expected, since the 7" liner cement job performed on 6/30/97 went as planned, confirmation for the AOGCC will be needed. The IOR benefit of 165 bopd for this work is based on MI benefits only. This is conservative as there will be waterflood benefits also associated with the conformance modifications. Plans are to put this well on MI shortly after the Borax and IPROF logs are obtained and containment to the Sag and Ivishak are confirmed. For questions or comments please contact: Danielle Ohms Whitne Kin 564-5759 w 564-4840 w 440-9082 c 310-989-7674 c 345-2477 h n/a cc: w/a: Well File 2/10 SL Puli MCX • • 1. RU SL. 2. RIH and drift to 4-1/2" MCX at 2210' MD (2183' SLM). Pull MCX and POOH. Fuilbore SBG: 3. Bullhead SBG treatment from surface. Wellbore volume is ~185 bbls. Aliow treatment to soak for three hours before displacing into perforations. SL Drift, Caliper, set CIBP 4. Drift well as deep as possible for a 4-1/2" CIBP (OD = 3.593"). Well surpasses a 70° deviation at 9748' MD. Note: SL was able to reach 9871' MD on 7/29/03. 5. MU 2-3/4" 40 arm PDS caliper. RIH to deviation. Caliper from as deep as possible to near surface. Note: caliper will be used to determine the condition of liner for the setting of the CIBP. 6. RIH with 4-1/2" Baker CIBP (OD = 3.593) and set CIBP as deep as possible (~9860) using SLB e-fire or Halliburton ETD tool. Minimum restricfion is 3.725" C~ 9263' MD. CIBP should be set at least 30' below the second set of perforations (30' below 9740'). At least 30' of rathole below the bottom most perf is requested for logging later on. Note: SL was able to reach 9871' MD on 7/29/03. 7. RDMO. 8. Put well on injection at target rate of 3000 bwpd. E/L Adperf and Borax/IPROF loq 9. Well should be placed back on injection for a day or two in order to confirm injectivity change (signifying plug is holding) before RU e-line. 10. RU E-line. SI well and freeze protect top 2500' of wellbore (~38 bbls). Ensure well is liquid packed before proceeding with adperf job. 11. Using the reference log SWS/Anadrill MWD logs 6/26/97 - 7/8/97 for tie-in, perforate the following intervals: • 9458' - 9498' (40') • 9584' - 9604' (20') ~ • 9614' - 9634' (20') • 9642' - 9662' (20') • 9700' - 9740' (40) Perforate lower intervals first (a) Use the 3-3/8" Power Jet 3406, HMX, 6 spf, 60 degree phasing, and random orientation. See email (page 7) on perforating with 3-3/8" TCP guns before proceeding with adperf job. Guns must be shot in fluid, not gas. Max swell of 3-3/8" guns in liquid is 3.66". Minimum ID is 3.725" C~ 9263' MD. NOTE: rollers may be needed as section approaches 70°. 12. RDMO and return well to injection at target rate of 3000 bwpd for 2-4 weeks. 3/10 13. RU e-line. MU IPR~gging tooistring: CCUGR-PRESS-T~P-SPINNERS (fullbore and inline) and X-Y C er. RIH. 14. Once toolstring is out of the tubing, ensure well is injecting at 3000 bwpd. When well appears to be on stable injection, make the following logging passes using SWS Anadrill/CDR Impulse Log O6/28/97-07/08/97 for tie in: • Log up and down passes at 40, 80, and 120 fpm from 9400' to 10' above CIBP (~9850) • Take stop counts at: 9400', 9540', 9609', 9638', 9680', and 10' above CIBP (~9850) • SI well and log baseline temperature pass at 40 fpm from 9400' to 10' above CIBP (~9850). • Log warm back temperature passes at 1, 3, and 5 hour intervals at 40 fpm from 9400' to 10' above CIBP (~9850). ~Pass ~'1tr~#iczn ~p~eci: [3~pth ~fi~ IVID) ~~I~te~ , - _ . . ~~.. ~;~~ , ~.~ _ . „ , ~ . _. ~f ~: .~ ~,_~, . ~ < 1_ t -r ..~ ~ ~ x; .~ ~ w~ --_., ~ ,. Flowing Up/Down 40 9400' to 9850'** Well Injecting STP Flowing Up/Down 80 9400' to 9850'** Well Injecting STP Flowing Up/Down 120 9400' to 9850"`" Well Injecting STP Stop Down Stops 9400' Stop Counts Counts 9540' 9609' 9638' 9680' 9850"* Log Baseline Down 40 9250' - 9850'** Well SI Tem Pass Warmback Down 40 9250' - 9850'** Well SI Tem Passes 1,3 and 5 hrs ~ x"9850 is 10' above the CIBP** • ~ jk,~,c,Q~~-~- % ~-r ~..~~ iU~ ~}'v,~t¢ x . ~'~' . 15. ject Borax an log from 9250' to 10' above CIBP (~9850). RIH with GR ess temp/RST tools to as deep as possible. Tie into SWS Anadrill/CDR Impulse Log 06/28/97-07/08/97. Log two baseline passes from as deep as possible to 9250' MD. First pass should be 30 fpm and the second at 60 fpm. 16. Pump 60 bbls of borax as per PE manual, then log from 10' above CIBP (~9850) to 9250' at 60 fpm. Pump second round of borax (60 bbls) then re-log interval at same speed. 17. Put well back on injection to overdisplace borax. 18. POOH. RDMO. 19. Leave well on injection at target rate of 3000 bwpd. Notes for Schlumberger: • Depth shift final log to correlate with 6/26/97 - 7/8/97 SWS/Anadrill MWD logs: CDR/ARC5/Impulse. • Please upload the PLT Client D-List and LAS to InterACT after the log is complete. 4/10 ild-t = VUEi.LFiEACk FhA~faEhl2 AGTti4T{iR= BAKfR KB. ~.EV = 68.34' ~ , ELE~+ _ _ 38.45 K = 61~ut My~ = 99 ~ 11B DetumMD= 953ff D~tvmT.+[~= BS00' SS ( r a~,e- cs~, n~, ~-eo, ~= i z aar ~ 268: Mir~mum 1D = 3.725" ~ 9263' 4-12" HES XI+) NIPPL~ 9,51$'X7'BKRZXPFKRWfTE44l7t.Q~7.5[I' ~J a-~s• x r B~ ~ncu,~t ~R D= a.2s° 5211 9-51g' tS~'i, dTt1. 480. Q= 8.881' ~rlA t.~tr~UE (7'}(~'BKRZ?SPPKRh4~TI~ACK,D=5.25D" 1 ~4-y,~t' lBG, 12 Bi~, i-E~, .015s22 bpt, D= 3.958" bD1. ~ = 8 PB~FORATION SUh41ARY RFJF10~: CDR~`+RRCS~'ltdPlllSE4N4!6f~-07.?{7t3!9~7 ~r~~ aT r+~ s~, a i~ asav 1~7lP_' R#+lPt tn Rfre~i~r}inn flfi fnr haelnrirnl ro'( riat~ S~E ~ lVfEFNAI tlptr'Sq~ DATE 2-718' t 9F}30-9850 O 12t2-019T 2-7:~' 1 9720-9740 4 12f~0;'87 2-7a8' 1 1ipT0-11090 4 13~90797 2-7,~&` t 11i~~D-i1t4p b 12~30~97 ~-~r~r ~ ~ 11ao-~ ~ tsa v 12r~or~r SAFEfY NOTES: W~L ~ 70 DEG ~ 9Y7B AND ~ 9fl DbG S~'~~~ ~IAf~ft~MB~i~4Y9~3r8"MLLpJTWihi1QM-' NON ~ ~ a-i l2' !f5 FIXO BV N, i7 = 3.813' ~ r.a c r~r ean uroa c sr ~~o Tvo a~v v~v rr~ Ln~ai s~ onrE i ~oo s 2~a~ o ~€~ ~ ~~t os~~2~fo ~ s-~~s• ~utaur wr~nr~w: 64~2'- 5d18' {OFF1MliPSTt?C!i) $~' 7' 7{ 4-91~" Bt4i S3 PKI~ E?= 3 875" ~' 4-t~~"HE~XN~D=3Et3' pg' ~_ti1- HES X N~ D= 3:8t3' '18' i- x~.~,7- ~ta s-a ~t, o~ 3.s~~• F vt4[ rL~-A;c nra ~ Mrr, iu= ~.a',s ~ 9263' a-t ~z` HeS ?0'a 1dP. ~1= 3.a~5• 92T5' a_z~~`wI.~G 9283' ~n~ m . i d-1t2' Lt,~t. 12 $tt, L80. 015?, 0152 hpE, [1= ~ 858' f"~ TOPCtF4.tt2" 5tCaTTED L~R. ID = ~.956' a-t2-sEOrr~ u~~;1~s~..a~s~,.oys2 0~ ID = 3.958" v ~ ~ ~ca ~tc ecP ~~ ~ P91b 12219' OATE ~ BY COh111fNT5 DATE REV BY ~dMh'HVTS Ott(~gt~1 QRI~-1pl COIuF'I,ETICN+1 p7;Q2~pt CHACAK Qp(~2ECTqNS 72rU6,~D0 a~~Lii O~hNE#~'iED TO CANVA ~ 12~]ZiUO ~,JL#i REYE~ D3t92.~fiT WC, SEt~TRACK {16Br27.+~1 R4V0 PRUQHDEBAY UNti W~,1.: 5~26 P~261T N3. 97-v1 A H N0: 50-024-2? A 14-02 t629' SNL 8 793' Bkl, 5ec.3s, T12M, FYI3E 6/10 • • Weli: S-22B Date : ........... . ....7/t (09................ Cost Est: $100,000 ......................................... CC or AFE: PBSPDWL22-C ......................................... PERFORATING PROCEDURE Ver72,Rev10/21/Ot API #: 50-029-22119-02 .................................. Prod Engr D. Ohms Office Ph: 564-5759 H2S Level: _ .............................••-- -................................................ . . ••--- Home Ph: .•• .............. 345_2477................. NA - injecto CelUPager: 440-9062 ...... . ........................................... WBL Entries IOR Type Work Desciption ................................................................................................................•-•••.................................................. : 165 :,.,_____..E ;Add/re erf Sa and Ivishak in the heel section of this in'ector ~ ........ ......... P.......~ ...................••••••-••••-•••••••••....................l.....................................: Well Ob-ectives and Pertoratin Notes: To be performed following SL work to Dr'rfUtag, caliper liner and set plug. In the event not all sets of perfs are accessible with EL, those sets wiil canceiled. Attachment: Reference bq with proposed perfs annotated. 5"l100' scale Reference Log Tie in Log Add -1 to +2 feet LOJ: CDFUARCS/Impuls ................... CCL/GR .............................. ~ to the tie-in log to be on .. Date: 6126/97-7J8/97 12/24/1997 depth with the reference log. Company: SWS/AnadriH ................... SWS ................... Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/lperf .... 9,458'... ._ '....9,498'... ... 9,456'.... ' .... 9,496..... .....40..... .....6..... .... random..... ....... .60 de~:....... .. . Sa9.. ...---- Adperf ---•-°- •••- 9,584'... .. '....9,604'... ... 9~582'.... " •••• 9.602.•••• ••-•.20..... s ............. ... random.--.. .. . .........60 deg:....... .. . Z4... ...... .Adperf._..._.._ .____9,614' -.9;634' 9,614: - .9,634' 20... 6 random 60 de~. Z4 Adperf/Reperf ••-- 9,642'... .. '... 9 862'... .. 9_642..... ' 9,662' .................... ••...20 .. ..... ............. . 6. . . ..••••••-•-••...••••••- random . . ............................ 60 de~: .. .......... Z4 ....... Adperf/Reperf •••••9'700•-•. . '....9,740'... ...9,701.'.... ' ....9,741.'.... .....40.... . .. ... 6 . . . .... ....random..... ....... ................... 60de~. .. . ... Z4 . .. Adperf..-•---• Requested Gun Size: 3-3/8' Charge: 3406 PJ, HMX ..................•• ••............................. Is Drawdown Necessary/Desired/Unnecessary During Perforating n/a ...........................••--°........................................ Preferred Amount of DrewdowNSuggestions to Achieve Drawdown n/a . .................... .•--•............................................... Last Tag: 12.218 ft MD on _ 8/2/2003___ Est Res. Pres. @ .__ 9,802 _._. MD is ___ 3400_ psi (approximately) ..... -- -- ------ - Perforation Summary summary Dist Well: S-226 own: °------------° Date: ................... API #: ....... 50-029-22119-02 ..... Prod Engr: ---..............................._......... Anch Prod Engr ' P.D. CeMer PBTD ..................... Ge~eral Comments: ............................................................................................................................................... ---° °°•°-°--.....-° °--•-°° .............................°---• ~-------....-°--.....................-°--........................................--°-............................., Depths Balance Based on Ref Log Gun Dia. Orie~t. SPF Phasing Zone O/B/U - ........................................ ...°--.°°•---... ............... ..........-° -°--.....---......_... ..................... O/B/U - .................... .................... .................... ............... ............. ....................... ...................., O/B/U - .................... .................... .................... ............... ............. ....................... ...................., O/B/U - .................... .................... ..............°-°. ............... ............. ..-.-°-° °----°..... .................... O/B/U - .................... .................... .................... ............... ............. ......°°... °-.-°... ...................., O/B/U - ........................................ ..°--.............. ............... ---°--...... ...........-----....... ...................., O/B/U - --~ ..................................... .................._ ..---.......... .---........- ---._......---°--..... ..................... Adperf/Reperf ......-° •--°--° ................ ............... ................... ............................. . ° ° .......-----° .................... 7/10 • __ ~Mr~~at rnase ne_~s~_~ry .u~ m_n t=nr~'~+n~ _ S-22B 6128197 - 7/8J9~ °`2 --- `°"M~' ~ SWS~Ana~ rill ~MPULSE Ph~sa Shift R~sisinrity 28 mch 2MNz (f~2bN} Q2 (OHMI~A) ~ C DRI AR C5/ I I 1 ~~U ISE: LO{~ ..-. .•~~~LSE Phsse Shktt ResislivHY 2? lnch 2MHz (P22H} . .......... .... .... .......... ... .... ...... . .,.. .,, Q2 ~ (OH-dM) ~ tMPULS6 Gamma Ray FiMered (GR_ FILn 0 ~GAPI) 100, ,_. _ _ . ~.._. ARGS Gamma Rey Fltered (GR_FILT_ daC~ 0 (GAPi) 100 iMPULSE FkslslwNy Tlme ARa~ BH (ARTM) 0 {HFi) 50 Gamms Ray ~GR CDR) 0 (GAPi) 100 Fiato o~nat~~iM~n, Stt l~llared (RQPS~ ~ - ~ ~~~!HR) ~ ~ p --, IAiPULSE Phase 3hHt Reaisliv~ 16 inch 2Mhtz ~P16H~ ~~ Q2 --------~- ~OHt~1M} - ------ -~ INPULSE Pha~e Shldt iiasisllrity 10 inch 2MNz iPtONr a~~ -- --- ------~~Kk~Re} 2~ _ A~iG~ Pt-~4e g~N1 R4s~t~v~~~a -nch 2~~-iz ~F~~1~ -- ~.2 - - - ~ ~ - (OHNIM) 2~ ARCS Pha~e Shift Resistivity 28 inch 2NINz (P28H) 0.2 (OHfAM) 2~ . _- -........ ... AACS.Phase_Sh~ft Resistivil~ 22.inch 2MNz (P22H! • •....... - .0.2. ...... ...... .......-~OHMM)•- .... ...--- -..._. ~ ~ - -- - - --- -- _ _ ~ 4 ~_ ARCS Phase ~ift Resislevity 16 inchi 2Mlli (M81i1 T~ e 0.2 ~~~~~...~- ~OHMM~ i---- - ~2( 8/10 9/10 ~ ~ - - - ~ S-22B 6128l97 - 7/8197 - - - . - - • ; r . '. ~ - SWSlAnadrill 9~oa -= - _ _ _ _ __ _ - -- }j~ + CDRf ARC~J Impulse Log ._ _ _ . ~ , , -- , - - ~ - - ; ~ ~ f ~ i ; • i _ 9700' - 9740' MD - ~' - ' , - - - Z4 ADPERFS - . • - - ~ _- -- --- - - - ~ ~ __ __- -_ _ _ _ - . _ , -- - - - -?- ~ - -- - _ . _. ._ _ --- - - - - . - ~ ____ _ _ _ _ __ - - -- - ~ i -_ __ _ - - - - - - - _ . __ _ , -.. _- - - - .: .t . -- -- - - _ _ . _ -- - , - ~ __ __ . _ _ _ _ _ _ _ ' ' - i ' 1 _ ' J , 1 f .i .. _ _ .. _'_ _."' -" ] _.__ _ '_ _ . - __ - _.. - _ . __ . _ _ . _ - T ' . . -- ~ . _'" ,. .~. - . _ _ .- - . -- ____ ___. - . - ~ ~r ~ ~ . ~f . I i ~` _ .. _ . _. .. _. --- _ __ _ __.. -- ... , 4 i . } ; , - - -.. _ - - - -- --- ' - ~~ - ' ~ ' i . -- -. - - . - - .__ _~ -- -.- - -. - . _ .~ ... -- ~-~ - - - . ~ - ! .~ _ r ~ ' - -' - - _ . _ ~~ - _ ~ i ~ - ' _ y~~ ~ ~ " - - --- - - t i- • _ . _ ~ ~ .. _ _ ~ - -- ~t - - -j - _ ~ . r RUN G ~ - - --~ -- - - - - . ~ r ~ -- - - - - - - --- j -- - - - ' - -- - iMPUISE ~ __ ' } - --_- -- - - __ - - - - ~ ._ - - - ' -- -- ~ j ~ - - - - -_. _ _ _ .. . __ . ~; -; - -- ___ /_ ~ --- -- -- - - - - - - - -- -~ - --- _ - - - - _ . __. ,~ -- -- - - - ; - - • _._ . ; - - _ _ , ,- , - , . ' , ~ __ , € -- - I j - - _ , - __ ~ - 7 - - - _ , . _ ~ i / ,: _ r _ ~ ~ ,, ~ ; -- 99~0 ._ - - i i - -- - .,_ .`- - - - -- - - - -- -- - _- - - - - - - - - - __- 10/10 09/O1/2009 TUE 10:10 FAX 5645016 ~008/013 • • ~ /~ ~ ~~...., ~~ ..~.~.~., ~~..~..~ ~ (' ~ Morning Drilling Report Operator BP Exploration Well S-22B Field Prudhoe Bay Rig Nabors 18E 06:00-19:OQ BHA run no. 10 * NO ACCTDENTS * NO SPZLLS " ** 1374 bays since last LTA ** ** 798 Days since last spiJ.l ** * 2 PTSM * 06:00-08;00 Circulared at 1.2221.0 ft Drilled into a fault at 06:00 hrs losing 3.50 bph, ROP dropped to 8 ft/hr. Well TD'd at i2,221' - Planned TD was 12,271•, Circ hole clean for short trip. H2S Drill @ 08:00 hr - AMAS 2:30 min. 08:00 Obtained clean returns - 200.00 ~ hole volume 08:0fl-09:30 Pulled out of hole to 9A50.0 ft 09:30 At top of check trip interval 09:30-10:30 l2.I.H. to 12221.0 ft 10:30 on bottorn 10:30-12:00 Circulated at 12221.0 ft 12:00 Iiole awept with slug - 20Q.00 ~ hole volume 12:00-12:30 Tield safety meeting Pre Tour Safety & Environmental Meeting. 12:30 Completed operations 12:30-13:00 Circulated at I2221.0 ft Circ 40 bbl high vis sweep, no ahange in returns. Drop 2" driEt. 13:00 HoJ.e swept with slug - 25Q.00 ~ hole volume ].3:~U-15:00 Pulled out of hole to 9400.0 ft Spill Dri11 @ 15:00 hr - AMAS 2;40 rain. 15:00 Stopped : To splice cable 15:OQ-15:30 Serviced Block ].ine Slip and cut 105' o~ drill line. Z5:30 Line slipped and cut 15:30-i8:00 Puiled out of hole to 217.0 ft 28:00 At BHA 1$:00-19:00 Pnlled BTiA ~.9:00 BHA Laid out 19:00- Run Liner 4-1 2in O.D. 19:00-20:00 Rigqed up Tubing hand ing eguipment Rig up tubing e~t. iiold safety meeting, 20:00 8quipment work completed 20:00-23:30 Ran Liner to 2949.0 Et (4-1/2in OD) ~."a,~„`j'~~~~'!~t .;- °. Make up 4.5" Bonzai liner. ""'`'"r 23:30 Stopped : To change handZing equipment 23:30-00:00 Rigged down Tubing handling equipment 00:00 Equipment wor3c completed 00:06-00:30 Held safety meeCing Pre Tour Safety & Environmental Meeting. 00:30 Completed 'operations 00:30-01:00 Circulated at 2949.0 ft - Circ liner volume. 01:00 Broke circulation 01:OQ-04:30 Ran Liner on landin strin to 9452 0 ft 04:30 At in cas ng shoe 04:30-¢5:00 Cir~~2latAd~t 945_2 0 f~E Circ drill pa.pe and liner volvme at shoe. 05:00 Slow ciraulation rates completed 05:00-06:00 Ran Liner on landing string to 12221 0 Et un iner in open o e. 06:00 On bottom Report 17, page 3 Date 0(:p0, 09 Jui 97 ~.' ~~ L;hc ~G~ ~wrs K L Iti ~ -_J ~~~ ~- 3/-~? ~ ~ 2 ~G /c. `~ , ~ ~ 1~~ ~~ .`, ~~.~~ 09/O1/2009 TUE 10:08 FAX 5645016 ~004/013 • • ~"~ ~ ~ T,D Sl Morning Driliing Repor# ,~...._~~._~_.~ Operator BP Explorarion Wetl S-22B Rield Prudhoe Bay Rig Nabors 1$E Report 18, page 3 Date 06:00, 10 JuI 97 06:00-07:30 Run Liner, 4-1/2in O.D. * I30 ACCIDEN2S * NO SPILLS * ** 1375 Days since last LTA ** ** 799 Days Since last spi11 ** * 2 PTSM * 06:00-07:30 Circulated at 11924.0 £t Circulate landing stYing and ].aner. f2U cement head. 07:30 Hole displaced with Seawater - 150.00 8 displaced 07:30-13:00 Cement : Liner cement 07:30-10:30 Circulated at 11924.0 ft Drop first plua and t~umA down Plua did not se~. Spill Drill held at 08:00 hzs - 2:30 response time. 10:30 Other sub-surface equipment failed - Change opera~ion 10:30-11:30 xe],d safety meeting Suspended a11 rig operations and held SSD Safety Focus Standdown meeting with all on tour personnel. Reviewed latest series of incidents. 11:30 Completed operations 1].:30-12:00 Rigged down High pressuxe lines RD cementing lines and plug head. 12:40 Stopped : To hold safety meeCing 12:00-12:30 Iield safety meeting Hold pre tour PJSM and environmental meeting. 12:30 Completed operations 12:30-13:00 Rigged down High pressure lines Continue rig_aing down lines and head. Check head for plugs, fi.xst plug gone, 13:00 Work aompleted, equipment lazd out 13:00-15:30 Siickline wixeline work 13:00-13:30 Rigged up S1ickline unit 13:30 Work campleted - Slickline unit in position 13:30-15:00 Conducted slickline oberations on Slickline ewibment - Tool r~n RIH w/ slickline and locate plug in 3-1/2" x 5' XO. u ree. 15:00 Compieted r~sn with Toolstring from 0.0 ft to 23Q0.0 ft 15:00~25:30 Rigged down Slickline unit 15:30 Work completed, equipment laid out 15:30-01:00 Cement : Liner cement 15:30-16:00 Circulated at 1.1924.0 ft Pump plug down and land in landing coilar. 16:00 Stopped : At su -assembly 16:00-17:00 Rigged up High pressure lines RU plug head and cementing lines. 17:OQ Wozk completed - High pressure lines in position 17:40-17:30 Held saEety meeting PJSM-Held meeting with BJ, Halliburton, Baker, and rig personziel conCerning cementing job. 17:30 Completed operations 17:30-18:45 Cleared Chicksan lines BJ peunped through sur£ace lines filliag same. 18:45 EquiBment work completed 18:45-18:50 Tested High pressure lines Tested cement_ ].i.neG_ 18:50 18:50-19:15 19:15 19:15-J.9;50 ssure test completed successfu7.ly - 4200.000 psi cti.oned Downhole equipment Pressured up to 1204 psi and set liner hanger. Slack o£f weight and verify that hanger set. Inczeased pressure to 2200 psi and inflaCed ECP. Inczeased pressure to 2700 psi and openned Hallibux~on ES Cementer. Batch mixed slurry - 52.004 bbl 09/O1/2009 TUE 10:08 FAX 5645016 ~005/013 ~ ~'~ , o~) . C ~~? Morning Drilling Report Operator BP Exploration Field Pradhoe Bay Wcll S-22B Rig Nabors 18E Report I8, page 4 Date 06:00,10 Ju197 Circulated we11 while batch mixing cement. ~ ].9:50 Batch slurry mixed 19:50-20:i0 Pumped water spacers - volume 70.000 bbl Pumped 20 bbls water spacer. Pumped 50 bbls MCS-4 spacer at 10 ppg. 20:1Q Required volume of spacer pumped 20:10-20:30 Mixed and pumped slurry - 62.000 bbl Pumped 62 bbls (295 sx) Class G cement and additives per plan at 15.7 ppg. 20:30 Re ease Dart 20:30-21:Q0 Displaced slurry - 129.000 bbl DispJ,aced cement with 224 bbls o£ seawater. Saw dart latch plug after 84 bbis seawater pumped. Bumped plug. ressure up to 2400 psi and hold same. 21:00 Plug bumped 21:00-21:15 Functioned Mechanical packer Released £rom liner hanger and mechanicallv set__ ap cker• 21:25 Equipment Wozk comgleted 21:15-22:36 Reverse circulated at 11924.0 £t Reversed ciYCUlated - saw trace oE cement back. 22:3d Obtained cZean returna - 150.00 ~ hole volume 22:30-00:00 Held safety meeting Held SSD Safety Focus Standdown meeting with all on tour personnel. Reviewed latest series of incidents. 00:00 Completed operations " 00:00-00:30 Held saEety meeting HoJ.d pre tour PJSM and environraental meeting. 00:30 Completed operations a0:30-01:00 Circulated at 1192A.0 ft Circulated aC 7.'7 bpm 01:00 Hole displaced with Seawater - 100.00 ~ displaced '"' 01:00-04:00 Run Liner, 4-1/2in O.A. 01:00-04:00 Pulled Drillpipe in stands to 0.0 £t POOH with ].iner running tool - chained out. Lay dovm. running tool. 44:00 At Surface : 0.0 ft 04:00- BHA run no. 11 04:00- Made up BHA no. 11 P/U and strag 2-7/8" tools. P/U BHA ~.ic~' ° '.JY~9 Yrrs~' ~) J \~ /~~M~ Z ° ~ i~,{ n n'~' : r,x:j. S O ~•~1 y`p @ ~ 1 ~ C~~' ~ C !~Jbra~+rity ^' "{'c.~~~.~ r~ tn~ ~o ~~ ~ y,~; ~~F 3% x 5" X U, ~r r~qn~-J=- '~ll,~ G~'~ o l`~~~a~~.c~ E[I" ~ u~PQH~t.~ C~ CQ ~~a~, ~~ ~ T~,.' . (3~.,~-~.~, <,.,-~. G'2 l;~c. a {a~,,.r.~~.:5 t,~,,. • ~. .+~,,e~l, s e!- L. ~ tic.~ p<,<.l..c.-, . R.eve/£o~;y~ ~7~~J/~ ta~ l.r~.~~.. ~r'Yae,~ C.ke~. ~ (~ U 2~/g Ta~>?s, 09/O1/2009 TUE 10:13 FAx 5645016 ~012/013 ~ ~ ~ ' Morning Driiling Report ~. ,~., _ Operator BP Exploration Weil S-22B Field Prudhoe Bay Rig Nabors 18E 06:00-16:00 06:00-10:30 10:30 10:30-11:00 ii:oo 11:00-12:00 12:04 12:00-12:30 ~.a:sa 12:30-14:3Q 14:30 24:30-16:00 16:00 16:00-17:30 16:00-16:30 16:30 16:30-17:00 17:00 17:00-17:30 1') : 3 0 17:30-19:00 17:30-18:00 18:00 18:00--19:00 19:06 19:00-01:00 19:00-00:04 00:00 00:00-00:30 00:30 00:30-01:00 Run Liner, 7in 0 A * NO ACCIDENTS * NO SPILLS * ** 1365 Aays since last LTA ** "* 789 Days since Zast spill ** * 2 PTSM * Ran Liner to 9452.0 ~t (7in OD) Ran total 109 jts 7• 26# L80 Mod Butt. Spill Drill @ 08:00 hr - AMAS 2:25 min, Stopped : mo change handling equipment Ran Drillpipe in stands to 5402.0 £t At window : 5402.0 ft Circulated at 5A02.Q ft Circ drill pipe / liner volume at window. Broke cz.rculation T~eJ.d safety meeting PTSM - iiigh pressure testing. Completed operations Ran Drillpipe in sCands to 9440.0 ft RIH with liner breaking circ every 10 stands. Observed 20.00 kib resistance Circulated at 9~152.0 ft ltamp up circ rate to 10 bph while reciprocating liner. Washed and worked shoe from 9440' to.bottom at 9452'. 142 spm(10 bpm) (3 1140 psi. Obtained bottoms up (100~ annulus volume) Ceraent : Liner cement Mixed and pumped slurry - 169.000 bbi Pump 5 bl Ii20, test lines to 4500 psi, 1S bbl H2O. Pump 50 bbl MCS-4 11.0# spacer, 130 bb1 G 11.0# lead, 39 bbl G 15.8# tail. Drop dart with 5 bbl H2O. Cement pumped Displaced slurry - 252.000 bbl Displace cement with rig pump at 10 bpm. Visual pressure spike when dart latched ~lua did not bump plug. Report 8, page 3 Date 06:00, 30 J'un 97 ~ / / ~, C~~. ~t.•--~~ ~_~ ~ ~~ ~ ~ Strsng sp ace with Water based mud - 100.00 ~ displaced Functioned Liner hanger Slack oft string, hanger set with 36,000 lbs down weight. Released running tool, pick up exposing setting dogs. Mechanicaliy set packex with 4U,000 lbs dovm weight. Equipment worlc Completed Fluid system Reverse circulated at 5204.0 ft Rev carc out s conCaminated cement and spacer. 80 spmt5.6 bpm? Q 560 psi. String displaced wiCh Water based mud - 100,00 $ disp].aced Circulated at 5204.0 ft Circ boCtom up - 90 spm(6.3 bpm) 0 J.000 psi. Obtai.ned bottoms up (lOQ~ annulus volume) 5in. briilpipe workstring run Pu11ed~Arillpipe in stands to 0.0 £t POOH - Lay down drill pipe as needed. Lay down liner running tool. Pire Drill 4 21:00 hr - AMAS 2:15 rain. Stopped : To hold saPety meeting , Held safety meeting Pre Tour Safety & Environmental Meeting. Completed operations Laid down 1953.4 ft of 5in OD drill nibe 09/O1J2009 TUE 10:13 FAX 5645016 ~013/013 ~ ~ ~ ' Morning Drilling Report Operator BP L~xploration Weli S-22B Report 8, page 4 F~eld Prudhoe Bay Itig Nabors 18B Date 06:00, 30 Jun 97 Continue laying down dri21 pipe. 01:60 63 joints laid out 01:00-02:00 Nipple up Top ram 01:00-02:00 Installed SOP stack - Pull wear rzng, install te5t plug. Change top ram from 7" to 5•. 02:00 Equipment work comple~ed 02:00-03:34 Test we11 coatrol equipment 02:00-03:30 Tested BOP stack Test BOPE to 250 psi low, 5000 psi high. Annular to 25Q psi Iow, 3500 psi high. witnessed by Chuck Shieve with AOGCC. 03:30 Pressure test completed successfully - 5000.000 psi 03:30-04:00 wellhead work 03:30-04:00 Installed Bore protector Pull test plug, install wear ring. 04:00 Equipment woxk completed 0~1:00- BHA run no. 4 04:00-05:00 Made ug BHA no. 4 Make up 6" FAS+ end rotary assy to clean out liner. 05:00 BHA no. 4 made up 05:00-06:00 Singled in drill pipe to 963.0 Et " Pick up 3 1/2" drill pipe. i BP Exploration (Alaska) Inc. Attn: Weil Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, C~ bp =~ ~ ~ JuL o ~ zoo~ Enclosed please find a spreadsheet with a list of wells from S-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, 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, .,~~r~a~C~~:~ ,i'u~. ~, ~' ~~~ i Torin Roschinger BPXA, Well Integrity Coordinator ~ • BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad Date 6/25/2009 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top otf date Corrosion inhibitor Corcosion inhibitod sealant date ft bb~s ft na al S-O7B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1947090 025 NA 025 NA 1.7 5/25/2009 5-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 7951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 7920980 0 NA 0 NA 0.9 5/26/2009 S-088 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31 /2009 S-11B 1990530 0.25 NA 025 NA 1.7 5/27I2009 S-12A 7851930 0.25 NA 025 NA 1.7 6/1@009 5-13 1821350 8 NA 6 NA 55.3 6/1I2009 5-75 1840170 025 NA 0.25 NA 3 6/2/2009 S-77C 2020070 025 NA 025 NA 2.6 6/1/2009 S-ieA 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 7970.510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 0.25 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 7960120 0 NA 0 NA 0.85 5/27/2009 S-30 1900660 0.5 NA 0.5 NA 5.t 5/31/2009 S-31A 7982200 0.5 NA 0.5 NA 3.a 5/26/'L009 S32 1907490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 S36 1921160 0.75 NA 0.75 NA a25 5/27/2009 5-37 1920990 1.25 NA 125 NA 77.s 5/27/2009 5-38 1927270 025 NA 0.25 NA 702 5/27/2009 S-47 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-700 2000780 2 NA 2 NA 213 5/29/2009 S-101 2001150 125 NA 125 NA 11.9 5/29/2009 5-702L1 2031560 125 NA 125 NA 11.7 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 16.25 NA 1625 NA 174.3 &2/2009 S-7o7 2011130 225 NA 225 NA 28.9 5/18/2009 S-ioa 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 17.75 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-itaA 2021980 1.25 NA 125 NA 702 5/30I2009 S-t~5 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 73.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 5-119 2041620 1 ~ NA 1 NA 52 5/30/2009 S-120 2037980 5.5 NA 5.5 NA 672 5/29/2009 S-127 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 5-125 2070830 225 NA 225 NA 20.a 5/28/2009 5-726 20710970 125 NA 1.25 NA 15.3 6/t/2009 5-200 - 1972390 125 NA 725 NA 14.5 5/28/2009 S-201 2001840 0 NA 0 NA 0.85 6/19l2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2007970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 5-401 2060780 16 NA i6 NA s9.5 6/2/2009 S-50a 0 NA 0 NA O.aS 5/28l2009 MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Reri II \~i6 DATE: Tuesday, October 11, 2005 SUBJECT: Mechanical Integrity Tests 8P EXPLORATION (ALASKA) INC S-228 PRUDHOE 8A Y UNIT S-228 Src: Inspector ûs\ \C\/'( FROM: John Spaulding Petroleum Inspector Well Name: PRUDHOE BAY UNIT S-22B Insp Num: miUS051010105835 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22119-02-00 Permit Number: 197-051-0 Reviewed By: -<'-'0 P.I. Suprv ..J Jjk::.- Comm Inspector Name: John Spaulding Inspection Date: 10/8/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-228 IType Ioj. TVD 8549 IA 240 4000 3950 __ 394~..+_ P.T. 1970510 I TypeTest SPT Test psi 2137.25 OA 350 420 420 420 I Interval INITAL P/F P Tubing I 600 600 600 600 --L Notes 6.0 BBLS MEOH $CANNEr NOV 1 '1 2005 Tuesday, October 11, 2005 Page 1 of 1 10/10/2005 1 :06 PM 1 of 1 Content-Description: MIT PBU Y-10 10-07-05 (4).xls MIT PBU Y-10 10-07-05 (4).xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Jim Regg AOGCC Please schedule MITs and provide at least 24 hrs advance notice for inspector witness. I'd appreciate confirmation of your scheduling by next Monday, 10/10/2005. PBU S-22B (PTD 1970510) - last MIT 8/15/2001 PBU Y-10A (PTD 2042500) - initiated injection 6/2005; no record of MIT being performed The Commission's records show MITs are due on the following wells: SCANNED NO" 1 7 2005 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Wednesday, October 05, 2005 4: 18-'-'-PM -...--.--....- To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: MITs Due Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Work: 1-907-659-5525 Pager: 1-907-659-5100 x1923 Email: E..qÞ..~:.~:.~:...:...~~~:.~S:..};..~.~.~ì.~~.P...~...~..?~ Please call with any questions. Well Y-10A is a PWI currently operating under Variance #300-103 (04/20/00)and an internal waiver. Most recent compliance testing was a passing CMIT-TxIA to 4000 psi on 09/03/05. Attached, please find the MIT test form for this test. Well S-228 (PTD 1970510)passed an AOGCC witnessed MITIA 10/08/05 with AOGCC representative John Spaulding. I will send the MIT form tomorrow. Jim, ~ ...... ........ ..... ". .... ............ .... ..... ..' .. .... .. ............ttÞ.~7.··0~ Su~J~ct:~E:M~~~'~Üe<. ..<.................... ........ ..... ..... ............ ................ .'< ...... ........./«<><><·'¡<i' Däte:8un09()ct200521:18:3.8..0800 ." " .... . '.' ..... ','. '. ..;.... '...... ........ ". ... ... . .. <. . ..... ... .....<... <.......... < .'.< . . <", ." ) ) RE: MITs Due MITs Due e e 'í7 ID\?\OS' ~f1 Subject: MITs Due From: James Regg <jimJegg@admin.state.ak.us> Date: Wed, 05 Oct 2005 16:18:00 -0800 To: "NSU, ADWWeJl lrit~grity Ent:Vneer";<NSUADWWcnintcgrityEngincer@BP.eom> cc: Winton G Aubért::::Winton_aubert@admiI1.Statc.ak.us> The Commission's records show MITs are due on the following wells: PBU S-22B (PTÐ 1970510J - last MIT 8/15/2001 PBU Y-10A (PTD 2042500) - initiated injection 6/2005; no record of MIT being performed Please schedule MITs and provide at least 24 hrs advance notice for inspector witness. I'd appreciate confirmation of your scheduling by next Monday, 10/10/2005. Jim Regg AOGCC ~(;A\~WJE[ c ~ 2005 1 of 1 10/5/20054:18 PM WELL LOG TRANSMITTAL II, ProActive Diagnostic Services, Inc. To~ State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Printls) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of 'this transmittal letter to the attention of' doey Burton / deni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska], Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM COLOR Open Hole 1 I I S~22b 8-3-03 Res. Eval. CH 1._/ I 1 Mech. CH 1 Caliper Survey Signed ' Print Name: ProActive Diagnostic Services, Inc., Po Box 1369 Stafford TX 77477 Phone: (281) 565-9085 Fax: (281) 565-1369 E-mail: pds~memorylog.com Website: www. memorylog, com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 65' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UM S-22Bi At top of productive interval 9. Permit Number / Approval N(~. 197-051 626' NSL, 411' EWL, SEC. 26, T12N, R12E, UM 10. APl Number At effective depth 50- 029-22119-02 1065' NSL, 2118' WEL, SEC. 27, T12N, R12E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 1065' NSL, 2120' WEL, SEC. 27, T12N, R12E, UM Pool 12. Present well condition summary Total depth: measured 12221 feet Plugs (measured) true vertical 8819 feet Effective depth: measured 12219 feet Junk (measured) true vertical 8819 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 250 cu ft AS (Approx.) 110' 110' Surface 2655' 13-3/8" 3723 cu ft AS III & II 2685' 2685' Intermediate 9696' 9-5/8" 2020 cu ft Class 'G' 5402' 5167' Production Liner 4248' 7" 948 cu fl Class 'G' 5204' - 9452' 5006' - 8795' Liner 2934' 4-1/2" 348 cu ft Class 'G' 9273' - 12221' 8630' - 8819' Perforation depth: measured 9630'-9650', 9720'-9740', 11070'-11090', 11120'-11140', 11170'- Slotted Section: 11927' - 12219' true vertical 8947'- 8961', 8999'- 9007', 8935'-8933', 8929'-8926', 8921'- 8918' ~,IUL 2 7 ~00'l Slotted Section: 8825'- 8819' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 9208'; 4-1/2", 12.6#, L~80 at 92'~ska 0il & Gas COns. CorrllTliSS[Or Anchorage Packers and SSSV (type and measured depth) HES 'HXO' SVLN at 2210'; Baker 'ZXP' packer at 5204'; 4-1/2' Baker 'S-3' packer at 9184'; Baker 'S-3' packer at 9273'; Baker 'ZXP' Liner Top packer at 9273'; Baker 'CTC' Payzone packer at 11889' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water & Gas Injector [] Daily Report of Well Operations 1'~. I here~y certify th~:qt t~e f°,r~g0ing i;~o'rr;gct to th'e best of my knowledge Signed Terrie Hubble -~.~, Title Technical Assistant Date I ' ~.~ ~ ~ ~ ! ~ I fiPrcparedByName/Nurnber: SondraStewrnan, 564-4750 Form 10-404 Rev. 06/15/88 i i ~'~ [ ['3 i i~I /'~, Submit In Duplicate Page 1 of 2 Well Service Report Well bob Scope IIJob Number S-22B IIDRILL-PREP WORK 'Date IIDaily Work 06/24/200111DRILL-PREP WORK' CHEMICAL CUT TUBING 111207001504.5 Ilunit Number IIsws 2158 Day iiComplete o II True II F~,$~ II sws-D~O~ZK II JACKSON Field IIAFC# Ilcc# IIDaily Cost I Accum Cost IlSigned I ? 4P9059 RWO 9335- 8975 42393 ~ XXX-XXX Init Tbg Final Tbg IlInit Inner IIFinal Inner IITnit Outer IFinal Outer Press Press IIAn n llAn n IIAn n lAn n o II o I! o 11 o II o II o Daily CHEM CUT 4-1/2" TUBING AT 9203' BELOW COLLAR ABOVE X Summary NIPPLE AT 9211'. RIH TO PBTD @ 9255', LOGGED TIE IN PASS OVER JEWELRY & GLMS, POSITION & CUT TUBE @ 9203', POOH, RDMO,LEFT WELL SI, NOTIFIED CO. MAN & DSO OF DEPARTURE. Time IILog Entry 13:50 ARRIVE LOCATION SWS UNIT 2158 ENG. DROPIK/ HOLD SAFETY MTG, DISCUSS RIG UP AND WORKING AROUND THE RIG. .I. i4'15 IIPOSITION UNIT ON RIG MATS I ~s'oo IlmG uP I5:50 SAFETY MTG, DISCUSS CHEM. cu-n-ER SOP, EXPLOSIVES, ]OB @ HAND. I17'00 IIHOOK UP TOOL STRING, MAKE UP TO WIRE AND ARM CU~-FER. I Iz7.30 IISTAB ON TREE, PT LUBE TO S00~ LP THEN 3000~ HP, GOOD TEST. I I19.3o IILOGGED TIE IN PASS I 20:20 LOGGED INTO POSITION & CUT @ 9203', GOOD SHOT INDICATION, POOH 21'45 IIOOH, DISARM CUI-FER, RD, CLEAN UP. 23:00 LEAVE LOCATION, NOTIFY DSO AND DOYON CO/MAN OF STATUS, LEFT WELL SI. http://a~ps~a~aska.b~web.bp.c~m/sst-dri~~ing-we~~s/.../we~~event-awgs.asp?~D=S226242~~ 100590 7/27/2001 Page lof2 ....... L maryReport Legal Well Name: S-22 Common Well Name: S-22B Spud Date: 6/22/2001 Event Name: REENTER+COMPLETE Start: 6/22/2001 End: 6/27/2001 iContractor Name: DOYON Rig ReleaSe: 6/27/2001 Rig Name: DOYON 14 Rig Number: Hours Activi~ Code NPT l~Phase:l~ of ., ........... ~'-~J .............. , ....... ~J~::~!~ ~7~:. ~ Description Operations 6/23/2001 15:30 - 00:00 8.50 WHSUR DECOMP Standby. Wait on tubing cutting operation. Rig in position to move over well. 6/24/2001 00:00 - 02:30 2.50 RIGU DECOMP Move and spot and shim rig over S-22Bi 02:30 - 03:30 1.00 RIGU DECOMP Cantilever floor 03:30 - 04:00 0.50 PULL DECOMP Re~ive workover fluid and RU floor 04:00 - 05:00 1.00 PULL DECOMP PU lubricator. Pull BPV. LD lubricator 05:00 - 10:00 5.00 PULL DECOMP RU to circ. Prespud mtg. Circ 60 bbls dn annulus to circ out freeze protection fluid out of tbg. Circ dn tbg to remove freeze arotection fluid from annulus. Li~le diesel recover. Pmp at 6 bpm and 700 psi. 10:00 - 11:00 1.00 PULL DECOMP Set ~C and test below to 1000 psi. 11:00 - 12:00 1.00 PULL DECOMP ND tree and adapter. 12:00- 16:00 4.00 PULL DECOMP NU BOPE 16:00 - 22:30 6.50 PULL DECOMP Test BOPE, choke manifold, inside BOPs, & kelly valves at 250 psi and 4000 psi. (Annular BOP to 3500 psi). Witnessing waived by AOCGG rep, Chuck Sheave. 22:30 - 00:00 1.50 PULL DECOMP Slip and cut drilling line. 6/25/2001 00:00 - 01:30 1.50 PULL DECOMP PSJM. RU lubricator e~ension and ~C lubricator. Pull ~C. RD same. 01:30 - 02:30 1.00 PULL DECOMP BOLDS. Pickup and work tubing hanger. Pulled free. Pulled up to 175K and pulled tubing free (25K over string weight). 02:30 - 03:30 1.00 PULL DECOMP Circ BU. Pump at 7.5 bpm at 400 psi. RU control line retrieval equipment. 03:30 - 04:30 1.00 PULL DECOMP Lay down landing joint and hanger. Watch fluid levels in well. OK. 04:30 - 07:00 2.50 PULL DECOMP Pull and lay down 4.5", 12.6~, L-80, mod BTC tubing. Retrieve old control line to SSSV. Recover all 57 ss bands. 07:00 - 08:00 1.00 PULL DECOMP RD control line retreival equipment. Clear floor. 08:00 - 14:30 6.50 PULL DECOMP LD total of 216 jts 4.5" tbg, SSSV mandrel, 6-GLMs, & 1 shoA cut joint (1.75'). NORM check indicated radiation nil. 14:30 - 15:30 1.00 PULL DECOMP PT casing to 4000 psi for 30 min. 15:30 - 16:00 0.50 PULL DECOMP Test lower pipe rams (250 psi & 4000 psi). Unable to test during last BOPE test because tubing hanger EN intefferred with ram closing. 16:00 - 16:30 0.50 PULL DECOMP Install wear bushing. 16:30 - 17:30 1.00 PULL DECOMP RD tubing tools and clear floor. 17:30 - 18:30 1.00 PULL DECOMP RU slick line to run GR & JB. 18:30 - 21:00 2.50 PULL DECOMP Run Hallibudon WLS 8.5" gauge ring and junk basket to top of 7" liner at 5204" (5215' wlm). JB clean. 21:00-22:30 1.50 PULL DECOMP Run 6" GR & JB to top of $.5" tubing stub at 9203' (9214' wlm). JB clean. 22:30 - 23:00 0.50 PULL DECOMP RD wireline and pull wear bushing 23:00 - 23:30 0.50 PULL DECOMP RU to run 4.5", 12.6 ~, NSCT, L-80 completion tubing. 23:30 - 00:00 0.50 PULL DECOMP PU and RIH with completion tubing. Pick up and run Unique overshot, "X" nipple, subs, and S-3 packer assembly on tubing. 6/26/2001 00:00 - 07:30 7.50 RUNCO~ COMP PJSM. Run 4.5" completion tubing. 07:30 - 09:00 1.50 RUNCO~ COMP Rig up SSSV control line running equipment. Hook up lines and test to 5000 psi for 10 min. 09:00 - 13:00 4.00 RUNCO~ COMP Continue running 4.5" completion tubing with control lines. 13:00 - 15:00 2.00 RUNCO~ COMP Space out. Pick up 5.88' tubing pup. 15:00 - 17:30 2.50 RUNCO~4 COMP Reverse circulate 238 bbls of inhibited seawater and displace with 117 bbls of clean seawater. Printed: 7/2/2001 11:28:16 AM - BP ~PEORATION Page 2 of 2 :_ marY:Report - _ Legal Well Name: 8-22 Common Well Name: $-22B Spud Date: 6/22/2001 Event Name: REENTER+COMPLETE Start: 6/22/2001 End: 6/27/2001 Contractor Name: DOYON Rig Release: 6/27/2001 Rig Name: DOYON 14 Rig Number: ~ours Activity Cod~NPT~:iPhasei: Description of Operations 6/26/2001 17:30 - 18:30 1.00 RUNCOI~q COMP Pick up and install hanger. Hook up control lines and test to 5000 psi for 10 min. 18:30 - 19:00 0.50 RUNCOI~ COMP Land tubing. Overshot muleshoe at 9211' (tubing tally meas.)(3.5' "swallow" on tubing cut stub). PU: 165K; SO: 139K. 19:00 - 20:00 1.00 RUNCOA~ COMP Rig up HallibuAon Wireline. Use lubricator. 20:00 - 21:00 1.00 RUNCOA1 COMP RIH and pull dummy valve from SSSV mandrel (2211' WLM). 21:00 - 22:30 1.50 RUNCOA1 COMP Run 3.77" tubing drift on wireline and tag PBD at 9259' WLM ( below tubing cut). 22:30 - 23:30 1.00 RUNCOAI COMP Run "~" plug to land in new completion "X" nipple at 9197'. Could not get past SSSV mandrel at 2211' POH. 23:30 - 00:00 0.50 RUNCO~ COMP Redress OD of packing on "~" plug. 6/27/2001 00:00 - 03:30 3.50 RUNCO~ DFAL COMP Rin with "~" plug to "X" nipple at 9197. Would not set. POH and repin. 03:30 - 06:00 2.50 RUNCO~ P COMP Run "~" plug and set in "X" nipple at 9197'. 06:00 - 07:30 1.50 RUNCO~ COMP Run SSSV dummy valve and set in mandrel at 2210'.. POH & RD wireline. 07:30 - 10:00 2.50 RUNCO~ COMP PJSM. Set pkr & test tbg to 4000 psi for 30 min. OK. Bled tbg to 1500 psi and press annulus to 4000 psi for 30 min. OK 10:00 - 12:00 2.00 RUNCO~ DPRB COMP Rig down test equipment. Could not confirm packer setting due to downhole configuration requiring additional wireline work. Remobilize wireline. 12:00 - 13:00 1.00 RUNCO~ COMP Rig up wireline to run equalizing prong in "~" plug to allow definitive packer setting test. 13:00 - 15:00 2.00 RUNCO~ COMP Run in with equalizing prong on slickline and open "~" plug at 9197', 15:00 - 15:30 0.50 RUNCOA~ COMP Press. tbg to 1500 psi. PT annulus to 4000 psi for 30 min. OK. Bleed down tbg and shear RP valve in GLM at 2991'. 15:30 - 16:00 0.50 RUNCOAP COMP Install ~C in tbg hanger. PT to 2500 psi. 16:00- 18:00 2.00 RUNCO~P COMP ND BOP. : 18:00 - 19:30 1.50 RUNCO~ P COMP NU tree. 19:30 - 20:00 0.50: RUNCO~ P COMP PT adapter flange and tree to 5000 psi for 10 min. OK. 20:00 - 20:30 0.50 RUNCO~ P COMP RU DSM Pull ~C w/Lubricator 20:30 - 22:00 1.50 RUNCO~ P COMP PJSM. RU Hot Oil Se~. PT lines to 3500 psi. Pump 151 bbls diesel down annulus to freeze protect. 22:00 - 23:30 1.50 RUNCO~ COMP Hook up annulus to tubing and "U" tube diesel into tubing to freeze protect. 23:30 - 00:00 0.50 RUNCOI ~ COMP Run BPV in tree and secure well. RREL at 2400 hrs 612712001. Printed: 7/2/2001 11:28:16 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~'¥'.v~_~' DATE: August 15, 2001 Commissioner ~ \~. SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder~~~'~,O BPX P.I. Supervisor ~_,,,,~,.p~~ ~ PBU S Pad S-22B FROM: John Crisp Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Dep~ Pretest Initial 15 Min. 30 Min. , ., w.~,I s-22B i Typ~ Inj. I '" I TT'V-0' I S3~2 ! Tubing i' r~ '! 22oo I '2~ I 2~0' I,.t~.va~! ' P.T.D.i 1970510 ITypet~l 'g-' IT~P~! 22OO i c,.~ngl250 '1 ,500 I. 500 I' 5q0,, I. P~F I P Notes: This well recenti~ had tubing patch installed.,. First_ MIT after .repair:. .... ~,~qi~'"e'~- I I ~.v.o. I I ~u~.~ I ! i i I'~'i P-T-D:I,, ~ ITYPet,,estlITes~',PS, i,I , I,c~ngl I I' I '1 P/F I ._ Well P.T.D. Notes: Well P.T.D. P.T.D. Notes: 'l~pe'n~'l .... i ~.V.~. I ' ' iTu~ng'l' ! .... !~ '1 I'~nt~a'l" IT~.t~l ' , IT..est'P~i.1, .cas~,l I I . I , I I Type ,nj. I 1 ~.v.'o. i I Tubing I i ' I ' ' I ..... T.~'pet~l,"' IT.est..I' I Casingl , I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's PBU to witness the initial MIT on well S-22B. Problems w/the test pump delayed completion of the MIT. Good test. No problems witnessed. M.I.T.'s performed: Attachments: Number of Failures: 0 Total Time dudng tests: 3hm. cc: MIT report form 5/12/00 L.G. MIT PBU S Pad 8-15-01jc. xls 8/17/01 Re: S-22B Status (PTD 197-051) Subject: Re: S-22B Status (PTD 197-051) Date: Mon, 18 Dec 2000 14:03:34-0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "GPB, Well Integrity Engineer" <GPBWelllntegrityEngineer@BP.com> Thanks much for the information, Joe/Kevin. It will be nice to have the well repaired. Tom "GPB, Well Integrity Engineer" wrote: Hello Tom. This is a summary of well S-22B (PTD 197-051) status. It is a pre-produced injector SI due to holes in the tubing. VVhen production was stopped and the well converted to injection, a pre-injection MITIA failed. The well was never placed on injection. Below is a listing of recent events: > 11/28/99: Memory LDL found holes at 6300', 7175' and GLM# 2 (8620') > 02/24/00: CMIT-TxlA passed to 3000 psi > 12/14/00: SL set TTP The well is scheduled for a rig workover to replace the tubing. Please call if you have any questions Joe Joe Anders, P.E. / Kevin Yeager Well Integrity Engineer BP Exploration Alaska, Inc. (907) 659-5102 email: G PB WelllntegrityEngineer@bp. com Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 12/18/00 2:03 PM STATE OF ALASKA -- ALASK JL AND GAS CONSERVATION COM, APPLICATION FOR :SUNDRY' APPROVAL SION 1. Type of Request: r-i Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Puli Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface v' ~ ,,./ 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UM At top of productive interval 626' NSL, 411' EWL, SEC. 26, T12N, R12E, UM At effective depth 1065' NSL, 2118' WEL, SEC. 27, T12N, R12E, UM At total depth 1065' NSL, 2120' WEL, SEC. 27, T12N, R12E, UM 12. Casing 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED DEC 07 2000 Present well condition summary ,",.,',or.~ u. e~ ~o ,.,,~,,o. ,..,.,......oo.~ Anchorage Total depth: measured 12221 feet Plugs (measured) true vertical 8819 feet Effective depth: measured 12219 feet Junk (measured) true vertical 8819 feet Length Size Cemented Structural Conductor 110' 20" 250 cu ft AS (Approx.) Surface 2655' 13-3/8" 3723 cu ft AS III & II Intermediate 9696' 9-5/8" 2020 cuft Class 'G' Production Liner 4248' 7" 948 cu ft Class 'G' Liner 2934' 4-1/2" 348 cuft Class 'G' 6. Datum Elevation (DF or KB) KBE = 65' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-22Bi 9. Permit Nu.m/ber 197-051 v 10. APl Number 50- 029-22119-02 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool MD TVD 110' 110' 2685' 2685' 5402' 5167' 5204'-9452' 5006'-8795' 9273'-12221' 8630'-8819' Perforation depth: measured 9630'-9650', 9720'-9740', 11070'- 11090', 11120'- 11140', 11170'- 11190' Slotted Section: 11927' - 12219' true vertical 8947' - 8961', 8999' - 9007', 8935' - 8933', 8929' - 8926', 8921' - 8918' Slotted Section: 8825' - 8819' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 at 9275' Packers and SSSV (type and measured depth) HES 'HXO' SVLN at 2214'; Baker 'ZXP' packer at 5204'; Baker 'S-3' packer at 9273'; Baker 'ZXP' Liner Top packer at 9273'; Baker 'CTC' Payzone packer at 11889' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation December 15, 2000 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Pre-Produced Injector (Converting to WAG Injection Post RWO) Name of approver Date Approved Contact Engineer Name/Numben Barbara Holt. 564-5791 Prepared By Name/Number: Terrie Hubble, 564-4628 17. , hereby DanCertify that~o~oi.n~l is true and correct to the best of my knowledge / ~//~/'//~1 Signed Stone~/~~~ Title Senior Drilling Engineer Date Conditions of Approval: Notify Commission so representative mayjcitness II Approval No. ~__.~ ~~) Plug integrity __ BOP Test .1~. Location clearance __ Mechanical Integrity Test .'~. Subsequent form required 10- ~b~. Approved by order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL D Tay'to, Commissioner Date/...~ ~./~ (~ Submit?//~iiJlicate Scope of Work S-22Bi failed an MIT prior to the well conversion from a producer to injector. A PDS multi-finger caliper survey run Dec 15, 1999 indicates the tubing is in poor condition with holes recorded in 4 joints and an additional 29 joints with possible holes in the tubing. The S-22Bi scope of work is to remove the existing 4-1/2" L-80 completion and run new 4-1/2" L-80 tubing with a stacker packer. Pre-Riq Work 1. Drift 4-1/2" tubing down to 9275' MD. 2. Pull the bottom GLV. 3. Circulate the well to seawater. 4. Chemical cut the 4-1/2" tubing @ 9200' MD (just above the X-nipple @ 9208'md). 5. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the 9 5/8" packoff tests, completely back out and check each 9-5/8" and 4-1/2" lock down screw for breakage (check one at a time). If tested recently, e-mail or fax in test report. 6. Set a BPV and clear and level pad in preparation of the rig move. Assure annuli are freeze protected. Ri.q 1. Workover Procedure - 6 days MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater. 2. Pull 4 ~" tubing down to the tubing cut @ 9000' MD. 3. RIH with RTTS and test 9-5/8" casing to 4000 psi for 30 minutes. 4. Run 4-1/2" L80 completion with new packer and overshot assembly. 5. RU slickline and make drift run in tubing. Set packer. 6. Freeze protect permafrost zone through top GLM. 7. Set BPV, ND BOPE, NU and test tree. RDMO. Assumes the 7" x 9-5/8" casing passes the 4000 psi integrity test. Post-ric~ Work 1. Install flowline and reset wellhouse. 2. RU slickline and pull RHC sleeve. 3. Replace RP shear valve with dummy valve. RECEIVED DEC 0 7 2000 Alaska 0il & Gas Cons, C0rnm/sajon A~cl~orage TREE: 4" CIW KB. ELEV = 68.34' WELLHEAD:FMC-GEN 2 BF. ELEV = 36.05' ACTUATOR: BAKER S-22bi O 4.5"HMS HXO BVN (3.813"1D) -- 13 318"72# L-80 BTC CSG ~ Il, 13 3/8"SHOE I 2685' I GAS LIFT MANDRELS: CAMCO 4.5~( I"KBG-2LS W/DE-1 LATCH (3.9091D) [ NO, I MD(BKB) TVDss DEV. 6 3022' 2956' 0 4.5" 12.6~ L-80 BTC-M TBG 5 5620' 5280' 33 4 7225' 6708' 27 -7X 9 5/8"BAKER ZXP LNR/PKR 3 8042' 7443' 25 I I W/TIEBACK SLEEVE I 5204'1 2 8611, 7959, 24 7-26~ L-80 1 9138'I 8442' 21 BTC-M CSG '~ KOP I CAP:.0383 BBL/FT I MILLED WINDOW 1 5402'- 5418' I ID: 6.276" IN 9 5/8"CASING I FOR SIDETRACK I I 4.5"HMS X-NIPPLE (3.813"1D) I 9208' I I 7X4 1/2"BAKER 8-3 PACKER (3.850"1D) 19218' 9-5/8", 47#/ff, I I 4.5"HMS X-NIPPLE (3.813"1D)I 9242' L-80, BTRS ! 4.5"HES XN-NIPPLE (3.725"1D) I 19263'9283, L , %~ XN ELMD Category II No SSSV iW/TIEBACK SLEEVE (3.850"1D) ~4.5,, WlEG I 9275'1 PERFORATION SUMMARY: SIZE SPF INTERVAL FT Date 2 7/8 1 9630-9650 20 open-12/24/97 2 7/8 I 9720-9740 20 open-12/30/97 2 7/8 1 11070-11090 20 open-12/30/97 ~ ~ ~ 2 7/8 1 11120-11140 20 open-12/30/97 ~ , '~ 27/8 1 11170-11190 20 open-12/30/97 i i ~-- "'~, ~ BakerCTC1~acker , , · ~ - L,. ,,,,,., I PBTDI12219'I 4.5" 12.~ L-80 IBT-MOD LINER ~ ~k CAPACITY: .0152 BbI. Jft 4 1/2"12.6# ID: 3.958" Slotted Liner DATE REV. BY COMMENT.~ PRUDHOE BAY UNIT 7/12/97 CHH SIDETRACK COMPLETION / RIB 18-E WELL: S-22Bi APl NO: 50-029- 22119-02 12/3o/97 A Coleman Add perfs SEC 35; TN 12N ; RGE 12E 1/19/99 GLM Rever~ depths back to ddllers depth BP EXPLORATION (ALASKA) CAMCO 4.5~ I"KBG-2LS W/DK-1 LATCH (3.9091D) NO, MD(BKB) TVDss DEV. 6 3022' 2956' 0 5 5620' 5280' 33 4 7225' 6708' 27 3 8042' 7443' 25 2 8611' 7959' 24 1 9138' 8442' 21 PERMIT DATA AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 07/19/99 T DATA PLUS RUN RECVD 97-051 7862 97-051 DIR SRVY 97-051 PERF 97,~.,., .._ WHPST~~ 97-051 S ,T 10-407 DAILY WELL OPS 6795-12225 ~ ~ J~'6795-12225 ~ a~ ~f~SCHLUM GR/ARC5 ~/SS~HLUM 5388.80-12162.24 ~'~9080-9720 ~ t~ZC ~ FINAL 08/07/97 FINAL 11/13/97 FINAL 11/13/97 FINAL 11/13/97 1 11/13/97 11/21/97 FINAL 01/16/98 PERF .......... _~/-9050-12100 ~:_:?,_~::,~-~-- '" FINAL ~ L 9800-10 3 NAL. /.29/98 L 9800~102'81 FINAL' 0~/29/98 DATE . 711hl~,.?l Are dry ditch samples required? yes (~._And received? Was the well cored? yes ~Analysis & description received? Are well tests required?~s ~o~ Received? Well is in compliance IHitial COMMENTS T D BOX -- STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [~lOperation Shutdown []Stimulate [~] Plugging [~ Perforate ~] Pull Tubing [~Alter Casing [--I Repair Well [--lOther 2. Name of Operator 15. Type of well: 6. BP Exploration (Alaska)Inc. [ [] Development ~] Exploratory 7. 3. Address I--I Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 [--I Service 4. Location of well at surface 8. 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 679' NSL, 392' EWL, SEC. 26, T12N, R12E, UPM At effective depth 4214' NSL, 2120' WEL, SEC. 27, T12N, R12E, UPM At total depth 1063' NSL, 2066' WEL, SEC. 27, T12N, R12E, UPM Datum Elevation (DF or KB) KBE -- 65.5' Unit or Property Name Prudhoe Bay Unit Well Number S-22Bi 9. Permit Number / Approval No. 97-51 10. APl Number 50-029-22119-02 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12221 feet true vertical 8819 feet Effective depth: measured 12220 feet true vertical 8819 feet Casing Plugs (measured) Junk (measured) 9348'-10070' 8603'-8253' 300 sx Class 'G' 130 sx Class 'G' Length Size Cemented M D TVD Structural Conductor 110' 20" 250 cu ft AS (Approx.) 110' 110' Surface 2655' 13-3/8" 3723 cuft AS III & II 2685' 2649' Intermediate 9696' 9-5/8" 2020 cuft Class 'G' 9726' 8727' Production Liner 2934' 4-1/2" 348 cuft Class 'G' 9287'-12221' 8643'-8819' Perforation depth: measured 9630'-9650';9720'-9740';11070'-11090';11120'-11140';11170'-11190'; (11927'-12219' open hole) true vertical 8881 '-8895';8934'-8942';8870'-8867';8863'-8860';8855'-8852'; (8760'-8754' open hole) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 9275' 0J I¢INAL Packers and SSSV (type and measured depth) Packer @ 9218' SSSV @ 2214' 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation: 491 1454 1382 0 Subsequent to operation: 1606 2793 1892 0 Tubing Pressure 298 394 15. Attachments 16. Status of well classifications as: I--I Copies of Logs and Surveys run [--I Daily Report of Well Opera~,ons [] Oil [] Gas [] Suspended 7. I hereby certify..t, hat tr0je for~!ng is tr~ and correct to the best of my knowledge Signed ¢~~1~.~....._. Title Technical Assistant III Service Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Submit In Duplicate S-22B DESCRIPTION OF WORK COMPLETED ADDPERF 12/24/97 SUMMARY The following additional interval were perforated using 2 7/8" guns, 1 SPF, random orientation and random phasing. 9630' - 9640' MD 9640' - 9650' MD ADDPERF 12/28/97 SUMMARY The following additional interval were perforated using 2 7/8" guns, 1 SPF, random orientation and 0 phasing. 9720' - 9740'MD 11170' -11190' MD 11120'- 11140' MD 11070' -11090' MD ALAS leare, d rvIces rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: February 5, 1998 From: Subject: Terrie Hubble Technical Assistant Permit #97-51, S-22B Enclosed, in duplicate, are revised copies of the above listed Well Completion Report and Log. A calculation error was found in the Location of well at Total Depth. The well histories and logs have previously been filed with the Commission and there are no changes. Thank you. /tlh STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Revised: 01/27/98 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [--] Suspended []Abandoned []Service Pre-Produced Iniector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-51 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22119-02 4. Location of well at surface~.__...... ~ ........ 9. Unit or Lease Name 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UPM ~~i Prudhoe Bay Unit At top of productive intervalI~~ ;10. Well Number 679' NSL, 392' EWL, SEC. 26, T12N, R12E, UPM S-22Bi At total depth 11. Field and Pool 1066' NSL, 2126' WEL, SEC. 27, T12N, R12E, UPM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 65.5'I ADL 028258 12. Date Spudded6/24/97 113' Date I'D' Reached ] 14' Date C°mp" Susp" °r Aband'115' water depth' if °ffsh°re 116' N°' °f COmpleti°ns7/8/97 7/12/97 N/A MSL, One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey t20. Depth where SSSV set 121. Thickness of Permafrost 12221 8819 FTI 12220 8819 FTI []Yes []No (Nipple) 2214' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, DIR, ARC5 RES, AlT, LDT, CNL, SP, Sonic, Caliper 23. CASlNG~ LINER AND CEMENTING RECORD CASING SE'FrlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 250 cuft Arctic Set (Approx.) 13-3/8" 68# NT-80 Surface 2685' 17-1/2" 3723 cu ft Arctic Set III & II 9-5/8" 47# L-80 Surface 5402' 12-1/4" 2020 cuft Class 'G' 7" 26# L-80 5204' 9452' 8-1/2" 948 cu fi Class 'G' 4-1/2" 12.6# L-80 9287' 12221' 6" 348 cu fi Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 9275' 9218' MD TVD MD TVD 11927' - 12219' 8825' - 8819' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc,) July 31, 1997 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO iTEST PERIOD I Flow Tubing Casing Pressure [CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORE) Press. ~4-HOuR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9450' 8793' Shublik 9495' 8834' Top of Sadlerochit 9570' 8899' Sag River 11190' 8918' Shublik 11740' 8852' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I herebYsigned certify t,b, at~ the foregoing,~s~. ~'/true and correct to the best of my knowledge ¢O~./~../~' James Smi~~-'~'-'~'~ ~¢- ~-'4-~ Title Senior Drilling Engineer, Acting Date S-2~Bi 97-51 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No, / Approval No. iNSTRUCTIONS GENERA': 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'. RECEIVED FEB Og t998 Alaska 0ii & Form 10-407 Rev. 07-01-80 Facility PBS Pad Progress Report Well S-22B Rig Nabors 18E Page Date 1 20 November 97 Date/Time 22 Jun 97 23 Jun 97 24 Jun 97 25 Jun 97 26 Jun 97 27 Jun 97 28 Jun 97 13:00-00:00 00:00-00:30 00:30-06:00 06:00-08:30 08:30-09:30 09:30-11:30 11:30-16:00 16:00-19:00 19:00-19:30 19:30-00:00 00:00-01:00 01:00-04:00 04:00-06:00 06:00-06:15 06:15-07:00 07:00-08:00 08:00-08:30 08:30-09:00 09:00-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-15:30 15:30-16:30 16:30-22:00 22:00-23:00 23:00-02:00 02:00-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-07:00 07:00-08:30 08:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-08:30 08:30-09:30 09:30-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-17:00 17:00-00:00 00:00-00:30 00:30-06:00 06:00-06:30 06:30-07:00 07:00-00:00 00:00-00:30 00:30-01:00 Duration llhr 1/2 hr 5-1/2 hr 2-1/2 hr lhr 2hr 4-1/2 hr 3hr 1/2hr 4-1/2 hr lhr 3hr 2hr 1/4hr 3/4 hr lhr 1/2 hr 1/2 hr 3hr 1/2 hr 1/2 hr 2hr 1/2 hr lhr 5-1/2 hr lhr 3hr Ilar 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 3-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 2-1/2 hr lhr 2hr 1/2 hr 1/2 hr 1/2 hr 2hr 2hr 7hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 17hr 1/2 hr 1/2 hr Activity Rig moved 100.00 % Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick (cont...) Held safety meeting Removed Xmas tree primary components Rigged up BOP stack Tested BOP stack Removed Tubing hanger Conducted electric cable operations Tested Casing - Via annulus Made up BHA no. 1 R.I.H. to 2300.00 ft R.I.H. to 2400.00 ft (cont...) Tested Kelly cocks Circulated at 2400.00 ft Held drill (Spill) Circulated at 2400.00 ft R.I.H. to 5405.00 ft Held safety meeting Held drill (Kick (well kill)) Rigged up Tubing head spool Set tool face Circulated at 5402.00 ft %',4 Milled Casing at 5402.00 ft Circulated at 5440.00 ft Pumped out of hole to 400.00 ft Pulled BHA Serviced BOP stack Pulled BHA Serviced Block line Functioned M.W.D. tool R.I.H. to 5440.00 ft Drilled to 5535.00 ft Held safety meeting Drilled to 6226.00 ft Held safety meeting Drilled to 6660.00 ft Drilled to 6854.00 ff Circulated at 6854.00 ft Pulled out of hole to 848.00 ft Pulled BHA Held safety meeting Pulled BHA Made up BI-IA no. 3 R.I.H. to 6854.00 ft Drilled to 7444.00 ft Held safety meeting Drilled to 8020.00 ft Pulled out of hole to 6750.00 ft R.I.H. to 8020.00 ft Drilled to 9011.00 ft Held safety meeting Drilled to 9041.00 ft GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11758 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 1/28/98 Well Job # Log Description Date BL RF Sepia LIS Tape N-11A. -~ ~ "~Oc~ 98020 RST-SIGMA 980108 I 1 1 N-11Ao GAS LIFT SURVEY 980109 I I , , C-34 , PRODUCTION PROFILE 980111 I 1 C-38 , LEAK DETECTION LOG 980110 I 1 D- 14A , GR/CCL CORRELATION 980120 I 1 H- 08, PERFORATING RECORD 9 712 2 7 I 1 H- 33 t PERFORATING RECORD/GR-CCL 9 80105 1 1 J-10 * PERFORATING RECORD 9 8010 6 1 1 M-09A ' PRODUCTION FLUID SAMPLER 9 80112 1 1 M-09A * PERFORATE RECORD 9801 15 I 1 N- 14 · CHEMICAL CUTTER 980118 1 1 R-05 .- WHIPSTOCK SETTING RECORD 980111 1 1 R-25A ~ ORIENTED WHIPSTOCK SET 9 71 2 2 8 1 1 S-22B /' PERFORATING RECORD 9 7122 9 1 1 W-22 ~ FULL SUITE PRODUCTION LOG 980116 I 1 X-6 / INJECT. PROF. W/WARMBACKS 9 8 01 18 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 1/12/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.11707 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay iCased Hole) .., ./ / Well Job # Log Description Date BL RF Sepia LIS Tape B-05 A' PRODUCTION PROFILE 9 71 218 1 1 B-05A' PERFORATION RECORD 97'1 225 1 1 B' 1 O' TUBING PUNCHER RECORD 971 201 1 1 E'21 A PLUG SETTING RECORD 971 204 1 1 · .~.. "-~,"'~"~ 98007 RST 971217 I 1 F-37 M-09A TEMPERATURE/FLUID DENSITY 971 214 I 1 M-20A PERFORATION RECORD 9712 03 I 1 M- 23 PERFORATION SUMMARY 9712 02 1 1 P-03 WHIPSTOCK SET RECORD 9 71220 I 1 P-6 WHIPSTOCK SET RECORD 9 712 09 I 1 R- 15 INJECTION PROFILE 9 71 207 I 1 S-22B PERFORATION RECORD GR/CCL 9 71 224 1 I t~lC~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, A/~,ka 99618-1199 .... ' STATE OF ALASKA - ALASKA C,,-AND GAS CONSERVATION COM~,ISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: []Abandon [] Alter Casing [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate [] Suspend [] Plugging [] Time Extension [] Perforate [] Repair Well [] Pull Tubing [] Variance [] Other :2. Name of Operator BP Exploration (Alaska)Inc. i3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [~] Development [] Exploratory I--] Stratigraphic ~l Service 4. Location of well at surface 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 679' NSL, 392' EWL, SEC. 26, T12N, R12E, UPM At effective depth 4214' NSL, 2120' WEL, SEC. 27, T12N, R12E, UPM At total depth 1063' NSL, 2066' WEL, SEC. 27, T12N, R12E, UPM Convert to Producer 6. Datum Elevation (DF or KB) KBE = 65.5' 12. Present well condition summary Total depth: measured 12221 true vertical 8819 Effective depth: measured 12220 true vertical 8819 Casing Length Structural Conductor 110' Surface 2655' Intermediate 9696' Production Liner 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-22Bi 9. Permit Number 97-51 10. APl Number 50-029-22119-02 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool feet Plugs (measured) 9'348' - 10070' 300 sx Class 'G' feet 8603' - 8253' 130 sx Class 'G' feet Junk (measured) feet Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Size Cemented MD TVD 20" 250 cu ft AS (Approx.) 110' 110' 13-3/8" 3723 cu ft AS I11 & II 2685' 2649' 9-5/8" 2020 cu ft Class 'G' 9726' 8727' ~,last~ 011 & 6as Cons. 6om~ Anchorage ORIGINAL 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Convert service well to producer Aug 1, 1997 16. If proposal was verbally approved Name of approver Contact Engineer NamelNumb~ _ _ 1~ Prepared By Name/Number: 17.1 hereby certify tha[~the,___ fo~g/~ true and correct to the best of my knowledge Signed '"~,, t,~. ,X_,~.A.~' PAUL CLYNE ,f,¢,.-~,- ------ - (j'- ~- Title Supervisor, NorthWest Fault Block Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test Mechanical Integrity Test ~ Location clearance Subsequent form required 10- ,¢,,~, '¢ ,? L;ommlssloner Approved by order of the Commission Form 10-403 Rev. 06/15/88 Date //-~'~-?~:~ Submit In Triplicate S-22B Convert to Producer This well is a high angle producer with horizontal sections in both the Sag and Ivishak. We presently have the Sag as the only producing interval through the slotted liner at the end of the well. We plan to add perforations further up hole in the solid cemented liner through the Ivishak. S ag production should continue into late December, followed by the addperfs which will be produced until aerial pressures and production rates indicate injection support is required. Then, S-22B will be converted to injection. Before converting to injection, we will resubmit a sundry and run a CBL or WFL to verify pressure isolation of the reservoir intervals. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11605 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 12/3/97 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape S-22B (REDO) 97473 GR & ARC5 -~[3 7 ~ ~ ~.~ 970708 1 *REDO -INCORRECT MNEMONICS S-43 (REDO) 9'7471 CDR&ARC5 ~-7~~ 970530 1 .."..' *REDO -SPLICE RESISTIVITY S-43 L1 (REDO) 97472 CDR &ARC5 ;:~ -"7~'~J,_~-- 970617 1 *REDO -MERGE RESISTIVITY IN EDIT FILE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnicai Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~ Facility PBS Pad Progress Report Well S-22B Page 2 Rig Nabors 18E Date 20 November 97 - Date/Time 29 Jun 97 30 Jun 97 O1 Jul 97 01:00-01:30 01:30-06:00 06:00-12:00 12:00-12:30 12:30-16:00 16:00-17:00 17:00-18:00 18:00-19:30 19:30-20:00 20:00-21:00 21:00-23:30 23:30-00:00 00:00-00:30 00:30-02:30 02:30-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-14:30 14:30-16:00 16:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-19:00 19:00-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-09:30 09:30-10:00 10:00-12:00 12:00-12:30 12:30-13:30 13:30-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-23:00 23:00-00:00 00:00-00:30 00:30-03:00 03:00-06:00 06:00-07:00 07:00-08:30 08:30-12:00 Duration 1/2 hr 4-1/2 hr 6hr 1/2 hr 3-1/2 hr lhr lhr 1-1/2 hr 1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr lhr 4-1/2 hr 1/2 hr lhr 1/2 hr 2hr 1-1/2 hr 1/2hr 1/2 hr 1/2 hr 1/2 hr lhr 5hr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr lhr lhr 3-1/2 hr 1/2 hr 2hr 1/2 hr lhr 5hr lhr 1/2 hr 1/2 hr 2-1/2 hr lhr 1/2 hr 2-1/2 hr 3hr lhr 1-1/2 hr 3-1/2 hr Activity Pulled out of hole to 7967.00 ft Drilled to 9167.00 ft Drilled to 9248.00 ft Held safety meeting Drilled to 9452.00 ft Circulated at 9452.00 ft Pulled out of hole to 5400.00 ft R.I.H. to 9398.00 ft Reamed to 9452.00 ft Circulated at 9452.00 ft Pulled out of hole to 684.00 ft Pulled BHA Held safety meeting Pulled BHA Installed BOP stack Tested Top ram Rigged up Casing handling equipment Ran Liner to 1025.00 ft (7in OD) P, EC£IVED Ran Liner to 9452.00 ft (7in OD) Ran Drillpipe in stands to 5402.00 ft Circulated at 5402.00 ft Held safety meeting Ran Dfillpipe in stands to 9440.0~ka Oil &__.~a~ Cons. o to"omm'ss-n Circulated at 9452.00 fl Mixed and pumped slurry - 169.000 bbl Displaced slurry - 252.000 bbl Functioned Liner hanger Reverse circulated at 5204.00 ft Circulated at 5204.00 ft Pulled Drillpipe in stands to 0.00 ft Held safety meeting Laid down 1953.00 ft of 5in OD drill pipe Installed BOP stack Tested BOP stack Installed Bore protector Made up BHA no. 4 Singled in drill pipe to 963.00 ft Singled in drill pipe to 5231.00 ft Tested Liner R.I.H. to 6775.00 ft Held safety meeting R.I.H. to 9102.00 ft Drilled cement to 9370.00 ft Circulated at 9370.00 ft Tested Casing Tested Kelly Drilled to 9457.00 ft Circulated at 9457.00 ft Held safety meeting Circulated at 9457.00 ft Pulled out of hole to 7050.00 ft Pulled BI-IA Made up BHA no. 5 R.I.H. to 8100.00 ft Facility PBS Pad Progress Report Well S-22B Rig Nabors 1SE _. Page Date 3 20 November 97 Date/Time 02 Jul 97 03 Jul 97 04 Jul 97 05 Jul 97 06 Jul 97 12:00-12:30 12:30-13:30 13:30-20:00 20:00-21:00 21:00-00:00 00:00-00:30 00:30-01:00 01:00-03:00 03:00-04:30 04:30-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-12:00 12:00-12:30 12:30-18:00 18:00-19:00 19:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:30 01:30-04:30 04:30-05:30 05:30-06:00 06:00-12:00 12:00-12:30 12:30-19:00 19:00-19:30 19:30-20:00 20:00-20:30 20:30-21:00 21:00-00:00 00:00-00:30 00:30-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-09:30 09:30-10:00 10:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-07:30 07:30-12:00 12:00-12:30 12:30-13:00 13:00-14:30 14:30-18:00 18:00-18:30 18:30-00:00 00:00-00:30 Duration 1/2 hr lhr 6-1/2 hr lhr 3hr 1/2hr 1/2 hr 2hr 1-1/2 hr 1/2 hr lhr lhr lhr 4hr 1/2 hr 5-1/2 hr lhr 3-1/2 hr lhr 1/2 hr 1/2 hr lhr 3hr lhr 1/2 hr 6hr 1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 1-1/2 hr lhr 2hr lhr 3-1/2 hr 1/2 hr 2hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 4-1/2 hr 1/2hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr Activity Held safety meeting R.I.H. to 9457.00 fi Drilled to 9630.00 ft Circulated at 9630.00 ft Pulled out of hole to 1400.00 ft Held safety meeting Pulled out of hole to 86.00 ft Made up BHA no. 6 R.I.H. to 3500.00 ft Serviced Block line R.I.H. to 5800.00 fi R.I.H. to 9530.00 ft Took MWD survey at 9562.00 ft Drilled to 9724.00 ft Held safety meeting Drilled to 9853.00 ft Circulated at 9853.00 ft Pulled out of hole to 228.00 ft Pulled BHA Made up BHA no. 7 Held safety meeting Made up BHA no. 7 R.I.H. to 9847.00 ft Took MWD survey at 9847.00 ft Drilled to 9883.00 ft Drilled to 9913.00 ft Held safety meeting Drilled to 10025.00 ft Circulated at 10025.00 ft Pulled out of hole to 9450.00 ft R.I.H. to 10025.00 fl Drilled to 10025.00 fl Pulled out of hole to 3341.00 ft Held safety meeting Pulled out of hole to 73.00 fl Pulled BHA Made up BHA no. 8 R.I.H. to 1500.00 ft R.I.H. to 10005.00 fi Took MWD survey at 10005.00 ft Drilled to 10113.00 ft Held safety meeting Drilled to 10930.00 ft Held safety meeting Drilled to 11276.00 ft Drilled to 11254.00 ft Pulled out of hole to 78.00 ft Held safety meeting Pulled BHA Made up BHA no. 9 R.I.H. to 11175.00 ft Reamed to 11254.00 ft Drilled to 11406.00 ft Held safety meeting Progress Report Facility PBS Pad Well S-22B Rig Nabors 18E Page 4 Date 20 November 97 Date/Time 07 Jul 97 08 Jul 97 09 Jul 97 00:30-06:00 06:00-08:30 08:30-10:00 10:00-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-15:00 15:00-15:30 15:30-17:30 17:30-18:30 18:30-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-07:00 07:00-07:30 07:30-08:00 08:00-11:30 11:30-12:00 12:00-12:30 12:30-13:30 13:30-17:30 17:30-21:00 21:00-21:30 21:30-00:00 00:00-00:30 00:30-06:00 06:00-08:00 08:00-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-15:30 15:30-18:00 18:00-19:00 19:00-20:00 20:00-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-04:30 04:30-05:00 05:00-06:00 06:00-07:30 07:30-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-13:30 Duration 5-1/2 hr 2-1/2 hr 1-1/2 hr 1 hr lhr 1/2 hr lhr 1/2 hr lhr 1/2 hr 2hr lhr 5-1/2 hr 1/2hr 1-1/2 hr 4hr lhr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr lhr 4hr 3-1/2 hr 1/2 hr 2-1/2 hr l/2hr 5-1/2 hr 2hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 2-1/2 hr lhr lhr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr lhr 1-1/2 hr 3hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2hr Activity Drilled to 11564.00 ft Drilled to 11700.00 ft Circulated at 11700.00 ft Pulled out of hole to 9448.00 ft Circulated at 9448.00 ft Held safety meeting Circulated at 9448.00 ft R.I.H. to 11585.00 ft Circulated at 11585.00 ft Pulled out of hole to 9448.00 ft Circulated at 9448.00 ft R.I.H. to 11700.00 ft Drilled to 11827.00 ft Held safety meeting Circulated at 11700.00 ft Pulled out of hole to 2200.00 ft Pulled out of hole to 109.00 ft Pulled BHA Installed BOP test plug assembly Tested BOP stack Installed Bore protector Held safety meeting Made up BHA no. 10 R.I.H. to 11827.00 ft Drilled to 11908.00 ft Took MWD survey at 11875.00 ft Drilled to 11950.00 fi Held safety meeting Drilled to 12222.00 ft Circulated at 12221.00 fi Pulled out of hole to 9450.00 ft R.I.H. to 12221.00 fi Circulated at 12221.00 fi Held safety meeting Circulated at 12221.00 ft Pulled out of hole to 9400.00 ft Serviced Block line Pulled out of hole to 217.00 ft Pulled BI-IA Rigged up Tubing handling equipment Ran Liner to 2949.00 ft (4-1/2in OD) Rigged down Tubing handling equipment Held safety meeting Circulated at 2949.00 ft Ran Liner on landing string to 9452.00 ft Circulated at 9452.00 ft Ran Liner on landing string to 12221.00 ft Circulated at 11924.00 ft Circulated at 11924.00 ft Held safety meeting Rigged down High pressure lines Held safety meeting Rigged down High pressure lines Rigged up Slickline unit Facility Date/Time 10 Jul 97 11 Jul 97 12 Jul 97 Progress Report PBS Pad Well S-22B Page 5 Rig Nabors 18E Date 20 November 97 13:30-15:00 15:00-15:30 15:30-16:00 16:00-17:00 17:00-17:30 17:30-18:45 18:45-18:50 18:50-19:15 19:15-19:50 19:50-20:10 20:10-20:30 20:30-21:00 21:00-21:15 21:15-22:30 22:30-00:00 00:00-00:30 00:30-01:00 01:00-04:00 04:00-06:00 06:00-08:30 08:30-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-19:00 19:00-20:00 20:00-20:30 20:30-23:00 23:00-00:00 00:00-00:30 00:30-03:00 03:00-03:30 03:30-06:00 06:00-12:00 12:00-12:30 12:30-13:00 13:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-08:30 08:30-10:00 10:00-10:45 10:45-12:00 12:00-12:30 12:30-14:30 14:30-16:00 16:00-20:00 20:00-22:00 Duration 1-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1-1/4 hr 0hr 1/4hr 1/2 hr 1/4hr 1/4 hr 1/2 hr 1/4 hr 1-1/4 hr 1-1/2 hr 1/2 hr 1/2hr 3hr 2hr 2-1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 5-1/2 hr lhr 1/2 hr 2-1/2 hr lhr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 6hr 1/2 hr 1/2 hr 3hr 1/2 hr lhr 1/2 hr 6hr 1/2 hr 4hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 3/4 hr 1-1/4 hr 1/2 hr 2hr 1-1/2 hr 4hr 2hr Activity Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Circulated at 11924.00 fi Rigged up High pressure lines Held safety meeting Cleared Chicksan lines Tested High pressure lines Functioned Downhole equipment Batch mixed slurry - 62.000 bbl Pumped Water spacers - volume 70.000 bbl Mixed and pumped slurry - 62.000 bbl Displaced slurry - 124.000 bbl Functioned Mechanical packer Reverse circulated at 11924.00 fi Held safety meeting Held safetY meeting Circulated at 11924.00 ft Pulled Drillpipe in stands to 0.00 ft Made up BI-IA no. 11 Made up BHA no. 11 (cont...) R.I.H. to 9286.00 fi R.I.H. to 11000.00 ft Held safety meeting R.I.H. to 11865.00 fi Tested Liner - Via annulus and string Drilled cement to 11927.00 ft Circulated at 11927.00 fi R.I.H. to 12220.00 ft Circulated at 12220.00 ft Pulled out of hole to 11927.00 fi Held safety meeting Circulated at 11927.00 ft Rest hole at 11927.00 ft Pulled out of hole to 9790.00 ft Pulled out of hole to 500.00 ft (cont...) Held safety meeting Pulled BI-IA Laid down 990.00 ft of 5in OD drill pipe Retrieved Wear bushing Serviced Top ram Rigged up Tubing handling equipment Ran Tubing to 7058.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 9277.00 ft (4-1/2in OD) Rigged up Tubing hanger Circulated at 9275.00 ft Set packer at 9218.00 fi with 4000.0 psi Serviced Top ram Removed BOP stack Held safety meeting Removed BOP stack Installed Xmas tree Circulated at 3022.00 ft Installed Hanger plug RECEIVED Alaska 0Ii a Gas Cons. Commission Anchorage Anadrill Client: BP Exploration Field: Prudhoe Bay Well Name: S-22Bi APl number: 50-029-22119-01 Job umber: 4000838 Rig: 18-E County: NSB State: AK Survey Calculations Calc method for positions: Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL Depth reference KB 65.5 GL above Permanent 34.85 FT KB above Permanent 65.50 FT DF above Permanent FT Vertical section od~lin Latidude (+N/S-): 0 Departure (+E/W-): 0 Azim from rotary table to target: 279.36 degrees SURVEY REPORT Spud Date: 24-Jun-97 Last survey date: 8-Jul-97 Total accepted surveys: 146 MD of first survey: 5418.17 FT MD of last survey: 12162,24 FT Geomagnetic data Magnetic Model: BGGM 1996 Version Magnetic Date: Magnetic field strength: 1146.87 HCNT Magnetic dec (+E/W-): 28.29 degrees Magnetic Dip: 80.72 degrees MWD survey Reterence Criteria Reference G: 1002.68 Reference H: 1146.87 Reference Dip: 80.72 Tolerance G: 4 Tolerance H: 6 Tolerance Dip: 0.3 Correction Magnetic dec (+E/W-): 28.29 degrees Grid convergence (+E/W-): 0 degrees Total az corr (+E/W-): 28.29 degrees Schlumber~ler ANADRILL Survey/Report I Seq Measured Incl A~imuth Course TVD # Depth angle angle length depth (ftt {de~) (dec, I1 (It) (ft) I 5388.80 35.80 309.70 0.00 5155.60 2 5418.17 37.49 309.70 29.40 5179.19 3 5450.31 36.17 312.80 32.10 5204.88 4 5482.38 36.47 315.90 '32,10 5230.75 5 5513.46 35.91 318.90 31,10 5255.85 6 5545,00 34.62 321.90 31,50 5281.57 7 5577,04 33.04 325.80 32.00 5308.16 8 5609.50 31.98 , 329.90 32.50 5335,57 9 5640.13 30.54 332.90 30.60 5361,72 10 5671.76 28.74 338.00 31.70 5389.28 11 5703,26 27.73 341.60 31.50 5417,03 12 5734.32 27.42 347.70 31.00 5444.52 13 5765.85 27.31 353.50 31,50 5472.50 14 5796.23 27.23 359.80 30.40 5499.52 15 5826.95 26.90 6.70 30.70 5526.87 16 5857.81 26.42 12.40 30.90 5554.49 17 5889.65 26.19 18.60 31.90 5583.09 18 5921,39 26.49 21.60 31,70 5611.50 19 6013.00 27.05 21.70 91.60 5693.28 20 6109.55 27.58 22.80 96.50 5779.02 21 6205.57 27.60 25.10 96.10 5864.20 22 6298.67 27.81 25.90 93.10 5946.62 23 6392.53 27.41 23.50 93.80 6029.74 24 6486.14 27.50 20.50 93.60 6112.81 25 6581.25 27.42 21.10 95.20 6197.28 26 6675.92 27.17 21.90 94.60 6281.35 27 6770.73 26.67 22.10 94.80 6365.88 28 6862.84 26.42 22.50 92.10 6448.27 29 6956.98 26.49 21.80 94.20 6532.60 30 7048.77 26.55 21.10 91.80 6614.74 Vertical ]isplacement Total at Azrn DLS S~/ section +N/S- +E/W-lisplacement (deg/ tool tft) (ltl Iff) Itt) (decal 100f) t~/pe 807.12 572.80 -723.60 922.87 308.37 0.00 TIP 822.28 584.00 -737.11 940.42 308.39 5.75 MWD_M 838.62 596.66 -751.59 959.63 308.44 7,25 MWD_M 854.19 609.95 -765.18 978.54 308.56 5.80 MWD_M 868.65 623.46 -777.61 996,68 308.72 5.97 MWD_M 882.37 637.46 -789.20 1014.50 308.93 6,86 MWD_M 895,08 651,84 -799.72 1031.72 309.18 8.39 MWD_M 906,66 666.61 -809.02 1048.27 309.49 7,52 MWD_M 916.43 680.54 -816.62 1063.02 309.81 6.93 MWD_M 925.19 694.78 -823.15 1077,17 310.17 9,77 MWD 932.54 708.76 -828,30 1090.15 310.55 6.28 MWD 938.54 722.58 -832.10 1102.05 310,97 9,16 MWD 943.19 736.85 -834.46 1113,23 311.45 8,47 MWD 946.25 750.74 -835,27 1123.07 311.95 9.50 MWD 947.74 764.66 -834.49 1131.85 312.50 10,28 MWD 947.70 778.32 -832.20 1139.44 313.08 8.42 MWD 946.19 791.93 -828.43 1146.05 313.71 8.64 MWD 943.57 805.13 -823.59 1151.75 314.35 4.30 MWD 934.79 843.48 -808.37 1168.30 316.22 0.61 MWD 924.91 884.46 -791.60 1186.97 318.17 0.76 M WD 913.70 925.13 -773.54 1205.91 320.10 1.11 MWD 901.66 964.19 -754.90 1224.56 321.94 0.46 MWD 890.16 1003.68 -736.73 1245.05 323.72 1.26 MWD 880.72 1043.68 -720.57 1268.26 325.38 1.48 MWD 872.01 1084.72 -704.98 1293.68 326.98 0.30 MWD 862.89 1125.08 -689.09 1319.33 328.51 0.47 MWD 853.50 1164.87 -673.01 1345.32 329.98 0.54 MWD 844,28 1202.96 -657.39 1370.86 331.34 0.33 MWD 834.99 1241.82 -641.57 1397.76 332.68 0.34 MWD 826.41 1279.97 -626.58 1425.11 333.92 0,35 MWD Page 1 ORIGINAL Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical ]isplacement Total atAzm DLS Srvy # Depth angle angle length depth section +N/S- +E/W- lisplacement (deg/ tool (fi) (dec, I) (de?) (it) (It) (fl) (It) (it) ,(fl) (decal 100t1 ~ 31 7142.12 26.73 20.80 93.30 6698.14 818.00 1319.04 -611.62 1453~94 335.12 0.24 MWD 32 7235.12 26.62 20.6O 93.0O 6781.24 809.80 1358.10 -596.87 1483.47 336.28 0.15 MWD 33 7328.50 26.27 19.00 93.40 6864.87 802.26 1397.23 -582.77 1513.89 337,36 0,85 MWD 34 7423.45 26.50 19.40 95.00 6949.97 795.04 1437.10 -568.89 1545.60 338.40 0,31 MWD 35 7517.88 26.35 19.80 94.40 7034.51 787.57 1476.67 -554.80 1577.46 339.41 0.25 MWD 36 7612.73 26.20 20.40 94.80 7119.51 779.75 1516.08 -540.38 1609.51 340.38 0.32 MWD 37 7706.49 25,97 19.60 93.80 7203.76 772.14 1554.84 -526.27 1641.49 341.30 0,45 MWD 38 7800.73 25.79 18.30 94.20 7288,51 765.28 1593.72 -512.92 1674,23 342.16 0,63 MWD 39 7894.02 24,85 13.70 93.30 7372,86 760.65 1632,05 -501.90 1707.48 342.91 2.34 MWD 40 7987.86 24.80 12.30 93.90 7458.08 758,14 1670.46 -493,03 1741,70 343.56 0,63 MWD 41 8081.06 24.82 12.00 93.20 7542.68 756.24 1708.69 -484.80 1776.13 344.16 0.14 MWD 42 8174.70 24.95 13.60 93.60 7627.59 753.87 1747.09 -476,07 1810.79 344.76 0,73 MWD 43 8269.22 25.03 14.50 94.50 7713,24 750.61 1785.82 -466.38 1845,71 345.36 0.41 MWD 44 8362.35 25.26 13.30 93.10 7797.52 747.48 1824.22 -456.88 1880.56 345.94 0.60 MWD 45 6456.20 25.06 12.40 93.90 7882.51 745.05 1863.14 -448,00 1916.24 346,48 0.46 MWD 46 8550,67 24.68 12.40 94.50 7968.25 742.94 1901.96 -439.47 1952.07 346.99 0.40 MWD 47 8644.46 24.44 11.10 93.80 8053.56 741.31 1940.12 -431.52 1987.53 347.46 0.63 MWD 48 8739.15 24.14 13.30 94.60 8139.79 739.39 1978.15 -423.31 2022.94 347,92 1.01 MWD 49 8832.70 23.65 10.40 93.60 8225.37 737.73 2015.25 -415.51 2057.64 348.35 1,36 MWD 50 8924.44 23.25 10.10 91.70 8309.50 737.17 2051.16 -409,02 2091.54 348,72 0,46 MWD 51 9018.75 22.79 11.80 94;30 8396.29 736.15 2087.36 -402.02 2125.72 349.10 0.86 MWD 52 9112.23 22.47 11.50 93.50 8482.59 734.71 2122.59 -394.76 2158.99 349.46 0.36 MWD 53 9143.12 22.95 9.50 30.90 8511.09 734.48 21 34.32 -392.58 2170.13 349.58 2.94 MWD 54 9174.45 23.21 7.60 31.30 8539.89 734.65 2146.45 -390.76 2181.73 349.68 2.52 MWD 55 9205,79 23,79 4.20 31.40 8568.68 735.41 2158.90 -389.48 2193,75 349,77 4,70 MWD 56 9237.78 24.07 2.50 32.00 8597.93 736.77 2171.86 -388.72 2206.37 349.85 2.33 MWD 57 9267.58 24.08 1.70 29.80 8625.14 738.31 2184.01 -388.28 2218.25 349.92 1.10 MWD 58 9299.27 23.85 1.60 31.70 8664.11 740.03 2196.88 -387,91 2230.86 349.99 0.74 MWD 59 9329.73 23.48 2.30 30.40 8681.95 741.61 2209,07 -387.49 2242.80 350.05 1.53 MWD 60 9360.62 23.00 1.90 30.90 8710.35 743.15 2221.26 -387.04 2254.73 350.12 1.64 MWD 61 9442.83 22.07 1.90 82.20 8786.27 747.24 2252,74 -386.00 2285.57 350.28 1.13 MWD_M 62 9474.59 23.60 354.80 31.80 8815.58 749.62 2265.06 -386.38 2297.77 350.32 9.90 MWD 63 9505.86 27.10 345,50 31.30 8843.88 754.08 2278,21 -388.73 2311.14 350.32 16.91 MWD 64 9536.87 30.35 338.30 31.00 8871.06 760.98 2292,33 -393.40 2325.84 350.26 15.30 MWD_M 65 9550.34 31.60 335.70 13.40 8882.55 764.67 2298.67 -396.10 2332.55 350.22 13.66 MWD 66 9591.99 36.70 ; 327.10 41.70 8917.07 779.12 2319.12 -407.37 2354.63 350.04 16.82 MWD_M 67 9623.64 41.05 322.10 31.60 8941.67 793.10 2335.25 -418,89 2372,52 349.83 16.97 MWD_M 68 9655.72 48,70 319.20 32,10 8964.41 810.13 2352,72 -433.26 2392.28 349.57 24.66 MWD_M 69 9674.43 53.80 317.40 18.70 8976.11 821.48 2363.60 -442.97 2404.75 349.39 28,28 MWD_M 70 9686,50 57.30 317.00 12.10 8982.95 829,35 2370.92 -449.74 2413.20 349.26 29.05 MWD_M 71 9717.76 64.85 314,50 31.30 8998.08 851.40 2390.51 -468.86 2436.06 348.90 25.11 MWD_M 72 9747.83 68.65 307.30 30.00 9009.93 874.88 2408.52 -489.69 2457.80 348.51 25.42 MWD_M 73 9778.50 71.55 298.70 30.70 9020.40 901.30 2424.20 -513.88 2478.07 348.03 27.98 MWD_M 74 9795.88 74.05 293.30 17.40 9025.55 917.22 2431.48 -528.81 2488.32 347.73 32.94 MWD_M 75 9826.37 78.25 288.00 30.50 9032.85 946.25 2441.91 -556.51 2504.52 347.16 21.77 MWD_M 76 9856.03 82.06 283.90 29.60 9037.92 975,20 2449,91 -584.54 2518.68 346.58 18.76 MWD_M 77 9889.07 82.57 283.40 33.10 9042.34 1007.91 2457.65 -616.42 2533.78 345.92 2.15 MWD_M 78 9920.42 64.03 280.40 31.30 9046.00 1038.97 2464.06 -646.83 2547.55 345.29 10.60 MWD_M 79 9953.78 84.13 280.70 33.40 9049.44 1072.18 2470.14 -679.49 2561.90 344.62 0.94 MWD_M 80 9993.31 84.03 279.50 39.50 9053.51 1111.47 2477.03 -718.17 2579.04 343.83 3.03 MWD_M 81 10025.37 85.47 279.50 32.10 9056.45 1143.43 2482.31 -749.70 2593.05 343.19 4.49 MWD_M 82 10057.09 88.56 279.90 31.70 9058.10 1175.08 2487.64 -780.90 2607.33 342,57 9.83 MWD_M 83 10088.78 91.89 279.40 31,70 9057.98 1206.78 2492.96 -812.15 2621,91 341.96 10.62 MWD_M 84 10120.59 95.46 279.20 31.80 9055.94 1238.51 2498.08 -843.46 2636.64 341.34 11,24 MWD_M 85 10151.90 97.15 279.20 31.30 9052,50 1269.62 2503.06 -874.17 2651.31 340.75 5.40 MWD_M 86 10183.62 97.01 277.60 31.70 9048.59 1301.07 2507.65 -905.29 2666.06 340.15 5.03 MWD_M 87 10214.45 96.70 278.70 30.90 9044.91 1331.74 2512.00 -935.66 2680.60 339.57 3.67 MWD_M 88 10246.68 96.50 278.40 32.20 9041.21 1363.73 2516.76 -967.29 2696.24 338.98 1.11 MWD_M Page 2 Schlumberc}er ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical ~isplacement Total at Azrn DLS Srvy # Depth angle angle length depth section +N/S- +E/W- lisplacement (deg/ tool (ft) (dec, l,/ (de~l) (ft1 Ifil Itt1 (ft) {ft! /ft/ /dec, I/ 1001/ type 89 10278.37 96.36 277.90 31.70 9037.66 1395.22 2521.22 -998.47 2711.74 338.40 1.63 MWD_M 90 10309.91 95.98 279.50 31.50 9034.27 1426.53 2525.96-1029.43 2727.67 337.83 5.19 MWD_M 91 10341.58 96.50 277.60 31.70 9030.82 1458.04 2530.65-1060.59 2743.90 337.26 6.18 MWD_M 92 10373.50 97.16 276.00 31.90 9027.03 1489.68 2534.40-1092.04 2759.66 336.69 5.39 MWD_M 93 10405.43 96.74 277.20 31.90 9023.17 1521.31 2538.04 -1123.49 2775.58 336.12 3.96 MWD_M 94 10437.46 96.81 275.80 32.10 9019.38 1553.15 2541.64 -1155.16 2791.84 335.56 4.34 MWD_M 95 10469.43 97.96 275.20 31.90 9015.28 1584.71 2544.68 -1186.65 2807.76 335.00 4.06 MWD_M 96 10500.98 97.42 274.80 31.60 9011.05 1615.93 2547.41 -1217.85 2823.55 334.45 2.12 MWD_M 97 10532.02 96.97 275.30 31.00 9007.17 1646.60 2550.11 -1248.48 2839.33 333.91 - 2.16 MWD_M 98 10561.92 96.67 275.60 29.90 9003.62 1676.22 2552.93 -1278.04 2854.97 333.41 1.41 MWD_M 99 10592.67 97.32 275.20 30.80 8999.87 1706.72 2555.81 -1308.47 2871.28 332.89 2.47 MWD_M 100 10624.92 98.88 275.30 32.20 8995.33 1738.51 2558.73 - 1340.22 2888.47 332.36 4.85 MWD_M 101 10656.88 98.67 275.20 32.00 8990.45 1.770.06 2561.62 -1371.71 2905.77 331.83 0.73 MWD_M 102 10687.98 98.25 276.60 31.10 8985.88 1800.76 2564.78 -1402.31 2923.11 331.33 4.65 MWD_M 103 10719.91 97.84 276.90 31.90 8981.41 1832.32 2568.50 -1433.67 2941.53 330.83 1.59 MWD_M 104 10750.30 97.47 276.90 30.40 8977.36 1862.42 2572.11 -1463.58 2959.37 330.36 1.22 MWD_M 105 10781.67 97.33 275.20 31.40 8973.32 1893.50 2575.40 -1494.55 2977.64 329.87 5.39 MWD_M 106 10813.58 98.08 273.80 31.90 8969.04 1925.00 2577.88 -1526.06 2995.72 329.38 4.94 MWD_M 107 10844.48 97.91 275.00 30.90 8964.74 1955.48 2580.22 -1556.57 3013.38 328.90 3.88 MWD_M 108 10875.04 97.94 274.10 30.50 8960.54 1985.59 2582.62 -1586.68 3031.09 328.43 2.92 MWD_M 109 10906.67 98.25 274.10 31.90 8956.04 2017.04 2584.88 -1618.18 3049.61 327.95 0.97 MWD_M 110 10937.67 98.08 275.30 30.80 8951.67 2047.42 2587.38 -1648.57 3067.95 327.50 3.90 MWD_M 111 10969.72 97.80 274.60 32.00 8947.25 2079.02 2590.11 -1680.14 3087.32 327.03 2.34 MWD_M 112 11001.04 97.24 274.80 31.30 8943.15 2109.95 2592.65 -1711.07 3106.38 326.58 1.90 MWD_M 113 11032.29 96.82 275.20 31.30 8939.32 2140.92 2595.36 -1742.02 3125.78 326.13 1.85 MWD_M 114 11060.63 96.80 275.30 28.30 8935.97 2168.95 2597.93 -1770.00 3143.59 325.73 0.36 MWD_M 115 11091.70 97.22 274.10 31.10 8932.17 2199.72 2600.46 -1800.76 3163.09 325.30 4.06 MWD_M 116 11123.72 98.94 275.50 32.00 8927.67 2231.30 2603.11 -1832.33 3183.34 324.86 6.90 MWD_M 117 11155.52 98.64 275.00 31.80 8922.81 2262.64 2605.99 -1863.63 3203.79 324.43 1.82 MWD_M 118 11187.73 98.22 275.10 32.20 8918.09 2294.40 2608.79 -1895.35 3224.62 324.00 1.34 MWD_M 119 11220.01 97.91 275.80 32.30 8913.56 2326.31 2611.83 -1927.19 3245.88 323.58 2.35 MWD_M 120 11252.63 98.02 275.00 32.60 8909.04 2358.52 2614.87 -1959.33 3267.49 323.16 2.45 MWD_M 121 11283.88 98.33 275.30 31.30 8904.59 2389.42 2617.65 -1990.19 3288.30 322.75 1.37 MWD_M 122 11315.23 98.75 275.50 31.30 8899.94 2420.30 2620.56 -2021.00 3309.35 322.36 1.48 MWD_M 123 11347.18 98.71 275.20 32.00 8895.09 2451.85 2623.51 -2052.50 3331.00 321.96 0.93 MWD_M 124 11379.23 98.43 275.80 32.00 8890.32 2483.42 2626.54 -2083.99 3352.87 321.57 2.05 MWD_M 125 11410.32 95.94 ' 275.20 31.10 8886.43 2514.20 2629.50 -2114.70 3374.35 321.19 8.23 MWD_M 126 11441.96 95.63 275.30 31.70 8883.23 2545.66 2632.39 -2146.11 3396.36 320.81 1.03 MWD_M 127 11473.94 95.18 274.40 31.90 8880.23 2577.32 2635.07 -2177.75 3418.51 320.43 3.14 MWD_M 128 11505.86 95.39 275.20 32.00 8877.28 2609.08 2637.74 -2209.51 3440.87 320.05 2.57 MWD_M 129 11536.91 95.19 275.10 31.00 8874.42 2639.87 2640.51 -2240.25 3462.80 319.69 0.72 MWD_M 130 11568.80 96.70 274.90 31.90 8871.12 2671.50 2643.27 -2271.86 3485.43 319.32 4.77 MWD_M 131 11600.01 96.42 274.30 31.20 8867.55 2702.39 2645.76 -2302.75 3507.52 318.97 2.11 MWD_M 132 11631.76 95.56 273.70 31.80 8864.24 2733.88 2647.97 -2334.30 3529.97 318.60 3.29 MWD_M 133 11659.84 95.56 273.70 28.00 8861.52 2761.61 2649.76 -2362.11 3549.76 318.28 0.00 MWD_M 134 11693.77 96.15 274.00 34.00 8858.05 2795.28 2652.03 -2395.86 3573.99 317.91 1.94 MWD_M 135 11725.85 97.98 275.50 32.00 8854.12 2826.93 2654.66 -2427.50 3597.22 317.56 7.37 MWD_M 136 11783.07 98.15 275.20 57.30 8846.08 2883.52 2659.95 -2483.99 3639.44 316.96 0.60 MWD_M 137 11814.17 98.30 275.60 31.10 8841.63 2914.23 2662.85 -2514.63 3662.53 316.64 1.36 MWD_M 138 11845.31 99.30 276.70 31.10 8836.87 2944.91 2666.14 -2545.19 3685.96 316.33 4.75 MWD_M 139 11877.12 99.40 277.00 31.80 8831.71 2976.26 2669.88 -2576.34 3710.23 316.02 0.98 MWD_M 140 11942.38 95.00 276.30 65.30 8823.52 3040.96 2677.38 -2640.68 3760.53 315.40 6.82 MWD_M 141 11974.25 91.85 275.60 31.80 8821.63 3072.64 2680.67 -2672.24 3785.09 315.09 10.15 MWD_M 142 12006.17 90.75 274.20 32.00 8820.90 3104.53 2683.40 -2704.12 3809.58 314.78 5.56 MWD_M 143 12037.97 90.20 274.20 31.80 8820.64 3136.20 2685.73 -2735.83 3833.79 314.47 1.73 MWD_M 144 12069.36 89.65 273.80 31.40 8820.68 3167.47 2687.92 -2767.15 3857.73 314.17 2.17 MWD_M 145 12099.48 89.45 273.10 30.10 8820.91 3197.41 2689.74 -2797.20 3880.59 313.88 2.42 MWD_M 146 12130.35 91.05 272.70 30.80 8820.78 3228.01 2691.29 -2827.96 3903.90 313.58 5.35 MWD_M Page 3 ... -... ~.. " ',' - ," , " '\ ' .' . .,'. ' f . I , ., ",. .."..' ,', ,."',',', ,-..-,'- ,", """':_',:,"',.,I"\.."""',\,'"",,,,C"',;,, ~."".',..,.",...".~"",»-".,.",.".""""""",,,,""".""H"""""",..'~.U,'~n'~"',',"",~"-,,,' Schlumberger ANA DRILL Survey Report Seq Measured Inel Azimuth II Depth angle angle 'n) (deq) (d ,:i ~, Course length n - 31.90 I I~ Vertical IIsplaeement Total at Azm section +NIS- +E/W- msplacement 'n) (ff) (ff) (ff 147 12162.24 91.00 272.40 8820.21 Srvy tool .~ . ' 3259.68 2692.71= -2859.82 3928.01 <~ 313.28 0.95 MWD_M . RECEIVED NOV 2 1 1991 Alaska Oil & Gas Cons. CommiSSion Anchorage Page 4 .... 1 1/1 2/97 ~1[~"~ ~ ill ail 'Z~ ~ [~i GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11548 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape S-22B ~ '~:~:~ '~--.. 97473 GR & ARC5 970708 1 S-22B 97473 CDR/ARCS/IMPULSE (5") 970708 1 1 S-22B 97473 CDR/ARC5/IMPULSE (2") 970708 I 1 S-22B 97473 CDR/ARC5/IMPULSE TVD 970708 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11211 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive , Anchorage, AK 99501 8/1/97 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape B- 26 PERFORATING RECORD 9 7 0 62 6 I 1 C-9 PERFORATION RECORD 9 7 0 6 2 4 I 1 C-20A EZSV SET RECORD 9 70 6 21 I 1 C-27A JEWELRY LOG 9 70 6 2 4 I 1 D-23A JEWELRY LOG/PRESS SURVEY 9 70 6 21 I 1 'E-02 . ~) ,%" ©,.~ '~ TUBING CUT RECORD 970627 1 1 E- 26 TUBING CU'I-rER 9 70 63 0 1 1 H - 25 PERFORATING RECORD 9 70 6 2 2 I 1 H-35 FSPL 970625 I 1 K- 13 LEAK DETECTION 9 70 6 2 5 I 1 N- 20 A PERFORATION RECORD 9 70 621 I 1 R-29 ORIENTATED WHIPSTOCK 9 70 62 3 I 1 S-22 B PACKER RECORD 9 70 6 2 3 I 1 Y- 25 PLUG SET RECORD 9 70 62 2 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 MEMORANDUM TO: ./~Alaska David Jo~ Chairmar~ / THRU: Blair Wondzeil, -~'~ P. I. Supervisor State of Alaska Oil and Gas Conservation Commission DATE: June 30, 1997 FILE NO: ainkf4ee.doc FROM: Chuck Scheve, (-- -~ SUBJECT: Petroleum Inspector BOPE Test Nabors 18E PBU S-22B PTD # 97-51 Monday, June 30~ 1997: I traveled to BPX's S-22B Well being drilled by Nabors Rig 18E and witnessed the weekly BOPE test. As the attached AOGCC BOPE test report shows, the test lasted 2.5 hours with no failures. The test went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: I witnessed the weekly BOPE test on Nabors rig 18E. Nabors 18E, 6130197, Test Time 2.5 hours, no failures Attachment: ainkf4ee.xIs X Unclassified Confidential (Unclassified if doc. removed ) Confidential STAT OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: x Workover: DATE: Drlg Contractor: Nabors Rig No. fSE PTD # 97-5~ Rig Ph.# Operator: BPX Rep.: Well Name: S22B Rig Rep.' Casing Size: 7" Set @ 9,452 Location: Sec. 35 T. Test: Initial Weekly x Other 6/30/97 659/4608 Micheal Jackson Bill Bixby '/2N R. '/2E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. OK .... FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test I~dSll. Pressure I 250/5,0OO 1 250/5, 000 250/5, 000 250/5, OO0 P/F P P P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/2500 P I 250/5, OOO P I 250/5, 000 P I 250/5, 000 P 1 250/5, 000 P 2 250/5, 000 P ~ 250/5, 000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 16 250/5, 000 32 250/5, 000 Functioned Functioned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master:. Nitgn. Btl's: 8 @ 2250 2900 I 1700 minutes 27 minutes 3 OK Remote: Psig. see. OK Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within , days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Offlee at: Fax No. 276-7542 Inspector North Slope Pager No. 659-,3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIREDP YES X NO 24 HOUR NOTICE GNTN YES X NO Waived By: Witnessed By: AINKF4EE.XLS Chuck $cheve TONY KNOWLE$, GOVERNOR ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 rvlarch 27, 1997 Paul Prince Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bav Unit S-22B BP Exploration (Alaska) Inc. Permit No. 97-51 Sur. Loc 1629'SNL, 793'EWL, Sec. 35, TI2N, R12E, UM Btmhole Loc. 1193'NSL, 2184'WEL. Sec. 27. T12N, R12E, UM Dear Mr. Prince: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 25.030(g)(3). Sufficient notice (approximately' 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission may witness the tests. Notice ]nay be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely', Commissioner BY ORDER OF THE COMMISSION dlffEnclosure cc: Department ofFish & Game, Habitat Section xv/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Revised: 03/26/97 20 AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 64.55' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028258 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 828' NSL, 5250' WEL, SEC. 26, T12N, R12E, UPM S-22B At total depth 9. Approximate spud date Amount $200,000.00 1193' NSL, 2184' WEL, SEC. 27, T12N, R12E, UPM 05/31/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028257, 2184'I No Close Approach 2560 12340' MD / 8825' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 5395' Maximum Hole Angle 97.6° Maximum surface 3300 psig, Attotal depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 4830' 5245' 5039' 10075' 9055' 475 sx Class 'G' 6" 4-1/2" 12.6# L-80 IBT-Mod/NSCT 2415' 9925' 9049 12340' 8825' 250 SX Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10070 feet Plugs (measured) 9348' - 10070' 300 sx Class 'G' true vertical 9189 feet 8603' - 8253' 130 sx Class 'G' Effective depth: measured 8253 feet Junk (measured) true vertical 7545 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 250 cuft AS (Approx.) 110' 110' Surface 2655' 13-3/8" 3723 cuff AS III & II 2685' 2649' Intermediate 9696' 9-5/8" 2020 cuft Class 'G' 9726' 8727' Production Liner RECEIVED Perforation depth: measured None ~la~ka0lJ &~ (~IItB, ~ true vertical Allchora§ll 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Ddlling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ,, , Contact Engineer Nam~lumber: D~id Nakamura, 564-5606 Prepared By Name/Number: Terrie Hubble, $64-4628 21. I hereby certify that th~,foregoinq is/true and correct to the best of my knowledge Pau, Pr,nce ~.t~l,.X~.~.._t'"..,~ - Title Senior Drilling Engineer Date ~(~'~L Commission Use Only Permit Number APl Number I Approval Date I See cover letter 2.,,~- ._~/ 50-029-22119-02 for other requirements Condit~'ons of Approval: Samples Required [] Yes/,~' No Mud Log Required [] Yes .,~'~N~ Hydrogen Sulfide Measures ,~Yes [] No Directional Survey Required ./,~,Yes [] No Required Working Pressure for BOPE [] 2M; []3M; [] 5M; [] 10M; [] 15M Other: by order of A..pproved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BP EXPLORATION To: From: Subject: Bob Crandall David Nakamura Revision to S-22B Permit Date: March 26, 1997 Attached is the revision to the S-22B permit as was discussed on March 17th. Please use the attached with the directional plan from the original submittal of the drilling permit. If you have any further questions, please call me at 564-5606. Sincerely yours, David Nakamura DUPLICxl-E RECEIVED MAF~ 27 1997 AJa,m~ 0J/.& Qas Cons. ComrnLssion Anchorage I Well Name: I S-22B Redrill Plan Summary Type of Well (producer or injector): Pre-Produced MI Iniector I I Surface Location: 1629' FNL 793' FWL Sec 35 T12N R12E Start of Horizontal Location: 828' FSL 5250' FEL Sec 26 T12N R12E End of Horizontal Location: 1193' FSL 2184' FEL Sec 27 T12N R12E I AFE Number: 14P0904 I IRis: I Nabors 18E Estimated Start Date: I May 31, 1997 I I Operating days to complete: I 25 I MD: 112340' I ITVD: I8825' I IRT-GL I29.7' IKBE:I 64.55' Well Design (conventional, slimhole, etc.) High Angle Sidetrack. Objective: I Pre-produced MI injector targetting Zone 4 and Sag River Casinc/Tubinq Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC- 4830' 5245'/5039' 10075'/9055' MOD 6" 4-1/2" 12.6# L-80 I BT- 2075' 9925'/9049' 12000'/8826' MOD 6" 4-1/2" 12.6# L-80 NSCT 340' 12000'/8826' 12340'/8825' Tubing 4-1/2" 12.6# L-80 IBT- 9875' Surface 9875'/9038' MOD Cement Calculations: I Liner Size: I 7" liner Basis:I 50°/;0 open hole excess, 80' shoe joint and 150' liner lap ' Lead Cement Volume: 185 sxs of 15.7 ppg Class G Blend @ 3.31 ft3/sx Tail Cement Volume: 290 sxs of 15.7 ppg Class G Blend @ 1.15 ft3/sx I Liner Size: I 4-1/2" liner IBasis:I 40% open hole excess, 40' shoe joint, 150' liner lap and 200' on top of liner Total Cement Volume: I 250 1 sxs of 15.7 ppg Class G Blend @ 1.19 ft3/sx S-22B Permit Information Page 1 Mud Program: Sidetrack drilling fluid will be used as a millineI fluid. Sidetrack Mud-Properties: ' I Intermediate hole section: LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 10.0 45-50 12-15 4-8 8-12 9-10 8-12 Final 10.0 45-50 12-15 4-8 8-12 9-10 <6 HTHP-13.0 . , Hazards/Concerns History of Kuparuk gas cut mud, MW to be at least 10.0 ppg. Utilize hi vis sweeps to assist hole cleaning Monitor LSYP and increase if problems occur trying to clean the hole. Potential high torque could need lubricants (EP MudLube) Reduce APl fluid loss to <6 cc before drilling Kingak Section. If high torque is encountered, respond with lubricants. Note: The Jurassic shales may be troublesome, so treat with 2 ppb Baratrol and 6 ppb Baranex. Sadlerochit/Sag River Mud I New QUICKDRILn mud system will be used to drill 6" high angle Properties:I interval Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9365' 8.8-9.0 50-60 20-35 8-12 18-24 8.5-9.0 <6 12344' 8.8-9.0 50-60 20-35 8-12 18-24 8.5-9.0 <6 Hazards/Concerns Lost Circulation a possibility due to overbalance in Sadlerochit. Differential sticking possible with overbalance situation. Perform/report daily checks on KCI concentrations in QUICKDRILn system. High torque may be experienced and should be countered with lubricants Directional: I KOP: 15395' MD I Maximum Hole Angle: J97.6° Close Approach Well: No Close Approach Wells Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Shared Services Drilling Contact: Contact David Nakamura at (907) 564-5606 to answer any questions concerning Permit to Drill. S-22B Permit Information Page 2 Drilling Hazards: · Maximum anticipated BHP: · Maximum surface pressure: · Planned Completion Fluid: 3892 psi @ 8800' TVDss (8.5 ppg EMW) 2012 psi @ 8800' TVDss 8.5 ppg filtered sea water a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. The most recent H2S level on this well indicated 4 ppm H2S (maximum 4 ppm). prOper H2S precautions must be followed. d. Hydrocarbon-bearing zones expected above the Sag River formation in the Ugnu and Kuparuk formations Losses have been encountered drilling the Kingak, Sag River/Shublik and Sadlerochit formations on S Pad. Be prepared for losses near any faults and formation interfaces between the Kingak, Sag River/Shublik and Sadlerochit. RECEIVED & Ga~ Cone. OornmleeJon Anchorage S-22B Permit Information Page 3 S-22B Operations Summary . Pre-Rig Operations 1. Test the 9-5/8" mandrel packoff to 5,000 psi. 2. Bleed tubing and annuli pressures to zero. 3. Set TWC in the tubing hanger and test from below to 1000 psi. Secure well. 4. Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Rig Operations 1. MIRU drilling rig. 2. N/D the production tree. 3. N/U BOP. Test BOP to 250/5000 psi against TWC. Test annular preventer to 250/2500 psi. Remove TWC. Send adapter flange and tree to DSM for inspection and repair. Pull and lay down the 4-1/2" tubing and tubing hanger. Replace 9-5/8" mandrel if failed test. 5. Shut in well and test casing to 3500 psi for 30 minutes to ensure casing integrity. 6. P/U and RIH slowly with a 9-5/8" One-trip Whipstock packer assembly with MWD. MWD will be used to align the whipstock to 15° left of highside. Cimulate out freeze protect. Continue RIH. 7. Continue RIH 40' above planned whipstock setting depth. At this time start pumps and pulse MWD to check whipstock face orientation. Using MWD, align whipstock face to 15° left of high side making sure all excess torque is worked out of string. When proper orientation is achieved, set packer. Slack of +_45 klbs to shear whipstock from mill. 8. Test packer to 3500 psi. Displace well with sidetrack drilling fluid. 9. Begin cutting window using only enough WOB and RPM to cut window as smoothly as possible. Continue milling casing and try to make at least 22' of formation, approximately 38' total of milling and drilling from the top of the whipstock. This will allow the full-sized watermelon mill to pass through the window all the way down to the bottom of the window effectively reaming the sidetracked interval. POOH after ensuring the hole is clean and free of metal cuttings. 10. RIH with an 8-1/2" steerable assembly with MWD. Kickoff and directionally drill until well is landed in Zone 4. 11. RIH with 7", 26# liner with liner top hanger/packer. Space liner out with a 150' lap. Cement 7" liner. 12. RIH with 6" drilling assembly. Clean out 7" liner to landing collar. Test liner to 3500 psi. Continue cleaning out 7" liner. Drill ahead in Zone 4, turning well up through Shublik and landing well for a ___300' section in the Sag River. 13. RU Schlumberger. DPC Icg 6" section. R E C E IV E D 14. RIH with 4-1/2", 12.6# solid x slotted liner with a 20' ECP, ES cementer and liner toE,,.~ hanger/packer. Space liner out with a 150' lap. Cement 4-1/2" liner in place. - N~ 011 & Gas Cor~,. ~4~mmi.lon S-22B Permit Information AllCh~e 4 15. 16. 17. 18. 19. 20. RIH with 3-3/4" bit and clean out 4-1/2" liner to landing collar. Test liner to 3500 psi. Finish cleaning out 4-1/2" liner to TD. Displace well to seawater. RIH with 2-3/4" drillpipe conveyed perf guns and-perforate 4-1/2" liner. POOH and lay down guns. RIH with 4-1/2", 12.6#, L-80 completion with SSSV and 7" x 4-1/2" packer. Set TWC valve. Test to 1000 psi. ND BOPs. NU tubing head adapter and tree. Test same to 5000 psi. Pull TWC valve. Freeze protect well. Set packer and test tubing to 4000 psi. Test tubing annulus to 3500 psi. Set BPV. Release rig. Complete appropriate documentation and handover to Production. S-22B Permit Information Page 5 STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMIvIISSION APPLICATION FOR SUNDRY APPROVAL 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing i-'1 Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. KBE = 69.45' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1629' SNL, 793' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval N/A At effective depth 157' SNL, 1221' WEL, SEC. 34, T12N, R12E, UPM At total depth 45' SNL, 1930' WEL, SEC. 34, T12N, R12E, UPM 5. [] Development [] Exploratory [] Stratigraphic [] Service 8. Well Number S-22A 9. Permit Number 93-105 / 93-218 10. APl Number 50- 029-22119-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10070 feet true vertical 9189 feet Effective depth: measured 8253 feet true vertical 7545 feet Casing Length Size Structural Conductor 110' 20" Surface 2655' 13-3/8" Intermediate 9696' 9-5/8" Production Liner Plugs (measured) Junk (measured) 9348'-10070' 8603'-8253' Cemented 250 cuft AS (Approx.) 3723 cuft AS III & II 2020 cuft Class 'G' 300 sx Class 'G' 130 sx Class 'G' MD TVD 110' 110' 2685' 2649' 9726' 8727' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None ,. ? 4 7997 Oil & C-as Cons. CornrnisSior~ Anchorage Packers and SSSV (type and measured depth) None 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation May 1, 1997 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Nam~umber: ~id Nakamura, 564-5606 Prepared By Name/Numbe~. 17. I hereby certify that tl~/~ore/~gQ~in~ i~ ~e and coffect to the best of my knowledge ~ Signed ~~~J ~ p~u,p~ "~ ~ ~tle Senior Ddlling Engineer Terrie Hubble, 564-4628 Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance__ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 Commissioner Date~-/~ ~-? Submit In Triplicate Anadr[i! Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 Well ......... : Si22Bi (Pll) Field ....... i: Prudhoe BaY, S-Pad Computation.: Minimum Curvature Units ........ :' FEET Surface Lat .: 70.35361433 N, Surface Lon~.: 149.03404164 W DIRECTIONAL'WELL PLAN for SHARED SERVICES DRILLING Legal Description Surface ...... : 3651 FSL 4487 FEL S35 T12N R12E UM Tie-in Survey: 4224 FSL 5210 FEL S35 T12N R12E UM Tgt BSL Z4...: 828'FSL 5250 FEL S26 T12N R12E UM Tgt ESL Z4...: 960 FSL 1209 FEL S27 T12N R12E UM T~t BSL Sag..: 1099 FSL 1899 FEL S27 T12N R12E UM Tgt ESL Sag..: 1193 FSL 2184 FEL S27 T12N R12E UM BHL .......... : 1193 FSL 2184 FEL S27 T12N R12E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 618955.00 5979855.00 618222.46 5980416.18 618150.00 5982300.00 616909.00 5982412.00 616217.00 5982541.00 615930.00 5982630.08 615930.00 5982630.00 STATIC~] MEASURED INcLN DIRECTION K-15 TOP UGNU TOP WEST SA/( TIE-IN SURVEY 5388.75 35.77 309.65 TOP OF WINDOW 5395.00 35.77 309.65 PROPOSED WELL PROFILE __ VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 3574.55 3510.00 3624.55 3560.00 4849.55 4785.00 5155.59 5091'.04 807.15 5160.66 5096.11 810.31 Prepared ..... : 07 Mar 1997 Vert sect az.: 279..36 KB elevation.: 64~55 ft Magnetic Dcln: +28,313 (E) Scale Factor.: 0.99991607 Convergence..: +0.90973541 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN COORDINATES-FROM ;G~ASKA Zone 4 TOOL DL/ W~ LLI-!F-'~D X Y FACE 100 .. 572.79 N 723.59 W 618222.46 5980416.18 HS 57S.12 N 726.41 W 618219.62 5980418.47 HS · 0.0~. KOP CURVE 8/100 5400.00 35,77 309.66 TOP COLVILLE/SFD%BEE 5460.21 32.56 316.06 5500.00 30.64 320.91 5600.00 26.79 335.57 5164.72 5100.17 5214.55 5150.00 5248.45 5183.90 5336.24 5271.69 812.83 576.98 N 728.66 W 618217.34 5980420.29 134R 0.0~ 841.03 599.89 N 753.46 W 618192.17 5980442.80 129R 8.00 857.21 615.48 N 767.29 W 618178.10 5980458.16 125R 8.00 888.87 655.83 N 792.72 W 618152.0~ 5980498.11 112R 8.00 O (Anadrill (c)97 S22BIP11 3.0C 5:47 PM P) S.228i ,Di1, STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE 5700.00 24.83 5800.00 25,20 END 8/100 .CURVE 5845.81 26.15 5845.82 26.15 CMl 6693.65 26,15 KUPARUK SANDSTONE 7077.98 LCU 7161.53 KINGAK 8075.01 TJD 8704.42 CURVE 12/100 9223.38 26.1'5 26.15 26.15 26.15 26.15 25.81 25'.74 26.02 30.09 32.11 TJB 9244.68 CGOC 9277.98 9300.00 9400.00 SAG RIVER 9431.13 SHUBLIK TSAD 9485.50 36,23 9500.00 37.44 9584.25 45.01 9600.00 46.52 9700.00 56.49 END 12/100 CURVE INTERMEDIAT CSG PT TGT BSL (ZONE 4) START 10/100 CURVE TGT ESL (ZONE 4) 9800.00 66.92 9900.00 77.60 10000.00 88.39 10075.48 96,55 10075.48 96.55 10075.48 96.55 11329.81 96.55 11329.81 96.55 (Anadrill (c)97 S228IPll 3.0C 5:47 PM P} PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 353.45 5426.40 5361.85 12.42 5517.17 5452.62 20.60 5558.47 5493,92 20.60 5558.48 5493,93 20.60 6319.55 6255,00 20,60 6664.55 6600.00 20.60 6739.55 6675.00 20.60 7559,55 .7495.00 20.60 8124.'55 8060.00 20.60 8590.40 8525.85 14.82 8609.55 '8545.00 5.62 8639.55 8575.00 359.60 8659.37 8594.82 335.39 8747.89 8683.34 , 329.31 8774.55 8710.00 320.29 8819.55 8755.00 318.19 8831.15 8766.60 307.99 8894,55 8830.00 306,39 8905.54 8840~99 297.82 8967.78 8903,23 mm=mmm~m SECTION DEPART 907.19 911.82 909.33 909.33 836,52 803.51 796.34 717.88 663.83 619.2.6 617.91 617.69 618.82 636.62 646.30 667.77 674.44 720.67 730.64 802.77 291,07 9015.16 8950.61 887.67 285.31 9045.61 8981.06 981.62 280.01 9057.80 8993,25 1080.53 276,07 9054.55 8990.00 1155.84 276.07 9054.55 8990,00 1155.84 276.07 9054.55 8990.00 1155.84 276.07 8911.55 8847,00 2399.93 276.07 8911.55 8847,00 2399.93 07 ~ar 1997 Page 2 C00RDiNATES-~ROM WELLHEAD 697.27 N 738.99 N 757.97 N 757.97 N 1107.69 N 1266.23 N 1300,69 N 1677.49 N 1937.12 N 21'51,.18 N ALASKA Zone 4 X Y mmuz=um~m m{mmlmmmmm 804.45 W 618139.65 5980539,36 802.26 W 618141,17 5980581.10 796,61 W 6181~6.52 5980600.16 796,61 W 6181~6.52 5980600.16 665,14 W 618272.42 5980951.90 605.54 W 618329.485981111.35 '592.59W 618341.89 5981146.01 450.93 W 618477.53 598'1524.98 353.33 W 272.86 W 618648.05 5982001.40 TOOL DL/ FACE 100 96R 8.00 79R 8.00 HS 8.00 HS 8.00 HS 0.00 HS HS ~S 6185~0.99 5981786.10 HS 0.00 0.00 0,00 0.00 . 100L 0.00 2160.06 N 270.02 W 618650.74 5982010,32 95L 12.00 2174.27 N 267.46 W 618653.08 5982024,56 87L 12.00 2183.86 N 267.02 W 618653.36 5982034.16 81L 12.00 2228.75 N 277.65 W 618642.025982078.87 60L 12,00 2242.96 N 285.13 W 618634'.32. 5982092,97 55L 12.00 2267.78 N. 302.79 W 618636.27 5982117,49 476 12.00 2274.36 N 308.47 W 6186~0.49 5982123.98 46L 12.00 2311,88 N 349.13 W 618569.24 5982160.85 38L 12,00 2318.70 N 358.12 W 618560,14 5982167.52 37L 12,00 2359,82 N 424,44 W 618493.19 5982207.59 31L 12.00 2395.95 N 504.52 W 618412.54 5982242.43 28L 12.00 2425.48 N 594.88 W 618321,74 5982270.53 26L 12.00 2447.14 N 691.55 W 618224,74 5982290.65 26L 12.00 2457,68 N 766.14 W 618150.00 5982300.00 HS 12.00 2457.68 N 766.14 W '618150,00 5982300.00 HS 12.00 245?.68 N 766.14 N 618150.00 5982300.00 HS 12.00 '2589.38 N 2005.31 N 616909.00 5982412.00 77R 0.00 2589.38 N 2005.31 W 616909.00 5982412.00 77R 0,00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY _ S-22Bi :Pll. STATION IDENTIFICATION END 10/100 CURVE START 10/100 CURVE END 10/100 CURVE TGT BSL (SAG) PRODUCTION LINER PT TD TGT ESL (SAG) TOP BOT TOP ZONE 3 MEASURED INCLN DEPTH ANGLE 11381.31 97.64 11936.28 97,64 12000.00 92.94 12039.72 90,00 12039.?2 90,00 12340.23 90.00 12340.23 90.00 12340.23 90.00 COWC PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 281.14 8905.119 8840.64 281.14 8831.44 8766.89 285.46 8825.57 ,8761.02 288,14 8824.55 8?60.00 288.14 8824.55 8760.00 288.14 288.14 288.14 88.24.55 8760.00 8824.55 8760.00 8824.55 8760.00 9059.55 8995.00 9062.55 8998.00 9069.55 9005.00 .SECTION DEPART 2451.02 3000.80 3064.07 3103.44 3103,44 3400.43 3400.43 3400.43 ~7 Mar 1997 COORDINATES-FROM WELLHEAD 2597.02 N 2055.83 W 2703.29 N 2595.51 W 2717.89 N 2657.23 W 2729.36 N 2695.23 W 2729.36 N 2695.23 W 2822.92 N '2980.81 W 2822.92 N 2980,81 W 2822.92 N 2980.81 W Page 3 ----~m~tmmmmmm ALASKA Zone 4 ¥ TOOL DL/ FACE 100 616858.37 5982418.84 616317.12 5982516.51 616255.18 5982530.13 616217.00 5982541.00 616217.00 5982541.00 HS 10.00 137R 0.00 138R 10.00 HS 10.00 HS 10.00 615930.00 5982630.00 0.00 615930.00 5982630.00 0.00 615930.00 5982630.00 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN . (Anadrill (c)97 S22BIP11 3.'0C 5:47 PM P) Ma~-lO-97 O9:26A Anadrj~l DPC ~07~44 2160 P.Og SHARED SERVICES DRILLING iii ii i ii i · ¢ - O--CCDI ~li; I [ I VERTICAL SECTION VIEW jPPD,---'-'- . . T¥~ Scale' a inch-- ~00 feet ....... Dep Scale.' 1 inch : t200 feet 1 IFOR PER,~ITq'ING.~.__I: Drawn ..... '07 Mar ~997 ..................... : .~'~Y_.. ~ ~ .... ._ ~ .PLAN CLt.[ ¢ _ i ~n¢¢~]] SchYumberger :- Marker Identifkcation MD 8KB SECTN INCLN .) A) TIE-IN SURVEY 5389 5t56 807 35.77 ' B) TOP 0F WINDOW 5395 516~ 810 35.77 C) K0P CURVE B/100 5400 5165 813 35.77 .... : .... ' -'-' .......... D) END 8/i00 CURVE 5846 5558 909 . 26.15 ; E) CURVE' t2/~O0 9223 8590 6~9 26.15 F] END ~2/t00 CURVE 10075 9055 1156 96.55 .......... ]' G) INTERMEDIAT CSG PT 10075 9055 ~t56 96.55 ~~~1 - H) TGT BSL (ZONE 4) ~ ~0075' '9055 ~156 96.55 I : I) START 10/~00 CURVE ti330 8912 2~00 96.55 i J) TGT ESL (ZONE 4) ~*~ ~1330 8912 2400 96.55 ......... ' ..... ~ .... K) END ~0/~00 CURVE 1~38~. 8905 245~ 97.64 L) START tO/JOO CURVE ~936 883~ 300t 97.6~ N) END ~O/tO0 CURVE 12040 8825 3t03 90.00 N) TGT BSL (SAG) ~,N~ ~2040 8825 3103 90,00 - "~ .- - O) PRODUCTION LINER PT 12340 8825 3400 90.00 ~r~¢ '4~ P) TO ~2340 8825 3400 90.00 ' ~d ~kT~-~ 9) TGT ESL (SAG) ~ ~2340 8825 3400 90.00 ,. ............ . .. -~- ,~- / - ~:t~: ................... I~=~=~==~ =~c=Icc===c~ :::: . ............ ........ I ' I . / . 600 1200 t800 (~a~rill (c197 $228IPJ~ 3.0C 5:55 Pt4 P) 2400 3000 3600 4200 .4e00 Section Departure 5400 B000 6600 7200 '7800 Ma~-10-97 09:27A Anadr~l DPC 907 ~44 2160 P.11 SHARED i ! Marker Ident i f ication A) TIE-IN SURVEY 8l TOP OF WINDOW Ci KOP CURVE 8/100 0] END 8/100 CURVE E) CURVE 12/100 F) END 12/100 CURVE G) INTERMEDIAT CSG PT H) TG'r BSL (ZONE ,4) I) STAFIT t0/500 CURVE J) TGT ESL (ZONE 4) K) END ~0/100 CURVE- L)' START lO/lDO CURVE M) END t0/100 CURVE N) MD N/S 5389 573 N 5395 575 N 5400 577 N 5846 758 N 9223 2151N 10075 2458 N ~0075 2458 N 50075 2458 N 1~330 2589 N ~330 2589 N ~381 2597 N I1936 2703N 12040 2729 N SERV'ICES DRILLING E/W 726 729 797 273 766 786 766 2005 2005 2056 2596 2695 ii m S-22Bi (P11) PLAN VIEW CLOSURE · 4105 feet at Azimuth 3~3.44 DECLINATION.' +28.313 (E) SCALE ' 1 inch = 500 feet DRAWN ' 08 Mar 1997 TGT 85L {SAG) ~*~ 12040 2729. ~95. 'Anadrj ]] $ch]umbe£ger O) PRODUCTION LINER PI 12340 2823 N 2981 W ..... P) TO 12340 2883 N 298~ W I "i'-' t3) ~o-~-~-S{:--(SAG)-..~-~w~ ~23~0 .... 2023 N .... 2! ~BI .W ................ ~ ......... -- j 'FI3R PERM 7TII~G X _. ' ~ ! - P'~xN ~-L, ...... - ---¢- .x ..... .- I ~ I ~ j , KB i j ,' j [ · , 3250 3000 2750 2500 2250 2000 1750 15~ I250 1000 750 500 250 0 250 <- WEST' EAST -> (~adPi11 (c)g7 S2~IP$~ 3.06 4:~ ~ P) H 1 07070 /'~,', ~,':~,~'/ / ,~'-~'o~'ol $6! 5201 O0 VENDO~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. WELL PERMIT CHECKLISTco , ,, ADMINISTRATION ENGINEERING WELL NAME S-- ~-~2--~ PROGRAM: expD dev ~ re se wellbore seg~ ann disp para req~ 1. Permit fee attached ................... /~ ~ N 2. Lease number appropriate ................ I Y ~ N 3. Unique well name and number ............... I¥ i N 4. Well located in a defined pool ............. pY ~ N 5. Well located proper distance from drlg unit boundary.. FY I N 6. Well located proper distance from other wells ..... t Y I N 7. Sufficient acreage available in drilling unit ..... t Y I N 8. If deviated, is wellbore plat included ........ t Y ~ N 9. Operator only affected party .............. I'Y I N 10. Operator has appropriate bond in force ......... I.Y ~ N 11. Permit can be issued without conservation order .... t Y I N 12. Permit can be issued without administrative approval..I.Yi N 13~d before 15-day wait.' ...... Y N REMARKS .......... 14. Conductor string provided ................ Y N) 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ........ . ............. ~,/ N 26. BOPE press rating adequate; test to ~~ psig.~? N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~/__ 31. Data presented on potential overpressure zones ..... Y/N ~ .~ 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . ./6 . . Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: BEW~~(~ DWJ~ JDH~ mca i~!/'-~ t ,q >. HOWldlf - A:\FORMS%cheklist rev 01197 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . . . ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAM~ : S-22B FIELD NAFi~ : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA APINUM~ER : 50-029-22119-02 REFERENCE NO : 97546 Date ~)1-13 ~.-OI LIS Tape Verificatio~, Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/12/ 1 ORIGIN : FLIC REEL NA~E : 97473 CONTINUATION # : PREVIOUS REEL : co~Fr : B.P. EXPLORATION, PRUDHOE BAY S-22B, API #50-029-22119-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/12/ 1 ORIGIN : FLIC TAPE NA~iE : 97473 CONTINUATION # : 1 PREVIOUS TAPE : COA~Ff : B.P. EXPLORATION, PRUDHOE BAY S-22B, API #50-029-22119-02 TAPE HEADER PRUDHOE BAY MWD LOGS WELL NA~E : API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 97473 BARNEY JACKSON WELL CASING RECORD 1ST STRING 2ND STRING S-22B 500292211902 B.P. EXPLORATION SCHLUmbERGER WELL SERVICES 12-NOV-97 BIT RUN 2 BIT RUN 3 .................. 35 12N 12E 64.55 64.55 29.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8c500 7.000 9445.0 6.000 LIS Tape Verificatio~ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 3RD STRING PRODUCTION STRING Well drilled 26-JUN through 08-JUL-97 with GR and ARCS/ IMPULSE. Ail data was collected in seven bit runs. No depth shifts were applied to this data as per Troy Weiss of BP. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED f4~RGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUA~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 6791.0 12227.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (FiEAS~DEPTH) BASELINE DEPTH $ FIERGED DATA SOURCE LDWG TOOL CODE $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. f4F~RGE TOP FiERGE BASE 1 6791.0 11193.0 2 9410.0 11715.0 3 9548.0 9853.0 4 9798.0 10030.0 5 9986.0 11252.0 6 11193.0 11817.0 7 11715.0 12227.0 This is the merged and edited data from the GR and ARC5 and IMPULSE logged 26-Jun to 08-JUL-97. No depth shifts were applied to this data as per Troy Weiss of BP. The LIS Tape Verificatio~ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: data includes both Phase Shift and Attenuation curves using the LDWGmnemonics as provided by Dave Douglas. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT ROP f4WD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET f4WD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RP3CfMWD OP~4M O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD O~ O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 RA3~f~IWD OH~iM O0 000 O0 0 1 1 1 4 68 0000000000 RAX f4WD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RAM MWD OH~M O0 000 O0 0 1 1 1 4 68 0000000000 RA1) ~ OH~q O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verificatio~ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: ** DATA ** DEPT. 12227.000 ROP.MWD 38.010 FET.MWD -999.250 GR.MWD RPX~.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM.MWD RPD.MWD -999.250 RAX~f. MWD -999.250 RAX.MWD -999.250 RAM.MWD RAD.MWD -999.250 DEPT. 12000.000 ROP.MWD RPX~f. MWD 15.000 RPX. MWD RPD.MWD 19.250 RA3Of. MWD RAD.MWD 15.570 DEPT. 11600.000 ROP.MWD RPX~.MWD 47.520 RPX.MWD RPD.MWD 54.630 RA3Of. MWD RAD.MWD 63.520 DEPT. 11200.000 ROP.MWD RPX~.MWD 3.890 RPX. MWD RPD.MWD 9.650 RAXX.MWD RAD.MWD 14.710 DEPT. 10800.000 ROP.MWD RPX~.MWD 3.620 RPX.MWD RPD.MWD 4.200 RAXX. MWD RAD.MWD 4.760 DEPT. 10400.000 ROP.MWD RPXX.MBrD 5.190 RPX.MWD RPD.MWD 5.130 RAXX.MWD RAD.MWD 4.590 DEPT. 10000.000 ROP.MWD RPX~.MWD 1.470 RPX.MWD RPD.MWD 2.670 RAX~.MWD RAD.MWD 3.110 DEPT. 9600.000 ROP.MWD RPX~.MWD 8.690 RPX.MWD RPD.MWD 20.100 RAXX.MWD RAD.MWD 17.180 136. 360 FET.MWD 15. 810 RPS.MWD 11. 030 RAX. MWD 90.000 FET.MWD 47.520 RPS.MWD 300.000 RAX.MWD 31.690 FET.MWD 4.700 RPS.MWD 3.770 RAX.MWD 121. 630 FET.MWD 3. 810 RPS.MWD 3. 980 RAX.MWD 25.830 FET. MWD 5.190 RPS.MWD 4. 730 RAX . MWD 68. 970 FET.MWD 1. 800 RPS.MWD 2.430 RAX. MWD 62.940 FET.MWD 11.690 RPS.MWD 11.790 RAX.MWD 0.603 18.250 14.030 1. 027 49.250 88. 620 0.578 5.550 5.350 O. 641 3. 940 4. 290 O. 928 5.170 4. 650 O. 467 2.170 2. 710 1.291 15.780 15.170 GR .MWD RPM.MWD RAM. MWD GR. MWD RPM. MWD RAM. MWD GR .MWD RPM. MWD RAM. MWD GR. MWD RPM. MWD RAM. MWD GR. MWD RPM. MWD RAM. MWD GR. MWD RPM. MWD RAM. MWD GR .MWD RPM. MWD RAM. MWD DEPT. 9200.000 ROP.MWD 63.620 FET.MWD -999.250 GR.MWD RPX~.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RAXX.MWD -999.250 RAX.MWD -999.250 RAM. MWD RAD.MWD -999.250 DEPT. 8800.000 ROP.MWD 74.700 FET.MWD -999.250 GR.MWD RPX~.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM.MWD RPD.MWD -999.250 RAX~.MWD -999.250 RAX.MWD -999.250 RAM.MWD RAD.MWD -999.250 -999.250 -999.250 -999.250 44.990 20.090 16.450 83.390 52.150 70.710 46.110 6. 990 11. 720 21. 690 4. 050 4. 630 34.540 5.150 4.630 25.710 2. 450 3. 020 21.210 19.110 18.230 128.680 -999.250 -999.250 91.840 -999.250 -999.250 LIS Tape Verificatio~. Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: DEPT. 8400.000 ROP.MWD 209.440 FET.MWD -999.250 GR.MWD RPX~.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM.MWD RPD.MWD -999.250 RAX~.~ -999.250 RAX.MWD -999.250 RAM.MWD RAD.MWD -999.250 DEPT. 8000.000 ROP.MWD 116.890 FET.MWD -999.250 GR.MWD RPX~i. BIW-D -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. IVlWD RPD.MWD -999.250 RAIOf. MWD -999.250 RAX.MWD -999.250 RAM.MWD RAD.MWD -999.250 DEPT. 7600.000 ROP.MWD 124.150 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RAXX.MWD -999.250 RAX.MWD -999.250 RAM. MWD RAD.MWD -999.250 DEPT. 7200.000 ROP.MWD 191.480 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. f4WD RPD.MWD -999.250 RAXX.f4WD -999.250 RAX. MWD -999.250 RAM. MWD RAD.MWD -999.250 DEPT. 6800.000 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD RP302.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RAX3f.~ -999.250 RAX.f4WD -999.250 RAM. MWD RAD.MWD -999.250 DEPT. 6791.500 ROP.MWD -999.250 FET.MWD -999.250 GR.MWD RPX~.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.i%IWD -999.250 RAX~.MWD -999.250 RAX.MWD -999.250 RAM. MWD RAD.I%fWD -999.250 78.010 -999.250 -999.250 114.560 -999.250 -999.250 104.020 -999.250 -999.250 92.550 -999.250 -999.250 99.820 -999.250 -999.250 103.210 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ ! MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verificatl=__ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: FILE FILE NI]I4~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREPIFIVT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH FfWD 6791.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (ME~fORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9452.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~IA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0~) AT TEMPERATURE (DEGF): MUD AT MEASErRED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG T~PERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 08-JUL-97 5.0 34 5.0 34 _ MEMORY 12227.0 6791.0 12227.0 23.0 35.8 TOOL NUFZBER ........... CDR 751 8.500 9445.0 QUIKDRILL/SEAWATER 8.80 O. 140 70.0 LIS Tape Verificat~_. Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: TOOL STANDOFF (IN) EWR FREQUENCY (HZ) REMARKS: RUN 1 - 6856'-9452' 8.5" BS GR RUN 2 - 9452'-9630' 6" BS ARC5 RUN 3 - 9630'-9853' 6" BS ARC5 RUN 4 - 9853'-10030' 6" BS ARC5 RUN 5 - 10030'-11252' 6" BS ARC5 RUN 6 - 11252'-11817' 6" BS ARC5 RUN 7 - 11817'-12227' 6" BS ARC5 DATA FROM DOWNHOLE iVlEMORY, V5.0 34 SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verificat~__ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: DEPT. 9452.000 ROP.LW1 60.820 GR.LW1 -999.250 DEPT. 9200. 000 ROP.LW1 63. 620 GR. LW1 128. 680 DEPT. 8800. 000 ROP. LW1 74. 700 GR. LW1 91. 840 DEPT. 8400. 000 ROP. LW1 209.440 GR. LW1 78. O10 DEPT. 8000. 000 ROP. LW1 116. 890 GR. LW1 114. 560 DEPT. 7600.000 ROP.LW1 124.150 GR.LW1 104.020 DEPT. 7200.000 ROP.LW1 191.480 GR.LW1 92.550 DEPT. 6791. 500 ROP. LW1 -999. 250 GR. LW1 103.210 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUPIBER: 2 DEPTH INC~: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9410.0 9630.0 LIS Tape Verificata. Listing Schlumberger Alaska Computing Center i-DEC-1997 14:51 PAGE: $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (FIE~ORY or REAL-TIA~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 08-JUL-97 5.0 34 5.0 34 f4~4ORY 12227.0 6791.0 12227.0 23.0 35.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ TOOL NUMBER ARC5 016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 9445.0 BOREHOLE CONDITIONS MUD TYPE: ~ DENSITY (LB/G): MUD VISCOSITY (S) : FiUD PH: ~ CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHPI~) AT TEMPERATURE (DEGF): MUD AT F1EASURED TE~IPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): QUIKDRILL/SEAWATER 8.80 0.140 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RUN 1 - 6856'-9452' 8.5" BS GR RUN 2 - 9452'-9630' 6" BS ARC5 RUN 3 - 9630'-9853' 6" BS ARC5 RUN 4 - 9853'-10030' 6" BS ARC5 RUN 5 - 10030'-11252' 6" BS ARC5 RUN 6 - 11252'-11817' 6" BS ARC5 RUN 7 - 11817'-12227' 6" BS ARC5 DATA FROM DOWNHOLE M~IORY, V5. 0 34 SOFTWARE LIS Tape Verificati~ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 10 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP5 LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 TAB LW2 P!R O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 H~ O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 PIOH LW2 OI-11v~ O0 000 O0 0 3 1 1 4 68 0000000000 P16H LW2 OHlVl~ O0 000 O0 0 3 1 1 4 68 0000000000 P22H LW2 OHlVl~I O0 000 O0 0 3 1 1 4 68 0000000000 P28H LW2 OHIVl~ O0 000 O0 0 3 1 1 4 68 0000000000 P34H LW2 OHl~Vl O0 000 O0 0 3 1 1 4 68 0000000000 AiOH LW2 OPiM~ O0 000 O0 0 3 1 1 4 68 0000000000 A16H LW2 OHlVi~l O0 000 O0 0 3 1 1 4 68 0000000000 A28H LW2 O~ O0 000 O0 0 3 1 1 4 68 0000000000 A34H LW2 OHMPI O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verificati~ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 11 DEPT. 9630. 000 ROPS.LW2 GR.LW2 -999.250 PiOH. LW2 P28H. LW2 -999. 250 P34H. LW2 A28H. LW2 -999. 250 A34H. LW2 DEPT. 9600. 000 ROP5.LW2 GR.LW2 -999.250 PiOH. LW2 P28H. LW2 -999.250 P34H. LW2 A28H. LW2 -999. 250 A34H. LW2 DEPT. 9453. 000 ROP5. LW2 GR. LW2 - 999.250 P1 OH. LW2 P28H. LW2 -999. 250 P34H. LW2 A28H. LW2 -999. 250 A34H. LW2 64. 870 TAB. LW2 -999.250 P16H. LW2 -999. 250 A1 OH. LW2 - 999. 250 62. 940 TAB. LW2 - 999. 250 P16H. LW2 -999.250 AiOH. LW2 -999.250 -999.250 TAB.LW2 -999.250 P16H. LW2 -999.250 AiOH. LW2 -999.250 -999. 250 TABR . LW2 -999. 250 P22H. LW2 -999. 250 A16H. LW2 - 999.250 TABR. LW2 - 999. 250 P22H. LW2 -999. 250 A16H. LW2 -999. 250 TABR. LW2 -999. 250 P22H. LW2 -999. 250 A16H. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREFiENT: 0.5000 FILE SUP~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9548.0 9853.0 $ LIS Tape Verificati= Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 12 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~iEMORY or REAL-TIf4E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (PT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 08-JUL-97 5.0 34 5.0 34 _ MEMORY 12227.0 6791.0 12227.0 23.0 35.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ TOOL NUP~ER ........... ARC5 063 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 9445.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OI4I~lP~) AT TEMPERATURE (DEGF): MUD AT f4EAStrRED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): QUIKDRILL/SEAWATER 8.80 0.140 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 RUN 1 - 6856'-9452' 8.5" BS GR RUN 2 - 9452'-9630' 6" BS ARC5 RUN 3 - 9630'-9853' 6" BS ARC5 RUN 4 - 9853'-10030' 6" BS ARC5 RUN 5 - 10030'-11252' 6" BS ARC5 RUN 6 - 11252'-11817' 6" BS ARC5 RUN 7 - 11817'-12227' 6" BS ARC5 DATA FROM DOWNHOLE F~ORY, VS.0 34 SOFTWARE _ $ LIS Tape Verificati= ~isting Schlumberger Alaska Computing Center 1~DEC-1997 14:51 PAGE: 13 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RBCORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAI~E SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MODNUM~ SAMP ELE~4 CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT ROP5 LW3 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 TAB LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 TABR LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 PiOH LW3 OHT4~ O0 000 O0 0 4 1 1 4 68 0000000000 P16H LW3 OI-iF~ O0 000 O0 0 4 1 1 4 68 0000000000 P22H LW3 O~ O0 000 O0 0 4 1 1 4 68 0000000000 P28H LW3 OPiM~ O0 000 O0 0 4 1 1 4 68 0000000000 P34H LW3 OHlVi~ O0 000 O0 0 4 1 1 4 68 0000000000 AiOH LW3 OPiFI~ O0 000 O0 0 4 1 1 4 68 0000000000 A16H LW3 OHI~M O0 000 O0 0 4 1 1 4 68 0000000000 A28H LW3 OHI~IPI O0 000 O0 0 4 1 1 4 68 0000000000 A34H LW3 O~ O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** LIS Tape Verificati~ ~isting Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 14 DEPT. 9853 . 000 ROP5 .LW3 GR.LW3 -999.250 PtOH.LW3 P28H. LW3 -999.250 P34H. LW3 A28H~ LW3 -999 . 250 A34H. LW3 DEPT. 9600 . 000 ROPS. LW3 GR. LW3 21.210 P1 OH. LW3 P28H. LW3 19.110 P34H. LW3 A28H.LW3 18.230 A34H.LW3 DEPT. 9586. 000 ROPS.LW3 GR.LW3 -999.250 PiOH. LW3 P28H. LW3 2. 960 P34H. LW3 A28H. LW3 12.290 A34H. LW3 -999.250 TAB.LW3 -999.250 P16H. LW3 -999.250 AiOH. LW3 -999.250 -999.250 TAB.LW3 8.690 P16H. LW3 20.100 AIOH. LW3 17.180 -999. 250 TAB. LW3 2.110 P16H. LW3 3 . 040 AIOH. LW3 9.510 -999.250 TABR.LW3 -999.250 P22H.LW3 -999.250 A16H.LW3 1.291 TABR. LW3 11. 690 P22H.LW3 11 . 790 A16H. LW3 -999. 250 TABR. LW3 2. 360 P22H. LW3 3. 080 A16H.LW3 -999.250 -999.250 -999.250 1.233 15.780 15.170 1.241 2.700 4. 420 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9798.0 10030.0 $ LIS Tape Verificatl~ Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 15 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIbIE) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHt~4) AT TEMPERATURE (DEGF) : MUD AT MEAS~ TEMPERATURE (MT): MUD AT MAX CIRCTU_~TIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 08-JUL-97 5.0 34 _ 5.0 34 _ MEMORY 12227.0 6791.0 12227.0 23.0 35.8 RUN RUN RUN RUN RUN RUN RUN 1 - 6856'-9452' 8.5" BS GR 2 - 9452'-9630' 6" BS ARC5 3 - 9630'-9853' 6" BS ARC5 4 - 9853'-10030' 6" BS ARC5 5 - 10030'-11252' 6" BS ARC5 6 - 11252'-11817' 6" BS ARC5 7 - 11817'-12227' 6" BS ARC5 TOOL NUMBER ARC5 022 8.500 9445.0 QUIKI)RILL/SEAWATER 8.80 O. 140 70.0 DATA FROM DOWNHOLE MEMORY, VS. 0 34 SOP~WARE _ $ 20000 LIS Tape Verificatiu ~isting Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 16 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 ROP$ LW4 F/HR O0 000 O0 0 5 1 1 4 68 0000000000 TAB LW4 HR O0 000 O0 0 5 1 1 4 68 0000000000 TABR LW4 HR O0 000 O0 0 5 1 1 4 68 0000000000 GR LW4 GAPI O0 000 O0 0 5 1 1 4 68 0000000000 PiOH LW4 OH~M O0 000 O0 0 5 1 1 4 68 0000000000 P16H LW4 OHI~ O0 000 O0 0 5 1 1 4 68 0000000000 P22H LW4 OH~ O0 000 O0 0 5 1 1 4 68 0000000000 P28H LW4 Oh?4~ O0 000 O0 0 5 1 1 4 68 0000000000 P34H LW4 OH~ O0 000 O0 0 5 1 1 4 68 0000000000 AIOH LW4 OH~M O0 000 O0 0 5 1 1 4 68 0000000000 A16H LW4 OH~f O0 000 O0 0 5 1 1 4 68 0000000000 A28H LW4 OH~4~ O0 000 O0 0 5 1 1 4 68 0000000000 A34H LW4 OH~4~ O0 000 O0 0 5 1 1 4 68 0000000000 * * DA TA * * LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-D~C-1997 14:51 PAGE: 17 DEPT. 10030.000 ROPS.LW4 GR.LW4 -999.250 PiOH. LW4 P28H. LW4 -999.250 P34H.LW4 A28H. LW4 -999.250 A34H.LW4 DEPT. 10000. 000 ROPS.LW4 GR.LW4 -999.250 PiOH.LW4 P28H. LW4 -999.250 P34H.LW4 A28H. LW4 -999. 250 A34H. LW4 DEPT. 9853. 000 ROPS. LW4 GR. LW4 25. 760 P1 OH. LW4 P28H. LW4 2. 980 P34H. LW4 A28H. LW4 3.470 A34H. LW4 -999. 250 TAB. LW4 -999.250 P16H.LW4 - 999. 250 A1 OH. LW4 -999. 250 68.970 TAB.LW4 -999.250 P16H. LW4 -999.250 AIOH. LW4 -999.250 -999.250 TAB.LW4 1.730 P16H. LW4 3.100 AiOH. LW4 3.500 -999. 250 TABR. LW4 -999.250 P22H.LW4 - 999. 250 A16H. LW4 -999. 250 TABR. LW4 -999. 250 P22H. LW4 -999.250 A16H. LW4 4.926 TABR. LW4 2.240 P22H. LW4 2. 490 A16H.LW4 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4. 268 2. 730 2. 980 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3PIBER 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9986.0 11252.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 18 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME) TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS M[rD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHN~) AT TENPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TI~4PERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 08-JUL-97 5.0 34 5.0 34 _ MEMORY 12227.0 6791.0 12227.0 23.0 35.8 TOOL NUMBER ARC5 022 8.500 9445.0 QUIKDRILL/SEAWATER 8.80 0.140 70.0 RUN1 - 6856'-9452' 8.5" BS GR RUN2 - 9452'-9630' 6" BS ARC5 RUN 3 - 9630'-9853' 6" BS ARC5 RUN4 - 9853'-10030' 6" BS ARC5 RUN5 - 10030'-11252' 6" BE ARC5 RUN 6 - 11252'-11817' 6" BS ARC5 RUN7 - 11817'-12227' 6" BS ARC5 DATA FROM DOWNHOLE M~2~ORY, V5. 0 34 SOFTWARE _ $ 20000 LIS Tape Verificatio._ ~isting Schlumberger Alaska Computing Center 1-DEC-1997 1~51 PAGE: 19 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUFIB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ArO14~ SAMP ELEM CODE (HEX) O0 000 O0 0 6 1 1 4 68 0000000000 DEPT FT ROP5 LW5 F/HR O0 000 O0 0 6 1 1 4 68 0000000000 TAB LW5 HR O0 000 O0 0 6 1 1 4 68 0000000000 TABR LW5 HR O0 000 O0 0 6 1 1 4 68 0000000000 GR LW5 GAPI O0 000 O0 0 6 1 1 4 68 0000000000 PiOH LW5 OH~M O0 000 O0 0 6 1 1 4 68 0000000000 P16H LW5 OPE~I O0 000 O0 0 6 1 1 4 68 0000000000 P22H LW5 OH~ O0 000 O0 0 6 1 1 4 68 0000000000 P28H LW5 OH~ O0 000 O0 0 6 1 1 4 68 0000000000 P34H LW5 OH~ O0 000 O0 0 6 1 1 4 68 0000000000 AiOH LW5 OH~M O0 000 00 0 6 1 1 4 68 0000000000 A16H LW5 OH~E4 O0 000 O0 0 6 1 1 4 68 0000000000 A28H LW5 OP~4~ O0 000 O0 0 6 1 1 4 68 0000000000 A34H LW5 OH~4 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification misting Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 2O DEPT. 11252.000 ROPS.LW5 GR.LW5 -999.250 PIOH. LW5 P28H. LW5 -999.250 P34H. LW5 A28H. LW5 -999.250 A34H. LW5 DEPT. 11200.000 ROP5.LW5 GR.LW5 46.110 PiOH. LW5 P28H. LW5 6.990 P34H. LW5 A28H. LW5 11.720 A34H. LW5 DEPT. 10800. 000 ROPS. LW5 GR . LW5 21 . 690 P1 OH. LW5 P28H. LW5 4. 050 P34H. LW5 A28H. LW5 4. 630 A34H. LW5 DEPT. 10400.000 ROP5.LW5 GR.LW5 34.540 PiOH. LW5 P28H. LW5 5.150 P34H. LW5 A28H. LW5 4.630 A34H.LW5 DEPT. 10000.000 ROP5.LW5 GR.LW5 25.710 PiOH. LW5 P28H. LW5 2.450 P34H. LW5 A28H. LW5 3.020 A34H. LW5 DEPT. 9983. 000 ROP5. LW5 GR. LW5 19.280 P1 OH. L W5 P28H. LW5 -999. 250 P34H. LW5 A28H. LW5 -999.250 A34H. LW5 8.100 TAB.LW5 -999.250 P16H. LW5 -999.250 AiOH. LW5 -999.250 31. 690 TAB. LW5 3. 890 P16H. LW5 9.650 A1 OH. LW5 14. 710 121.630 TAB. LW5 3 . 620 P16H. L W5 4.200 A1 OH. LW5 4. 760 25.830 TAB.LW5 5.190 P16H. LW5 5.130 AIOH. LW5 4.59O -999.250 TAB.LW5 1.470 P16H. LW5 2.670 AiOH. LW5 3.110 -999.250 TAB.LW5 -999.250 P16H. LW5 -999.250 AiOH. LW5 -999.250 -999. 250 TABR. LW5 -999. 250 P22H. LW5 - 999.250 A16H. LW5 O . 578 TABR . LW5 4. 700 P22H.LW5 3. 770 A16H. LW5 0. 641 TABR. LW5 3.810 P22H. LW5 3 . 980 A16H. LW5 0.928 TABR. LW5 5. 190 P22H. LW5 4. 730 A16H.LW5 O. 467 TABR.LW5 1. 800 P22H. LW5 2. 430 A16H. LW5 0.033 TABR.LW5 -999.250 P22H. LW5 -999.250 A16H.LW5 -999.250 -999.250 -999.250 3.055 5.550 5.350 0. 603 3. 940 4.290 O. 819 5.170 4. 650 0.108 2.170 2. 710 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NANIE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAlViE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification. misting Schlumberger Alaska Computing Center 1~DEC-1997 14:51 PAGE: 21 FILE HEADER FILE NUFIBER 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREM~lVT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 11193.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL~TIf4E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11817.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 08-JUL-97 5.0 34 _ $.0 34 MEMORY 12227.0 6791.0 12227.0 23.0 35.8 TOOL ~ER ARC5 022 8.500 9445.0 QUIKDRILL/SEAWATER 8.80 0.140 70.0 LIS Tape Verification Disting Schlumberger Alaska Computing Center I-DEC-1997 14:51 PAGE: 22 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: RUN 1 - 6856'-9452' 8.5" BS GR RUN 2 - 9452'-9630' 6" BS ARC5 RUN 3 - 9630'-9853' 6" BS ARC5 RUN 4 - 9853'-10030' 6" BS ARC5 RUN 5 - 10030'-11252' 6" BS ARC5 RUN 6 - 11252'-11817' 6" BS ARC5 RUN 7 - 11817'-12227' 6" BS ARC5 DATA FROM DOWN-HOLE AiEMORY, VS~ 0 34 SOFTWARE _ $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 ROP5 LW6 F/HR O0 000 O0 0 7 1 1 4 68 0000000000 TAB LW6 HR O0 000 O0 0 7 1 1 4 68 0000000000 TABR LW6 HR O0 000 O0 0 7 1 1 4 68 0000000000 GR LW6 GAPI O0 000 O0 0 7 1 1 4 68 0000000000 PiOH LW6 OHMM O0 000 O0 0 7 1 1 4 68 0000000000 P16H LW6 OP~4M O0 000 O0 0 7 1 1 4 68 0000000000 P22H LW6 OH~f O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verificatio~ Disting Schlumberger Alaska Computing Center i-DEC-1997 14:51 PAGE: 23 NAME SERVUNIT SERVICE API API API API FILE NIJM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) P28H LW6 OH~ O0 000 O0 0 7 1 1 4 68 0000000000 P34H LW6 OH~ff~ O0 000 O0 0 7 1 1 4 68 0000000000 AiOH LW6 OH~M O0 000 O0 0 7 1 1 4 68 0000000000 A16H LW6 OH~ O0 000 O0 0 7 1 1 4 68 0000000000 A28H LW6 Ot{~ O0 000 O0 0 7 1 1 4 68 0000000000 A34H LW6 OHT~ O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11817.000 ROPS.LW6 4252131.000 TAB.LW6 -999.250 TABR.LW6 GR.LW6 -999.250 PiOH. LW6 -999.250 P16H. LW6 -999.250 P22H.LW6 P28H. LW6 -999.250 P34H. LW6 -999.250 AiOH.LW6 -999.250 A16H.LW6 A28H. LW6 -999.250 A34H. LW6 -999.250 DEPT. 11600. 000 ROPS. LW6 90. 000 TAB. LW6 1. 027 TABR. LW6 GR.LW6 83.390 PIOH. LW6 47.520 P16H. LW6 47.520 P22H.LW6 P28H.LW6 52. 150 P34H. LW6 54. 630 AIOH. LW6 300. 000 A16H.LW6 A28H.LW6 70. 710 A34H. LW6 63.520 DEPT. 11202.000 ROPS.LW6 -999.250 TAB.LW6 -999.250 TABR.LW6 GR.LW6 -999.250 PiOH. LW6 2.730 P16H. LW6 3.390 P22H.LW6 P28H.LW6 4.610 P34H. LW6 4.330 AIOH. LW6 3.460 A16H. LW6 A28H. LW6 9.300 A34H. LW6 10.330 -999.250 -999.250 -999.250 O. 822 49.250 88. 620 3.274 4.230 4. 820 ** END OF DATA ** **** FILE TRAILER **** FILE NAlVlE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification ~isting Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 24 FILE HEADER FILE NUFiBER 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUf4~ER: 7 DEPTH INCREM~k~Uf: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 11715.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12227.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 08-JUL-97 5.0 34 _ 5.O 34 _ MEMORY 12227.0 6791.0 12227.0 23.0 35.8 TOOL NUMBER ARC5 O63 8.500 9445.0 QUIKDRILL /SEAWATER 8.80 0.140 70.0 LIS Tape Verification. ~isting Schlumberger Alaska Computing Center 1-DEC-1997 14:51 PAGE: 25 TOOL STANDOFF (IN): BWR FREQUF~CY (HZ): 20000 RUN RUN RUN RUN RUN RUN RUN 1 - 6856' -9452' 8.5" BS GR 2 - 9452'-9630' 6" BS ARC5 3 - 9630'-9853' 6" BS ARC5 4 - 9853'-10030' 6" BS ARC5 5 - 10030'-11252' 6" BS ARC5 6 - 11252'-11817' 6" BS ARC5 7 - 11817'-12227' 6" BS ARC5 DATA FROM DOWNHOLE MEMORY, V5.0 34 SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 8 1 1 4 68 0000000000 ROP5 LW7 F/HR O0 000 O0 0 8 1 1 4 68 0000000000 TAB LW7 HR O0 000 O0 0 8 1 1 4 68 0000000000 TABR LW7 HR O0 000 O0 0 8 1 1 4 68 0000000000 GR LW7 GAPI O0 000 O0 0 8 1 1 4 68 0000000000 PIOH LW7 OHT4~ O0 000 O0 0 8 1 1 4 68 0000000000 P16H LW7 OHM~ O0 000 O0 0 8 1 1 4 68 0000000000 P22H LW7 OH~ O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification. ~isting Schlumberger Alaska Computing Center 1-DEC-1997 1~51 PAGE: 26 NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N73FiB SAMP ELEM CODE (HEX) P28H LW7 OPE4M O0 000 O0 0 8 1 1 4 68 0000000000 P34H LW7 OPE4~ O0 000 O0 0 8 1 1 4 68 0000000000 AIOH LW7 OHM~ O0 000 O0 0 8 1 1 4 68 0000000000 A16H LW7 OlqP~f O0 000 O0 0 8 1 1 4 68 0000000000 A28H LW7 OH~4~ O0 000 O0 0 8 1 1 4 68 0000000000 A34H LW7 OPkq~ O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 12227.000 ROPSoLW7 38.010 TAB.LW7 -999.250 TABR.LW7 GR~LW7 -999.250 PIOH~LW7 -999.250 P16H. LW7 -999.250 P22H. LW7 P28H. LW7 -999.250 P34H.LW7 -999.250 AiOH. LW7 -999.250 A16H. LW7 A28H. LW7 -999.250 A34H~LW7 -999.250 DEPT~ 12000.000 ROP5oLW7 136.360 TAB.LW7 0.603 TABR.LW7 GR.LW7 44.990 PIOHoLW7 15.000 P16H. LW7 15.810 P22H.LW7 P28H. LW7 20.090 P34H.LW7 19.250 AiOH. LW7 11.030 A16H. LW7 A28H. LW7 16.450 A34H~LW7 15.570 DEPT. 11758.000 ROPS.LW7 -999.250 TAB.LW7 -999.250 TABR.LW7 GR.LW7 -999.250 PiOH. LW7 -999.250 P16H. LW7 -999.250 P22H. LW7 P28H. LW7 -999.250 P34H.LW7 -999.250 AiOH. LW7 -999.250 A16H.LW7 A28H. LW7 -999.250 A34H.LW7 -999.250 -999.250 -999.250 -999.250 0.547 18.250 14.030 -999.250 -999.250 -999.250 ** ~ OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/12/ 1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 97/12/ 1 ORIGIN : FLIC TAPE NAME : 97473 CONTINUATION # : 1 PREVIOUS TAPE : CO14M~NT : B.P. EXPLORATION, PRUDHOE BAY S-22B, API #50-029-22119-02 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1-DEC-1997 PAGE: 27 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/12/ t ORIGIN : FLIC REEL NAf4E : 97473 CONTINUATION # : PREVIOUS REEL : COn, lENT : B.P. EXPLORATION, PRUDHOE BAY S-22B, API #50-029-22119-02