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Home My WebLink About202-135CAUTION: 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: Injector S-112 (PTD #2021350) will lapse on AOGCC MIT-IA Date:Friday, March 14, 2025 7:47:32 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 14, 2025 7:43 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>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-112 (PTD #2021350) will lapse on AOGCC MIT-IA Mr. Wallace, Injector S-112 (PTD #2021350) is due for it’s 2-year MIT-IA by the end of March 2025. There are no plans to have the well on Injector before the end of the month, it will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 05/03/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU S-112 PTD: 202-135 API: 50-029-23099-00-00 ULTRA SONIC IMAGING TOOL (USIT) TEMP/GAMMA RAY LOG 08/03/2002 Please include current contact information if different from above. 202-135 T38766 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 11:10:11 -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-112 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-135 50-029-23099-00-00 8642 Conductor Surface Intermediate Production Liner 6743 120 2882 6794 1825 8535 20" X 34" 9-5/8" 7" 4-1/2" 6743 35 - 155 34 - 2916 31 - 6825 6710 - 8535 35 - 155 34 - 2879 31 - 6667 6589 - 6753 None 770 3090 5410 7500 None 2280 5750 7240 8430 6900 - 8535 4-1/2" 12.6# L-80 29 - 6718 6711 - 6753 Structural 5" Baker Premier Packer 6658, 6552 6658 6552 Torin Roschinger Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, AURORA 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 29 - 6596 N/A N/A 282 964 400 300 2319 2374 N/A 13b. Pools active after work:AURORA OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:45 am, Jul 12, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.12 06:20:08 -08'00' Torin Roschinger (4662) DSR-7/12/23 RBDMS JSB 071323 WCB 2-29-2024 ACTIVITY DATE SUMMARY 6/24/2023 LRS CTU #2 - 1.75" Blue Coil. Job Objective: Adperfs MIRU. MU 2.20" HES Memory Logging BHA with 2.25" Jet Swirl Nozzle. RIH. Tagged TD at 8519'. Logged from TD to 6400' painting red tie-in flag at 7300'. Confirm +/- 0' correction, TD tag of 8521'. Make up Perf gun run #1 with 40' of 2" Maxforce perf guns, 6 spf. Tie-in at flag and drift to 8311' to confirm still in main bore. Paint yellow EOP flag at 8304.09'. Perforate 7348'-7388'. POOH. ...Continue on WSR 6-25-23... 6/25/2023 LRS CTU #2 - 1.75" Blue Coil. ***Cont. from WSR 6-24-23*** Job Objective: Adperfs Lay down perf gun run #1. Make up perf gun run #2 with 40' of 2" Maxforce perf guns and RIH. Drift to 8300' to confirm still in the motherbore and tie-in to flag. Perforate 7308-7348'. Make up perf gun run #3 with 40' of 2" Maxforce perf guns and RIH. Drift to 8300' to confirm still in the motherbore and tie-in to flag. Perforate 7107-7147'. Make up Logging BHA with 2.2" GR/CCL carrier and RIH. Log from TD of 8517' CTMD to 6400', paiting white tie-in flag at 8298'. Confirm -1' correction. Make up perf gun run #4 with 40' of 2" Maxforce perf guns and RIH. Drift to 8300' to confirm still in the motherbore and tie-in to flag. Perforate 7067'-7107'. Make up perf gun run #5 with 20' of 2" Maxforce perf guns and RIH. ...Continued on WSR 6-26-23... 6/26/2023 LRS CTU #2 - 1.75" Blue Coil. ***Cont. from WSR 6-25-23*** Job Objective: Adperfs Make up perf gun run #5 with 20' of 2" Maxforce perf guns and RIH. Drift to 8300' to confirm still in the motherbore and tie-in to flag. Perforate 6976'-6996'. Make up perf gun run #6 with 30' of 2" Maxforce perf guns and RIH. Drift to 8300' to confirm still in the motherbore and tie-in to flag. Perforate 6925-6955. POOH and freeze protect the well with diesel to 2500' TVD. RDMO. ***Job Complete*** 7/3/2023 T/I/O = 2350/1110/550. Temp = 130°. Bleed WHPs (UIC). IA & OA FL @ surface. Bled IAP to BT from 1110 psi to 300 psi in 2 min (0.3 bbls). Bled OAP to BT from 550 psi to 0+ psi in 5 min (0.5 bbls). Monitored for 30 min. OAP increased 20 psi. IAP increased 20 psi. Final WHPs = 2350/320/20. SV = C. WV, SSV, MV = O. IA & OA = OTG. 10:30 Daily Report of Well Operations PBU S-112 g Perforate 7348'-7388'. g Perforate 6976'-6996'. g Perforate 7308-7348'g Perforate 7107-7147'. g Perforate 7067'-7107'. g Perforate 6925-6955 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: Injector S-112 (PTD #2021350) request for temporary MI injection to evaluate TxIA communication Date:Tuesday, March 21, 2023 9:58:36 AM Attachments:image002.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, March 21, 2023 9:58 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Re: Injector S-112 (PTD #2021350) request for temporary MI injection to evaluate TxIA communication Oliver, Approved for 30 days MI diagnostics and monitoring as requested. AOGCC can temporarily waive the restrictive conditions set by AIO 22D.001. As this is an older (2008) administrative approval, and the Operator of record has changed since, Hilcorp will review the well and ensure they can comply with all other AOGCC regulations including those relating to safety/safety valves while under MI. 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: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, March 20, 2023 12:03:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Injector S-112 (PTD #2021350) request for temporary MI injection to evaluate TxIA communication Mr. Wallace, Injector S-112 (PTD# 2021350) currently operates under AIO 22D.001 since 2008 for slow TxIA communication when on MI and is restricted to PWI only. In 2016, after failing an MIT-IA, a leak was found at the sliding sleeve at 6596’ MD. An isolation sleeve was set over the sliding sleeve and an MIT-IA passed to 3135 psi. The well was placed on temporary MI in late 2016 to see if the repair fixed the slow TxIA on MI, but the communication was still present. An LDL on 10/25/2020 found a tubing leak which was repaired with a tubing patch on 11/17/2020 and passed a MIT-T to 2905 psi on the same date. It is possible that this tubing failure point repaired in 2020 was the historic communication path to MI. Hilcorp requests a temporary deviation from AIO 22D.001 to allow for the well to be placed Under Evaluation for up to 30 days on MI injection to monitor for TxIA communication. An AOGCC witnessed MIT-IA passed to 3392 psi on 3/14/2023 while on PWI. Maximum MI pressure at S-pad for the last 12 months has been 3150 psi. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, November 23, 2020 11:16 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: Injector S-112 (PTD #2021350) passed MIT-T post patch set Thanks Chris, The well will now be classified back to OPERABLE. Let me know if you have any questions. 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 (CED) <chris.wallace@alaska.gov> Sent: Monday, November 23, 2020 7:24 AM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] RE: Injector S-112 (PTD #2021350) Request to resume Produced Water Injection Andy, S-112 is approved to restart water only injection. 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: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, November 19, 2020 3:31 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: Injector S-112 (PTD #2021350) Request to resume Produced Water Injection Mr. Wallace, Injector S-112 (PTD #2021350) was made Not Operable on 10/08/20 after it was discovered to have TxIA communication on PWI. A Leak detect log performed on 10/25/20 identified a production tubing leak which was subsequently covered with a production tubing patch in accordance with Sundry #320-464. A passing MIT-T was performed to 2,905 psi indicating the tubing integrity has been restored. Per AA AIO22.D001, Hilcorp is seeking your approval to place S-112 back on Produced Water Injection. Please let me know if you have any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, October 8, 2020 1:31 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: NOT OPERABLE: Injector S-112 (PTD #2021350) TxIA communication Mr. Wallace, Injector S-112(PTD #2021350) was placed under evaluation after being found to have TxIA communication resulting in an IA pressure excursion over NOL. Diagnostics are continuing to be progressed to determine a corrective action to restore tubing integrity. The well is reclassified as NOT OPERABLE, and will not be placed back on injection pursuant to AA AIO22D.001 without AOGCC approval. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Alaska NS - PB - Field Well Integrity Sent: Friday, September 11, 2020 12:36 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: UNDER EVALUATION: Injector S-112 (PTD #2021350) TxIA communication Mr. Wallace, Injector S-112 (PTD #2021350) has been found to have TxIA communication resulting in an IA pressure excursion over NOL. During well start on 09/10/20, the inner annulus pressure increased to 2650 psi. The IA was bled, subsequent re-pressurization was determined not to be solely from thermal effects of the well start and the well was immediately shut in and freeze protected. At this time the well is classified as UNDER EVALUATION and will not be placed back on injection pursuant to AA AIO22D.001 without AOGCC approval and corrective action to restore tubing integrity. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO DHD Well Integrity Sent: Wednesday, December 21, 2016 2:35 PM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Prod Controllers <sewellcr21@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; Zoesch, Eric <zoese0@BP.com>; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AKIMS App User <akimsuser.service@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector S-112L1 (PTD #2021350) Return to Water Injection All, Injector S-112L1 (PTD #2021350) continued to show signs of IA repressurization when on MI injection and was shut in. An MIT-IA passed on 12/18/16, confirming two barriers to formation. The well is now reclassified as Operable and is ready to be put back on PWI injection only. Please use caution when bringing online as the annuli are fluid packed. Ryan Moore Well Integrity / Down Hole Diagnostics (907) 659-5525 Office (805) 550-5342 Cell Harmony # 5415 Alternate: Josh Prowant MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-112 PRUDHOE BAY UN AURO S-112 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/06/2023 S-112 50-029-23099-00-00 202-135-0 W SPT 6552 2021350 1638 2278 2279 2277 2277 210 527 513 504 OTHER P Bob Noble 3/14/2023 MIT-IA to request under eval to swap to MI, to max pressuer of 3200 psi. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S-112 Inspection Date: Tubing OA Packer Depth 878 3548 3413 3392IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230315130645 BBL Pumped:2 BBL Returned:2 Thursday, April 6, 2023 Page 1 of 1          AIO 22D.001   MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-112 PRUDHOE BAY UN AURO S-112 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/05/2023 S-112 50-029-23099-00-00 202-135-0 W SPT 6552 2021350 1638 2280 2281 2273 2231 202 496 483 462 OTHER P Austin McLeod 3/5/2023 MITIA. Test done for possible request to put on GINJ. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S-112 Inspection Date: Tubing OA Packer Depth 700 3202 3072 3009IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230305193929 BBL Pumped:1.8 BBL Returned:1.8 Wednesday, April 5, 2023 Page 1 of 1           From: AK, GWO SUPT Well Integrity Sent: Monday, December 05, 2016 12:16 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS WELL PAD S; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: NOT OPERABLE: Injector S-112L1 (PTD #2021350) Tubing x Inner Annulus Communication on MI Injection All, Injector S-112L1 (PTD #2021350) was brought online Under Evaluation on 11/19/16, injecting MI. The well operates under Administrative Approval AIO 22D.001, which restricts the well to water injection only due to T x IA communication previously observed on MI. The AOGCC granted a temporary deviation to the AA, allowing up to 30 days of MI injection, to evaluate whether remedial work completed on 09/13/16 had repaired the communication. After approximately one week, the IA began to exhibit repressurization. The well is reclassified Not Operable, and should be shut in as soon as operationally feasible. It must remain shut in until ready to resume water injection; there will be no application to cancel the AA. Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) O: (907) 659-5102 C: (907) 943-0296 H: 2376 From: AK, GWO SUPT Well Integrity Sent: Friday, November 18, 2016 2:38 PM To: AK, GWO SUPT Well Integrity; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bronga, Jaime; Bergene, Matthew; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Wellman, Julie; Holt, Ryan P; AK, GWO Well Integrity Well Information; AK, GWO Completions Well Integrity; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Injector S-112L1 (PTD #2021350) Evaluate TxIA Communication on MI Injection All – Injector S-112L1 (PTD #2021350) is a recently-completed coiled tubing drilling sidetrack. The well had a known one-way leak from the tubing to the Inner Annulus at the sliding sleeve. An isolation sleeve was set in the leaking sliding sleeve and and a subsequent MIT- IA passed on 05/15/16 proving two competent barriers. The well was reclassified as Operable on 06/04/16 and subsequent water only injection showed no indication of amomolous behavior. As an alternative to cancelling the existing Adimistrative Approval, the AOGCC has granted BP a temporary deviation from the AA to for MI injection as Under Evaluation to monitor for TxIA communication. Plan Forward: 1. Well Integrity: Reclassify as Under Evaluation – Done 11/18 2. Operations: Put well on MI Injection 3. Downhole Diagnostics: Monitor for TxIA Communication while on MI 4. Fullbore Pumping: MITIA while on MI 5. Well Integrity: Application to cancel the AA 22D.001 could follow. Please respond if in conflict with proposed plan. Thanks! Jack Lau (Alternate: Adrienne McVey) BP Alaska - Well Integrity Superintendent W: 907.659.5102 C: 907.943.0296 H: x2376 From: AK, D&C Well Integrity Coordinator Sent: Saturday, June 04, 2016 9:34 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bronga, Jaime; Bergene, Matthew; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Wellman, Julie; Holt, Ryan P Subject: OPERABLE: Injector S-112L1 (PTD #2021350) Post-Sidetrack MIT-IA Passed All, Injector S-112L1 (PTD #2021350) is a recently-completed coiled tubing drilling sidetrack. The well had a known one-way leak from the tubing to the Inner Annulus at the sliding sleeve. The well is approved for produced water injection only. During the course of the pre-rig work the sliding sleeve began leaking to fluid. The tubing and IA began tracking when pumping into the well, and the well subsequently failed an MIT- T, but passed a combination MIT-TxIA, proving competent production casing. An isolation sleeve was set in the leaking sliding sleeve and and a subsequent MIT-IA passed. After flowback another MIT-IA passed proving two competent barriers. This well is now reclassified as Operable. Once put on injection an AOGCC MIT-IA will be performed. Plan Forward: 1. Slickline: Install isolation sleeve across sliding sleeve, install live gas lift valves - DONE 05/15/16 2. Fullbore: MIT-IA to 3130 psi - PASSED 05/15/16 3. Well Testing: Flow back drilling fluids – DONE 05/18/16 4. Slickline: Set dummy gas lift valves – DONE 06/03/16 5. Fullbore: Circulate IA to diesel, MIT-IA – DONE 06/03/16 6. Operations: Put on produced water injection (mind fluid packed annuli) 7. DHD: AOGCC-witnessed MIT-IA Please mind the fluid packed annuli when putting well on injection. Thanks! Jack Lau (Alternate: Adrienne McVey) BP Alaska - Well Integrity Superintendent W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 15, 2016 6:29 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bronga, Jaime; Bergene, Matthew; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Injector S-112 (PTD #2021350) Post-Sidetrack Flowback All, Injector S-112L1 (PTD #2021350) is a recently-completed coiled tubing drilling sidetrack. The rig moved off the well on 23rd April 2016. The sidetrack was cut short due to a troublesome fault crossing (unable to drill into the desired sand in the target fault block), and TD was called approximately 1110’ shorter than planned. The rig ran a slotted liner rather than the originally planned cemented and perforated completion, and left 10.1 ppg drilling mud in the well instead of circulating the well to inhibited brine. The well has a known one-way leak from the tubing to the IA at the sliding sleeve (62’ above the production packer) when on MI injection, and operates under AA AIO 22D.001 for TxIA communication when on MI. The well is approved for produced water injection only. During the course of the pre-rig work, it became evident that the sliding sleeve had started leaking to fluid. The tubing and IA began tracking when pumping into the well, and the well subsequently failed an MIT-T, but passed a combination MIT-TxIA, proving competent production casing. The following changes to the post-rig work plan, outlined in Sundry #316-043, were approved by the AOGCC on 04/29/16: Post-rig flowback period, originally planned for 1-2 weeks, shortened to approximately 2-6 days. New objective is simply to produce back the 10.1 ppg drilling mud and solids left in the hole prior to returning the well to injection service. Target is to recover 5000 bbl of fluid. Prior to flowback, set isolation sleeve in the leaking sliding sleeve, and test by performing an MIT-IA. The well is reclassified as Under Evaluation, in order to flow back the drilling fluids. Plan Forward: 1. Slickline: Install isolation sleeve across sliding sleeve, install live gas lift valves - DONE 05/15/16 2. Fullbore: MIT-IA to 3130 psi - PASSED 05/15/16 3. Well Testing: Flow back drilling fluids 4. Slickline: Set dummy gas lift valves 5. Fullbore: Circulate IA to diesel, MIT-IA 6. Operations: Put on produced water injection 7. DHD: AOGCC-witnessed MIT-IA Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) Office: (907) 659-5102 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: 26 February 2016 19:37 To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; Bronga, Jaime; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed All, Injector S-112 (PTD #2021350) currently operates under AA22D.001 for known slow tubing by inner annulus communication, with a passing MIT-IA performed January 12, 2016. The well was scheduled for wellwork which necessitated producing the well prior to sidetracking in order to lower the downhole pressure. The well has begun showing signs of more rapid annulus communication and failed a subsequent MIT-T on February 24, 2016. The well has been reclassified as Not Operable and will not be brought online until well integrity can be restored downhole. Please call with any questions. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska - Well Integrity Coordinator Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@bp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. TREE = FMC 4-1/16"5M SAFETY NOTES: S-112 REA NGS AV FRAGE 125 ppm WHEN N MI' WELL L 1 1 I REQUIRES A SSSV WHEN ON M I""" 215.5 Ib/ft. A53 ERIN INSULATED 9-5/8" CSG, 40#, L-80, BTC, D = 8.750" 2915' Minimum ID = 2.45" @ 6447' 4-112" 45FLGD BAKER PATCH 4-12" 45FLGD BAKER PATCH, I.D. = 2.45" 6447' 1 114' 114-12" TBG, 12.75#, L-80 TCIL .0152 bpf, ID = 3.958-1-1 6718' CSG, 26#, L-80, D = 6.276" HMCV CEMENTER I—F 752W 4-12" CEMENTM PAYZONE ECP, ID = 3.937" S-11; 4-12" LNR, 12.6#, L-80 BTC -M, .0152 bpf, D = 3.958",�� , 2257' 1-14-1/2" HES X NIP, ID = 3 813" GAS LIFT MANDRELS ST I MD PERFORATION SUljMARY 5E-71 REF LOG: I PORT I 'TE ANGLEATTOP FH7F: WA Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sqz SHOT I SQZ 5616 1 5-112 KGB2 TMY BK 3-3/8" 6 6900 - 6925 0 0429/03 KGB2 'DI1A1' BK 3-3/8" 6 6960 - 6976 0 0429/03 05/03116 TT/JMD 4-12" SLTD 7650-8535 SLOT 0729/02 FINAL ODE APPROVAL 11/1820 S-112 L1 SET PATCH(11/1720) 2-7/8" 1 SLTD 16989-80541 SLOT 104/21/16 PULL XX PLUG (112320) HMCV CEMENTER I—F 752W 4-12" CEMENTM PAYZONE ECP, ID = 3.937" S-11; 4-12" LNR, 12.6#, L-80 BTC -M, .0152 bpf, D = 3.958",�� , 2257' 1-14-1/2" HES X NIP, ID = 3 813" GAS LIFT MANDRELS ST I MD I TVD 5E-71 TYPE I VLV I LATCH I PORT I 'TE 3 3850 3813 1 KGB2 'DRAY BK 0 06/02/16 2 5654 5616 1 1 KGB2 TMY BK 0 06/02/16 1 6529 6451 35 KGB2 'DI1A1' BK 0 O6/02/16 ALL STATIONS = EXTENDED PACKING 6596 4-12' BKR SLD SLV,D=3.813' "ONE WAY LEAK TO IA WHEN ON MI INJ 6706' 1—J4-1/2" FES XN NP MLLEDTO 3.80" (02126/16) 1 6710' —1 6718' 7" X 5" BKR ZXP LTP, D = 4.390" 4-1/2" WLEG, D=3.958" 6729 7"X5" BKR HMC LNR FIGR, D = 503- 6735— 5" X 4-12 XO BUSFfJG, D = 3.89" MLLOUT WINDOW(S-112LI) 6912'-6920' 3 825^ sI-nrm r1Fa ov sI v n = 6958- - 6989' 2-715 SOLD LNR 6A#, L-80 STL, .0058 bpf, D = 2.441" 8054FISH: MOTOR BR FISH SLTDLNR 6989' - S-112 L L-80 HYD 511, 8054' bpf, D = 2.441" 4-1/4" OPEN HOLE TO 8097' AURORA UNIT WELL: S-112 LI PERMIT No: 2021350/'2152220 API No: 50-029-23099-00/60 SEC 35, T12N, R12E, 949' FNL & 780' FWL DATE REV BY COMMENTS DATE I REV BY COMMENTS ORM7102 D-14 INITIAL COMPLETION 05/18/16 NXW/JMD GLV C/O (05/15116) 0424M6 NORDIC2 CTD -112 L7 06/06/16 JMG/JMD GLV C/0 (06/02/16) 0428116 JMD DRLG HO CORRECTIONS 09/19/16 ZV/JMD RESET ISO SLV/SET NIP RED 112116 05/03116 TT/JMD MINOR EDITS 10/1920 JKC/MM SET PLUG (1011620) 05/04/16 TT/JMD FINAL ODE APPROVAL 11/1820 SW/MM SET PATCH(11/1720) Hilcorp North Slope, LLC 05/18/16 RCT/JMD SET ISO SLEEVE (05114/16) 11125120 KB/MM PULL XX PLUG (112320) Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL S-112 (PTD 202-135) PATCH SETTING RECORD 11/17/2020 Please include current contact information if different from above. PTD: 2021350 E-Set: 34314 Received by the AOGCC 12/02/2020 Abby Bell 12/02/2020 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:202-135 6.50-029-23099-00-00 PRUDHOE BAY, AURORA OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 8642 8642 6743 6658 6552 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 117 20" X 34" 36 - 153 36 - 153 2280 770 Surface 2880 9-5/8" 35 - 2915 35 - 2878 5750 3090 Intermediate 6793 7" 32 - 6825 32 - 6667 7240 5410 Production Perforation Depth: Measured depth: 6900 - 8642 feet True vertical depth:6711 - 6743 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 30 - 6718 30 - 6596 6658 6572Packers and SSSV (type, measured and true vertical depth) 5" Baker PRM Prod Packer Liner 1825 4-1/2" 6710 - 8535 6589 - 6753 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 25001500452 997 600 2250 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen brian.glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5277 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ 5 WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured6743 Sundry Number or N/A if C.O. Exempt: 320-464 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Patch Tubing Operations shutdown Change Approved Program 5 n/a Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028257 PBU S-112 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:11 am, Dec 02, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.12.02 12:52:56 - 06'00' Stan Golis RBDMS HEW 12/2/2020 DSR-12/2/2020 SFD 12/2/2020MGR04FEB2021 ACTIVITY DATE SUMMARY 10/15/2020 ***WELL SI ON ARRIVAL*** TAGGED 4 1/2" MCX INJ VALVE @ 2257' MD. ***WSR CONTINUED ON 10-16-20*** 10/15/2020 T/I/O=1400/1550/0 Load tbg with 3 bbls 60/40 & 100 bbls diesel pre slickline FWHPs=2600/2300/0 10/16/2020 ***WSR CONTINUED FROM 10-15-20*** PULLED 4 1/2" MCX ON 3.81" X LOCK FROM 2257' MD. SET 2.31" XX PLUG @ 6685' MD. ***WELL LEFT S/I, READY FOR FB*** 10/16/2020 T/I/O=1924/1604/0 Assist Slickline as Directed (TxIA Comm) Pump 4 bbls diesel at min rate while slickline pulls MCX. CMIT-TxIA to 2500 psi *PASSED* at 2449 psi. T/IA lost 24/21 psi during the 1st 15 minutes. T/IA lost 15/13 psi during the second 15 minutes. Pumped 0.84 bbls of 40* F diesel to achieve test pressure. Bled the IA to S- 122 F/L. TBG pressure fell but at a slower rate. MIT-T to 2500 psi *FAILED* Pumped 15 bbls of diesel into the TBG with the IA open to establish LLRT of 0.18 bpm @ 2480 psi. Final T/I/O= 520/220/0. 10/18/2020 T/I/O = 1530/1140/Vac. Temp = SI. LLR x TBG (Eval T x IA). TBG FL @ near surface. IA FL @ surface. Hardline rigged up from IA to the TC on #122 (SI @ swab, 1/4 turn & IA casing). Flowline is SI @ wing & DBL plug valves (2700 psi). U- Tubed the TBG & IA for 30 minutes. Bled the IAP from 1106 to 3 psi in 1 hour (IA swapped to fluid/gas mix @ 14 psi, 3.4 bbls bled back). During the IA bleed the TP decreased to 240 psi. Bled the TP from 240 psi to 14 psi in 15 minutes (.6 bbls all fluid). During the TBG bleed the IAP increased 10 psi. Re-bled the IAP from 13 psi to a Vac in 2 minutes. During the second IA bleed the TP increased 200 psi. Pumped 6.3 bbls of DSL down the TBG @ max rate for triplex (taking returnns to a bleed tank). Max TBG pressure during attempted LLR = 1444 psi. 6.2 bbls returned from the IA. U-tubed the TBG/IA for 30 minutes @ end of job. Tag hung. FWPs = 780/760/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00. 10/19/2020 T/I/O = 900/590/VAC. Temp = SI. U-tube TP/IAP (pre LDL). 2" harline rigged up to IA & TC of S-122. T & IA FL @ surface. U-tubed TP/IAP to 650/640 psi for 2 hrs 30 min. Monitored for 30 min. TP increased 80 psi, IAP decreased 90 psi. Final WHPs = 730/550/VAC. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:30 10/25/2020 T/I/O= 280/110/0. LRS unit 72 Assist E-Line (LEAK DETECTION LOG) Pumped 115 bbls of diesel into the TBG with IA returns to S-122 F/L. Final T/I/O= 1280/260/0 10/25/2020 ...Well shut in on arrival... (HES Eline - LDL) LOG READ ARCHER LEAK DETECT LOG FROM TTP AT 6,685' TO SURFACE WHILE LRS ESTABLISHED A LLR OF 0.34 BPM AT 1450 PSI PUMPING DOW N THE TBG TAKING RETURNS UP THE IA. LEAK SIGNATURE FROM ACOUSTIC AND TEMPERATURE DATA AT 6,460' ELMD, CONFIRMED WITH STOP COUNTS. ***Job Complete. Well shut in on departure.*** 10/28/2020 T/I/O = 160/0/0. Temp = SI. Verify communication (Ensure well is not frozen). Used 1/8 bbl amb Diesel to pressure TP from 160 psi to 200 psi. IAP increased from 0 psi to 40 psi verifying communication. The companion side IA gauge also had communication. Bled TP from 200 psi to 60 psi in 1 min (Fluid, 1/8 bbl). IAP went on a Vac. Monitored for 30 min. TP increased to 150 psi. Collected IA fluid sample. Final WHPs = 150/Vac/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 Daily Report of Well Operations PBU S-112 Daily Report of Well Operations PBU S-112 11/13/2020 ***WELL S/I ON ARRIVAL*** DRIFTED CLEANLY W/ 30' x 3.68" DUMMY PATCH TO 6550' SLM. ***WELL LEFT S/I; READY FOR E-LINE*** 11/17/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line Set Baker Patch) SET 4-1/2" 45FLGD BAKER PATCH 6,449' - 6,474' ELEMENT TO ELEMENT (Top of patch ~ 6,447', MIN I.D. = 2.45", OAL LIH ~ 30.88'). LOGS CORRELATE TO READ LEAK POINT SURVEY DATED 25-OCT-2020. ***JOB COMPLETE ON 16-SEP2020*** 11/17/2020 T/I/O = 840/230/Vac. Temp = SI. MIT x TBG Passed to 2905 psi (Post patch). Test pressure = 2500 psi. Max applied pressure = 3005 psi. TBG FL @ surface. Pressured up the TBG w/ .3 bbls of DSL. The TBG lost 80 psi in the first 15 minutes and 20 psi in the second 15 minutes for a total 30 minute loss of 100 psi. Bled the IAP (.4 bbls, all fluid). Tag hung. FWPs = 840/260/Vac. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 11/23/2020 ***WELL S/I ON ARRIVAL*** (leak detection log) EQUALIZED & PULLED 2-7/8" XX-PLUG FROM NIP-REDUCER @ 6,685' MD. ***JOB COMPLETE, WELL LEFT S/I*** Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Monday, November 23, 2020 7:24 AM To: Alaska NS - PB - Field Well Integrity Cc: Oliver Sternicki; Aras Worthington Subject: RE: Injector S-112 (PTD #2021350) Request to resume Produced Water Injection Andy, S-112 is approved to restart water only injection. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7' 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: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Thursday, November 19, 2020 3:31 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: Injector S-112 (PTD #2021350) Request to resume Produced Water Injection Mr. Wallace, Injector S-112 (PTD #2021350) was made Not Operable on 10/08/20 after it was discovered to have TAA communication on PWI. A Leak detect log performed on 10/25/20 identified a production tubing leak which was subsequently covered with a production tubing patch in accordance with Sundry #320-464. A passing MIT -T was performed to 2,905 psi indicating the tubing integrity has been restored. Per AA A1022.D001, Hilcorp is seeking your approval to place S-112 back on Produced Water Injection. Please let me know if you have any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.oRR@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Oliver Sternicki <Oliver.Ster—ntc ' hilcor .com> Sent: Thursday, October 8, 2020 1:31 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWellln it hilcor .com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regl;@alaska.gov>; Stan Golis <s olis�hilcor >; Aras Worthington <Aras.Worthington@hilcorp.com>; Travis Smith - (C) <Travis.Smith>; Brian Glasheen Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:202-135 6.API Number:50-029-23099-00-00 PRUDHOE BAY, AURORA OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028257 Property Designation (Lease Number):10. 8. PBU S-112 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Patch Tubing Op Shutdown GAS 5 GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8642 Effective Depth MD: L-80 11. 11/4/2020 Commission Representative: 15. Suspended Contact Name: Brian Glasheen Contact Email: brian.glasheen@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 6743 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 6658, 6572 No SSSV Installed Date: Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 2915 35 - 2878 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 153 Structural 7240 Proposal Summary 13. Well Class after proposed work: 5" Baker PRM Packer 6900 - 8642 6711 - 6743 4-1/2" 12.6#30 - 6718 Liner 6685 6572 6685 36 - 153 770 9-5/8" 7" Contact Phone:907-545-1144 Date: 5410 117 228020" X 34"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2880 5750 Intermediate 6793 32 - 6825 32 - 6667 1825 4-1/2"6710 - 8535 6589 - 6753 8430 7500 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 6:32 pm, Oct 28, 2020 320-464 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.10.28 16:10:21 - 08'00' Stan Golis X DLB 10/29/2020 DSR-10/28/2020 2700 10-404 MGR28OCT20 Yes Required? Comm. 10/29/2020 dts 10/29/2020 JLC 10/29/2020 RBDMS HEW 11/12/2020 Tubing Patch Well:S-112/S-112L1 PTD:202-135, 215-222 API: 50-029-23099-00, 50-029-23099-60 Well Name:PBU S-112, S-112L1 API Number:50-029-23099-00/60 Current Status:Not Operable Rig:EL Estimated Start Date:November 24, 2020 Estimated Duration:2days Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker 564-4915 Permit to Drill Number:202-135, 215-222 First Call Engineer:Brian Glasheen (907) 564-5277 (O)(907) 545-1144 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3966 @ 6700’ TVD (Based on FL 10/10/18) MPSP:2700 psi (Boosted Water Pressure) Recent. SI Surface Pressure:2100 psi (10/15/20) Min ID:2.313” at 6596’ X Nipple Reducer Tie In Log:PDS Archer LDL dated 10/25/20 Brief Well Summary: Tubing x IA communication was noted after recent shut in. A CMIT was performed and passed. Next, a CMIT was attempted and a LLR of 0.18-BPM was recorded. Next, an Archer Leak Detect Log was run and a tubing leak identified at 6460’. This job will restore tubing integrity and allow the well to resume injection. Notes Regarding Wellbore Condition: x Well has AA for PWI only. x Plug set in tubing at 6685’ Objective: Install tubing patch to restore integrity. Procedure: E-line 1. MIRU EL unit. 2. Install Baker tubing patch per attached LDL 3. MIT-T to 3000 psi 4. RDMO. Slickline 1. MIRU Slickline unit. 2. Pull TTP set at 6685’. 3. RDMO Attachments: 1. As-built Schematic 2. Proposed Schematic * CMIT TxIA passed on 16-October-2020 to 2449 psi. (Tubing leak point determined utilizing 'Archer Leak Point log 25-Oct-2020 leak point on log identified at 6460' ELMD) Wallace, Chris D (CED) From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, October 8, 2020 1:31 PM To: Alaska NS - PB - Field Well Integrity; Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Travis Smith - (C); Brian Glasheen Subject: NOT OPERABLE: Injector 5-112 (PTD #2021350) TxIA communication Mr. Wallace, Injector S-112(PTD #2021350) was placed under evaluation after being found to have TxIA communication resulting in an IA pressure excursion over NOL. Diagnostics are continuing to be progressed to determine a corrective action to restore tubing integrity. The well is reclassified as NOT OPERABLE, and will not be placed back on injection pursuant to AA A1022D.001 without AOGCC approval. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: A a NS - PB - Field Well Integrity Sent: Friday, Se tuber 11, 2020 12:36 PM To: 'ch ris.waIlace @a a.gov' <chris.waIlace @alaska.gov> Cc: Regg, James B (CED) <Ji egg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.co Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brian heen <Brian.Glasheen@hilcorp.com> Subject: UNDER EVALUATION: Injector S-112.(PTD #2021350) TxIA communication Mr. Wallace, Injector 5-112 (PTD #2021350) has been found to have TxIA mmunication resulting in an IA pressure excursion over NOL. During well start on 09/10/20, the inner annulus pressure i reasedto 2650 psi. The IA was bled, subsequent re - pressurization was determined not to be solely from thermal effects the well start and the well was immediately shut in and freeze protected. At this time the well is classified as UNDER EVAL TION and will not be placed back on injection pursuant to AA A1022D.001 without AOGCC approval and corrective ction to restore tubing integrity. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO DHD Well Integrity Sent: Wednesday, December 21, 2016 2:35 PM To: AK, GWO SUPT Well Integrity<AKDCWellintegrityCoordinator@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS WELL PAD 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, September 11, 2020 12:36 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Oliver Sternicki; Travis Smith - (C); Brian Glasheen Subject: UNDER EVALUATION: Injector S-112 (PTD #2021350) TxIA communication Mr. Wallace, Injector S-112 (PTD #2021350) has been found to have TxIA communication resulting in an IA pressure excursion over NOL. During well start on 09/10/20, the inner annulus pressure increased to 2650 psi. The IA was bled, subsequent re - pressurization was determined not to be solely from thermal effects of the well start and the well was immediately shut in and freeze protected. At this time the well is classified as UNDER EVALUATION and will not be placed back on injection pursuant to AA A1022D.001 without AOGCC approval and corrective action to restore tubing integrity. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO DHD Well Integrity Sent: Wednesday, December 21, 2016 2:35 PM To: AK,,GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, OPS GC2 OSM <AKOPS�3C2OSM@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieIdOMTL1@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIlpadLead@bp.com>; AK, OPS WELL PAD S <AKOPSWELLI5 D$@bp.com>; AK, OPS Prod Controllers <sewellcr2l@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Darie, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP:Com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; Zoesch, Eric <zoese0@BP.com>; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AKIMS App User <akimsuser.service@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector S -112L1 (PTD #2021350) Return to Water Injection All, Injector S-1121-1 (PTD #2021350) continued to show signs of IA repressurization when on MI injection and was shut in. An MIT -IA passed on 12/18/16, confirming two barriers to formation. The well is now reclassified as Operable and is ready to be put back on PWI injection only. Please use caution when bringing online as the annuli are fluid packed. MEMORANDUM TO: Jim Regg 5I �lZozo P.I. Supervisor i FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commimiou DATE: Monday, April 27, 2020 SUBJECT: Mechanical Integrity Tests BP Epilmation (Alaska) Inc. 5-112 PRUDHOE BAY UN AURO 5-112 Sm: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-112 API Well Number 50-029-23099-00-00 Inspector Name: Austin McLeod Permit Number: 202-135-0 Inspection Date: 4121/2020 ✓ Insp Num: mitSAM200421151035 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min _ 60 Min Well 5-112 " Type InJ W, TVD 6852 Tubing 2420 2470J3204 2426 2425 ' PTD` 2021550 Type Test SPT Test psi 3300 IA 679 ,zoo1sz36BBL Pumped: 3 9 BBL Returned: 2s OA r 3 0ls 107 ' Interval REQVAR P/F P Notes: 2 year to MAIP. AIO 22D.001 Monday, April 27, 2020 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 03,2018 TO: Jim Regg B -, P.I.SupervisorF----71 ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-112 FROM: Adam Earl PRUDHOE BAY UN AURO S-112 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry '2--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-112 API Well Number 50-029-23099-00-00 Inspector Name: Adam Earl Permit Number: 202-135-0 Inspection Date: 4/8/2018 Insp Num: mitAGE180409142133 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-112 ' Type Inj W TVD 6552 - Tubing 2350 • 2356 - 2355 - 2330 PTD 2021350 Type Testl SPT Test psi 1638 IA 485 3295 - 3181 3144 - BBL Pumped: 3.7 BBL Returned: 2.6 OA 0 1 156 - 115 80 Interval REQVAR P/F P Notes: MIT/IA Tested as per AIO 22D.001 SCANNED Thursday,May 03,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com> Sent: Wednesday, December 21, 2016 2:35 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK,OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS WELL PAD S;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA);AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector S-112L1 (PTD#2021350) Return to Water Injection All, Injector S-112L1 (PTD #2021350) continued to show signs of IA repressurization when on MI injection and was shut in. An MIT-IA passed on 12/18/16, confirming two barriers to formation. The well is now reclassified as Operable and is ready to be put back on PWI injection only. Please use caution when bringing online as the annuli are fluid packed. Ryan Moore Well Integrity/Down Hole Diagnostics (907)659-5525 Office (805)550-5342 Cell Harmony#5415 Alternate: Josh Prowant • GW �•p Global izaticls SCANNED JAN 3. 0 2017 OrganFro . , GWO SUPT Well Integrity Sent: Monday, :; -mber 05, 2016 12:16 PM To: AK, OPS GC2 OSM; - OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS WELL PAD S; AK, OPS Prod Co 'Hers; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt • • AK, RES GPB East Wells Opt Engr; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWS ojects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; F Wig, James B(DOA) (jim.regg(aalaska.gov)'; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Mun Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras J Subject: NOT OPERABLE: Injector S-112L1 (PTD #2021350) ••ing x Inner Annulus Communication on MI Injection All, Injector S-112L1 (PTD #2021350)was brought online Under Evaluation on 11/1• 6, injecting MI.The well operates under Administrative Approval AIO 22D.001, which restricts the well to water injecti•• only due to T x IA communication previously observed on MI.The AOGCC granted a temporary deviation to the AA, allowi = up to 30 days of MI injection, to evaluate whether remedial work completed on 09/13/16 had repaired the communication. fter approximately one week, the IA began to exhibit repressurization. The well is reclassified Not Operable, and should be shut in as soon as operationally feasible. It musfremain shut in until ready to resume water injection; there will be no application to cancel the AA. 1 Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, December 05, 2016 12:16 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS WELL PAD S;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA);AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington,Aras J Subject: NOT OPERABLE:Injector S-112L1 (PTD#2021350)Tubing x Inner Annulus Communication on MI Injection All, Injector S-112L1 (PTD #2021350) was brought online Under Evaluation on 11/19/16, injecting MI. The well operates under Administrative Approval AIO 22D.001, which restricts the well to water injection only due to T x IA communication previously observed on MI. The AOGCC granted a temporary deviation to the AA, allowing up to 30 days of MI injection, to evaluate whether remedial work completed on 09/13/16 had repaired the communication. After approximately one week, the IA began to exhibit repressurization. The well is reclassified Not Operable, and should be shut in as soon as operationally feasible. It must remain shut in until ready to resume water injection; there will be no application to cancel the AA. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 SCANNED JAN . 0 2017, C:(907)943-0296 H:2376 From: AK, GWO SUPT Well Integrity Sent: Fri.: November 18, 2016 2:38 PM To: AK, GWO So' ell Integrity; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, 0• • C Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB '- ells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Bronga, Jaime; Bergene, Matthew; 'chris.wallace ska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Prof- -- Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; 'Regg, James B (D• ;'m.regg@alaska.gov)'; Wellman, Julie; Holt, Ryan P; AK, GWO Well Integrity Well Information; AK, GWO Completions We • egrity; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, •itney; Tempel,Troy; Worthington, Aras J Subject: UNDER EVALUATION: Injector S-112L1 (PTD #2021350) Evaluate Communication on MI Injection All— Injector S-112L1 (PTD#2021350) is a recently-completed coiled tubing drilling sidetrack. Th ell had a known one-way leak from the tubing to the Inner Annulus at the sliding sleeve. An isolation slee as set in the leaking sliding sleeve and and a subsequent MIT-IA passed on 05/15/16 proving two competent 1 S S . • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, November 18, 2016 2:38 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5; Bronga, Jaime; Bergene, Matthew; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; Regg,James B (DOA); Wellman,Julie; Holt, Ryan P;AK, GWO Well Integrity Well Information;AK, GWO Completions Well Integrity;AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney;Tempel,Troy; Worthington,Aras J Subject: UNDER EVALUATION:Injector S-112L1 (PTD#2021350) Evaluate TxIA Communication on MI Injection All— Injector S-112L1 (PTD#2021350) is a recently-completed coiled tubing drilling sidetrack. The well had a known one-way leak from the tubing to the Inner Annulus at the sliding sleeve. An isolation sleeve was set in the leaking sliding sleeve and and a subsequent MIT-IA passed on 05/15/16 proving two competent barriers. The well was reclassified as Operable on 06/04/16 and subsequent water only injection showed no indication of amomolous behavior. As an alternative to cancelling the existing Adimistrative Approval, the AOGCC has granted BP a temporary deviation from the AA to for MI injection as Under Evaluation to monitor for TxIA communication. Plan Forward: 1) Well Integrity: Reclassify as Under Evaluation — Done 11/18 2) Operations: Put well on MI Injection 3) Downhole Diagnostics: Monitor for TxIA Communication while on MI 4) Fullbore Pumping: MITIA while on MI 5) Well Integrity: Application to cancel the AA 22D.001 could follow. Please respond if in conflict with proposed plan. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W: 907.659.5102 SCANNED NOV 2 22016 C: 907.943.0296 H:x2376 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, September 21, 2016 8:41 AM To: 'AK, GWO SUPT Well Integrity' Subject: RE:Injector S-112L1 (PTD#2021350) - Evaluate TxIA on MI Service Jack, Assuming the well has integrity to MI after your troubleshooting and repairs,you are approved for up to 30 days MI injection for diagnostics and monitoring prior to a state witnessed MITIA while on MI. All being well and with the new MI data in hand, an application to cancel the AA 22D.001 could follow. 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: AK, GWO SUPT Well Integrity [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Tuesday, September 20, 2016 4:16 PM To: Wallace, Chris D (DOA) Subject: Injector S-112L1 (PTD #2021350) - Evaluate TxIA on MI Service Chris— Injector S-112L1 (PTD#2021350) is a WAG well that currently operates under AA 22D.001 for TxIA comm when on MI, and is PWI only at this time. In April 2016 a CTD sidetrack was completed to a new target. At this time BP indicated intent to return,or attempt to return,this well to MI service at some point in the near future, roughly 2 years. The well is currently Operable,on water injection,with the most recent MIT-IA passing to 3177 psi on 06/10/16. Reservoir development has a need for this well to be on MI sooner than anticipated and would like to get this well on MI in the very near future. To mitigate the TxIA Communication while on gas,first tubing integrity was confirmed to 3,467 psi by pulling the isolation sleeve from the sliding sleeve, installing a nipple reducer below the sliding sleeve, setting a plug in the nipple reducer, cycling the sliding sleeve, re-installing the isolation sleeve across the sliding sleeve, performing the MIT-T, and pulling the plug.This testing confirmed the tubing integrity,to liquid.To prepare the well for MI injection, an MCX was set in the SSSV nipple. As an alternative to cancelling the existing AA, we would like to pursue a temporary deviation from the AA to allow the well to be put on MI injection Under Evaluation to monitor for TxIA communication. Historical MI injection pressure indicates max injection pressure of 3300 psi. As discussed the most recent MIT-IA passed to 3177 on 06/10/16. The most recent MIT-IA above max injection pressure passed to 3600 psi on 04/30/2014, which is outdated per 24 month requirement in AA. Once the well has been POI and if the TxIA Comm has been mitigated BP would then perform an updated AOGCC MIT-IA to above max injection pressure. Are you in conflict with this proposal? SCANNED NOV 0 4E016 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Convert to Injector 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-135 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23099-00-00 7. Property Designation(Lease Number): ADL 028257 8. Well Name and Number: PBU S-112 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 8642 feet Plugs measured None feet true vertical 6743 feet Junk measured None feet JUN 2 2 2016 Effective Depth: measured 8642 feet Packer measured 6658 feet J U v true vertical 6743 feet Packer true vertical 6552 feet AOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 117 20"X 34" 36-153 36-153 Surface 2880 9-5/8" 35-2915 35-2878 5750 3090 Intermediate 6793 7" 32-6825 32-6667 7240 5410 Production Liner 1825 4-1/2" 6710-8535 6589-6753 8430 7500 Perforation Depth: Measured depth: 6900 8642 feet .SCA*NE10 DEC 0 6 ZQIQ True vertical depth: 6711 -6743 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-6718 30-6595 Packers and SSSV(type,measured and 5"Baker PRM Prod Packer 6658 6552 true vertical depth) 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: 96 1539 1990 1400 1850 Subsequent to operation: 1877 160 2150 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 0 Service Q Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG lf GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bronga,Jaime Email Jaime.Bronga@bp.com Printed Name Joe Lastuf a Title Drilling Technologist Signature k k_ l_. Phone +1 907 564 4091 Date b/n/I Form 10-404 Revised 5/2015 V 7-1.- "7-/ ///l- - 77,4 RBDMS of JUN 2 2 2016 �! 4 Submit Original Only • S-112 Well History T/I/O=S1/900/0. Post Nordic 2, R/D TS#05, and XO#05, R/D IA Temp#95 and comp IA 5/13/2016 Temp#43. PT tree cap to 500 psi. Pass. Job Complete. FWP's SI/900/0 see log for details. T/I/0=50/850/20 Temp=SI Assist SLB Slickline (CTD) No fluids pumped, Travel to location 5/14/2016 and Rig up ***JOB IN PROGRESS, CONTINUED FROM 5/13/16 WSR***(ctd). DRIFT & BRUSH TO 6,670' SLM W/4-1/2" BRUSH, 3.80" GAUGE RING (no issues, brush jewelery). SET 4-1/2" ISOLATION SLV(oal 54", id 2.50") IN BAKER CMD SSD @ 6,596' MD. 5/14/2016 RAN 4-1/2" CHECK SET TO ISOLATION SLV @ 6,596' MD (sheared). LRS Well Test Unit 1. S-112 L1 Post CTD Injector Flowback and Tests. Perform Unit move. SB for SLB( Idle Time). Rig Up. SB for Grease Crew( Idle Time). PT. POP Well. Flow/ 5/15/2016 Stabilize Well. Inlet Well S-112. Outlet Well S-118. ***Continued from 5-14-16*** MIT-IA to 3225 psi ***PASSED*** Pumped 2 bbls of 50* Diesel down IA to reach test pressure. First 15 minutes IA lost 46 psi. Second 15 minutes IA lost 15 psi. Total loss of 61 psi. Bled back -2 bbls. SLB Slickline in control of well upon LRS departure 5/15/2016 FWHP=72/498/0 ***JOB IN PROGRESS, CONTINUED FROM 5/14/15 WSR***(ctd). LRS PERFORMED PASSING MIT-IA TO 2930 psi. SET 4-1/2"WHIDDON C-SUB © 6,570' SLM. PULLED ST#2 &ST#3 BK-DGLV(ext packing). SET ST#3 BK-LGLV(1/4", 1500#) @ 3,850' MD. SET ST#2 BK-OGLV(20/64") @ 5,654' MD. PULLED EMPTY 4-1/2"WHIDDON C-SUB FROM 6,570' SLM. 5/15/2016 ***WELL S/I ON DEPARTURE***(pad op notified=job complete, well &well head status). LRS Well Test Unit 1. S-112 L1 Post CTD Injector Flowback and Tests. ***Continued from WSR 5/15/16 ***Continue to Flow/Stabilize Well. Increase GLR per generic unloading 5/16/2016 procedure. Begin 12 Hr Test. Inlet Well S-112. Outlet Well S-118. LRS Well Test Unit 1. S-112 L1 Post CTD Injector Flowback and Tests. ***Continued from WSR 5/16/16 ***Complete 12 Hr Test. Continue to Flow/Stabilize Well. Perform 6 Hr Test (Results for 2nd Test on WSR 5/18/16). Continue Flowback Until FP Arrives. Shut in S-112. 5/17/2016 SB for Freeze Protect. Begin Rig Down. Inlet Well S-112. Outlet Well S-118. T/I/O= 350/1000/0. Assist well testers with tbg freeze protect. Pumped 38 bbls of 50/50 down TBG. FW HP: 800/1000/0 5/17/2016 SV, WV= Closed SSV, MV, IA, OA = Well Testing crew LRS Well Test Unit 1. S-112 L1 Post CTD Injector Flowback and Tests. ***Continued from WSR 5/17/16 ***6 Hr Well Test from WSR 5/17/18. Continue Rig Down. SB for High Winds. 5/18/2016 Inlet Well S-112. Outlet Well S-118. ***Job Complete *** T/I/O=1200/933/vac Assist Slick line(Brush & Flush Tbg) Pumped 100 bbls 180* hot DSL 6/1/2016 down TBG for brush-n-flush. ***Job continues 06/02/16 WSR*** ***WELL S/I ON ARRIVAL*** (ctd) ATTEMPT TO SET 4-1/2"X-CATCHER(keyless)AT 6,596' MD DRIFT W/3.75" G-RING TO 6,578' SLM RAN 4-1/2" BRUSH & 3.25" G-RING TO 6,596' MD W/ LRS PUMPING 180* HOT DIESEL (100 BBLS) SET 4-1/2"X-CATCHER(keyless)AT 6,596' MD 6/1/2016 RAN 3.55" BLIND BOX TO FIND FLUID (at surface) ***Job continued from 06/01/16 WSR*** Assist Slick line (Brush & Flush Tbg) . Pumped 174 bbls Diesel down IA to correct overbalance, and load IA. Pumped 150 bbls 1% KCL 6/2/2016 down TBG to kill TBG psi. • • S-112 Well History T/I/O = 1780/1675/VAC. Temp =SI. T & IA FL (SL request). T FL @ 2802'. IA FL @ 4521'. 6/2/2016 SL in control of well upon departure. ***CONT FROM 6-1-16 WSR***(ctd) PULL BK-OGLV FROM STA. #2 AT 5,654' MD ATTEMPT TO PULL BK-DGLV FROM STA# 1 AT 6,529' MD (3/4"x 3/8"x 1/4" metal from pulling tool lih) PULL BK-DGLV FROM STA. #1 AT 6,529' MD PULL BK-LGVL FROM STA. #3 AT 3,850' MD SET BK-DGLV(extended packing) IN STA. #3 AT 3,850' MD SET BK-DGLV(extended packing) IN STA. #2 AT 5,654' MD LRS LOAD I/A WITH 140 BBLS OF DIESEL SET BK-DGLV(extended packing) IN STA. #1 AT 6,529' MD 6/2/2016 PULL EMPTY CATCHER FROM 6,596' MD ***CONT FROM 6-2-16 WSR*** (ctd) LRS PERFORMED PASSING MIT-IA TO 3,000 psi 6/3/2016 'WELL S/I ON DEPARTURE *** ***Job continued from 06/02/16 WSR*** Assist SLB MIT-IA @ 3210 ***PASS***. Pumped 0.95 bbls Diesel down IA to achieve test pressure. 1st 15 minutes lost 70 psi. 2nd 15 minutes lost 15 psi, for a total 30 minute loss of 85 IAP. Pumped 38 bbls diesel down TBG to Freeze protect, pumped 3 bbls 60/40 down flowline, and .5 bbls 60/40 up S-Riser. SL on well @ LRS departure. AFE and caution tags/freeze prot. tags hung. WV=closed, 6/3/2016 IA/OA=OTG. Double plug behind wellhouse closed. FWHP= 1716/0/vac T/I/O= 2357/791/514 Temp=INJ AOGCC MIT-IA **PASSED**to 3177 psi (CTD) Witnessed by Lou Grimaldi. Pumped 2.5 bbls dsl into IA to reach test pressure. 15 min IA lost 105 psi. 30 min IA lost 13 psi. Total loss of 118 psi in 30 mins. Bled IAP abck to 558 psi. Bled back 2.4 bbls. FWHP= 2356/680/580 **Fluid packed tags hung on IAV and WV** 6/10/2016 **AFE sign hung on MV** • V LI- FMC 41/16"5M S_I 12 SA c RTES:WELL ANGLE>70 WELLHEAD= FMC GEN 5 7026'"' H2S ACTUATOR= BAKER L1 READINGS AVERAGE 125 ppm WHEN ON MI•"'WELL OKB ELEV= 6960 REQUIRES A SSSV WHEN ON MI'*' BF.ELEV= -----J [1 KOP= 5626' Max Angle= 96"@ 745T 20'X34', —) 114' 2257' H4-112"HE5 X NP,ID=3.813' Catum MD= 7031' 215.5 blit.A53 Datum TVD= 6700'SS MVV INSULATED AS LFT MANDFil LS 9-5/8"CSG,40#,L-80,BTC,D=8.750" —{ 2915' ST MD TVD DEV 'TYPE VLV LATCH PORT DATE 3 3850 3813 1 KGB2 'DMY BK 0 06/02/16 Minimum ID =2.50" @ 6596' 2 5654 5616 1 KGB2 'DMY BK 0 06/02/16 4-1/2" ISOLATION SLEEVE 1 6529 6451 35 KGB2 'DMY BK 0 06/02/16 *ALL STATIONS=EXTENDED PACKNG 4112"ISOLATION SLV,la=2.50"(05/14/16) — 6596' I m_ill 6596 —4-1/2'BKR SLO SLV,D=3.813" *ONE WAY LEAK TOW WHEN ON AA NJ M ICI 6668' H 7"X 5"BKR PRM NKR,13=3.875' III 6685' —14-1/T t 5 X 4',D=3.813" 6706' -4112"HES XN NP PALLED TO 3.80"(02/26/16) 4-1/2"TBG, 12.75#,L-80 TCS,.0152 bpf,D=3.958" H 6718' ,7,-. 6710' -dr X 5"BKR ZXP LIP,D=4.390' 6718' --141/2'WLEG,D=1958" 6729 —7'X 5"BKR HMC LIR HGR,ID=5.03" 6735 H5"X 4-1/2 XO BUSHING,D=3.89" 7"CSG,26#,L-80,D=6.276" H 6825' PERFORATION SUMMARY 6863 H4-1/2"MARKER JOINT W!RA TAG REF LOG: ANGLE AT TOP FffiF: MA MILLOUT WINDOW(S-112 L1) 6912'-6920' Note: Refer to Production OB for historical perf data SIZE SFF NTERVAL Opn/Sqz SHOT SOZ ' 6957 -3.625"SHORTY DEPLOY SLV,D=2.370" 5-112 3-3/8" 6 6900-6925 0 04/29/03 6958'-6989' 2-7/8"SOLD LNR,6.4#,L-80 STL, 3-3/8" 6 6960-6976 0 04/29/03 .0058 bpf,D=2.441" 4-1/2" SLTD 7650-8535 SLOT 07/29!02 S-112 L1 .. 8054 1 FISH MOTOR 2-7/8" SLID 6989-8054 SLOT 04/21/16 BIT FISH 4-1/7 I�aCV MONTER H 7523' 4 i 2-7/8"SLID LNR, 6989'- S-112 L1 41/2"CEMENTED PAY ZONE ECP,D=3.937" 7542' ' 6.4#,L-80 HYD 511, 8054' I i .0058 bpf,D=2.441" ' 4-1/4"OPEN HOLE TD —I 809T • 5-112 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" --I 8535' DATE REV BY COMVEJTS ' DATE REV BY COMVENTS AURORA UNIT 08/07/02 D-14 IMTIAL COMPLETION 05/18/16 NXW/JMD GLV 0/0(05/15/16) WELL: 5-112 L1 04/24/16 NORDIC2 CTD(5-112 L1) 06/06/16 JMG/JMD GLV C/O(06/02/16) PERMT Pb: 2021350(2157,20 04/28/16 JMD DRLG HO CORRECTIONS AR No: 50-029-23099-00/60 05/03/16 TT/JMD MINOR EDITS SEC 35,T12N,R12E,949'FTL&780'FWL 05/04/16 TT/JA/113 FINAL ODE APPROVAL 05/18/16 RCT/JMD SET LSO SLEEVE(05/14/16) BP Exploration(Alaska) r 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Tuesday,June 14,2016 TO: Jim Regg P.I.Supervisor `��1l ��i4 f SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-112 FROM: Lou Grimaldi PRUDHOE BAY UN AURO S-112 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry I t-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-112 API Well Number 50-029-23099-00-00 Inspector Name: Lou Grimaldi Permit Number: 202-135-0 Inspection Date: 6/10/2016 Insp Num: mitLG160611100237 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-112 ' Type Inj W- TVD 6552 Tubing 2364 - 2364 - I 2363 - 2364 i PTD 1 2021350 ' Type Test SPT Test psi 3295 . IA 842 3295 - 3190 - 3177 - Interval REQVAR P/F P ✓ OA 519 806 - 786 776 Notes: Test req.by A1022D.001.Good test.2nd attempt today,1st attempt aborted due to surface equipment leak.2.5 bbl's diesel pumped,2.4 returned.PWI inj.Header pressure reported by pad operator as 2700 psi max.All pertinent paperwork supplied before test by Josh Murphy. ANNE® DEC 2 9 2016 Tuesday,June 14,2016 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, June 04, 2016 9:34 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5; Bronga, Jaime; Bergene, Matthew; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Dickerman, Eric; Regg, James B (DOA); Wellman, Julie; Holt, Ryan P Subject: OPERABLE:Injector S-112L1 (PTD #2021350) Post-Sidetrack MIT-IA Passed All, Injector S-112L1 (PTD #2021350) is a recently-completed coiled tubing drilling sidetrack. The well had a known one-way leak from the tubing to the Inner Annulus at the sliding sleeve. The well is approved for produced water injection only. During the course of the pre-rig work the sliding sleeve began leaking to fluid. The tubing and IA began tracking when pumping into the well, and the well subsequently failed an MIT-T, but passed a combination MIT-TxIA, proving competent production casing. An isolation sleeve was set in the leaking sliding sleeve and and a subsequent MIT-IA passed. After flowback another MIT-IA passed proving two competent barriers. This well is now reclassified as Operable. Once put on injection an AOGCC MIT-IA will be performed. Plan Forward: 1. Slickline: Install isolation sleeve across sliding sleeve, install live gas lift valves - DONE 05/15/16 2. Fullbore: MIT-IA to 3130 psi - PASSED 05/15/16 3. Well Testing: Flow back drilling fluids — DONE 05/18/16 4. Slickline: Set dummy gas lift valves — DONE 06/03/16 5. Fullbore: Circulate IA to diesel, MIT-IA— DONE 06/03/16 6. Operations: Put on produced water injection (mind fluid packed annuli) 7. DHD: AOGCC-witnessed MIT-IA Please mind the fluid packed annuli when putting well on injection. Thanks! '—. .... Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent SCANNEDJUN 1 3 2016 W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, D& me rity Coordinator Sent: Sunday, May 15, 2016 6: To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M T-C -Q S GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC 1 `� • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, May 15, 2016 6:29 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5; Bronga, Jaime; Bergene, Matthew; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector S-112 (PTD #2021350) Post-Sidetrack Flowback 7r&lM►!!1! ? t,"i'? 1 8 [D All, Injector S-112L1 (PTD #2021350) is a recently-completed coiled tubing drilling sidetrack. The rig moved off the well on 23rd April 2016. The sidetrack was cut short due to a troublesome fault crossing (unable to drill into the desired sand in the target fault block), and TD was called approximately 1110' shorter than planned. The rig ran a slotted liner rather than the originally planned cemented and perforated completion, and left 10.1 ppg drilling mud in the well instead of circulating the well to inhibited brine. The well has a known one-way leak from the tubing to the IA at the sliding sleeve (62' above the production packer)when on MI injection, and operates under AA AIO 22D.001 for TxIA communication when on MI. The well is approved for produced water injection only. During the course of the pre-rig work, it became evident that the sliding sleeve had started leaking to fluid. The tubing and IA began tracking when pumping into the well, and the well subsequently failed an MIT-T, but passed a combination MIT-TxIA, proving competent production casing. The following changes to the post-rig work plan, outlined in Sundry#316-043, were approved by the AOGCC on 04/29/16: • Post-rig flowback period, originally planned for 1-2 weeks, shortened to approximately 2-6 days. New objective is simply to produce back the 10.1 ppg drilling mud and solids left in the hole prior to returning the well to injection service. Target is to recover 5000 bbl of fluid. • Prior to flowback, set isolation sleeve in the leaking sliding sleeve, and test by performing an MIT-IA. The well is reclassified as Under Evaluation, in order to flow back the drilling fluids. Plan Forward: 1. Slickline: Install isolation sleeve across sliding sleeve, install live gas lift valves - DONE 05/15/16 2. Fullbore: MIT-IA to 3130 psi - PASSED 05/15/16 3. Well Testing: Flow back drilling fluids 4. Slickline: Set dummy gas lift valves 5. Fullbore: Circulate IA to diesel, MIT-IA 6. Operations: Put on produced water injection 7. DHD: AOGCC-witnessed MIT-IA Please reply if in conflict with proposed plan. Thanks, 1 Adrienne McVey • i Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: 26 February 2016 19:37 To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wel!pad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; Bronga, Jaime; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.reqg@alaska.gov) Subject: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed All, Injector S-112 (PTD#2021350) currently operates under AA22D.001 for known slow tubing by inner annulus communication,with a passing MIT-IA performed January 12, 2016.The well was scheduled for wellwork which necessitated producing the well prior to sidetracking in order to lower the downhole pressure.The well has begun showing signs of more rapid annulus communication and failed a subsequent MIT-T on February 24, 2016.The well has been reclassified as Not Operable and will not be brought online until well integrity can be restored downhole. Please call with any questions. Thank you, Kevin Parks (Alternate: Whitney i ett— BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com 2 • • PTD 20z-1.35— Loepp, 0z-135— Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Friday,April 29, 2016 11:01 AM To: Youngmun,Alex;AK, D&C Well Integrity Coordinator (AKDCWelllntegrityCoordinator@bp.com) Cc: 'Lastufka,Joseph N' Subject: NOT OPERABLE:Injector S-112 (PTD#2021350, Sundry 316-043) Sundry Modifications Approved Follow Up Flag: Follow up Flag Status: Flagged Alex,Joe, Approval is granted for the modifications to Sundry 316-043 as indicated in red including utilizing gas lift to clean up the well of drilling fluids. Please include this approval with the approved sundry for documentation. Note that a State witnessed MIT-IA is required after stabilized injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer SED MAY 0 9 �Q1�. State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa,alaska.cov CONFIDENTIALITY NOTICE: 'i his 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 Victorialoem@alaska.gov From: Youngmun, Alex Sent: Thursday, April 28, 2016 12:33 PM To: Lastufka, Joseph N Subject: RE: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed If the blanking sleeve leaks,the plan is to run a MLDL to determine any potential other leak point sources.The proposed plan is to then install a generic GL design to allow the well to be temporarily produced to a cleanup the well of drilling fluids. Wireline will return post flowback, dummy the GLV's,troubleshoot and work to mitigate the TxIA communication to fluid prior to placing back on injection. S-112 will not be placed on PWI until its passes integrity testing. Let me know if any further information or discussion is needed. Thanks, Alex 1 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, April 28, 2016 11:22 AM To: Lastufka, Joseph N Subject: RE: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed If the blanking sleeve leaks and the drilling mud is allowed to be lifted out with gas lift, what is the future plan for this well? From: Loepp, Victoria T(DOA) [nailto:victoria.loepp@alaska.gov] Sent: Thursday, April 28, 2016 10:45 AM To: Lastufka, Joseph N Subject: RE: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed Please send current schematic. From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Tuesday, April 26, 2016 9:35 AM To: Loepp, Victoria T(DOA) Subject: FW: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed Victoria, Please let me know if you have any questions or require additional information. We plan on beginning the work within 2 weeks. Thanks, Joe From: AK, D&C Well Integrity Coordinator Sent: Monday, April 25, 2016 2:29 PM To: Lastufka, Joseph N Cc: Youngmun, Alex; Allely, Josh; AK, D&C Wells Slickline Coordinator; AK, D&C Well Testing WSL; Sternicki, Oliver R Subject: RE: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed Joe, The post-rig plan for S-112, as outlined in the approved Sundry, has changed. I am thinking we might need an updated approval and sundry. Summary below: • Injector S-112 (PTD#202-135) operates under AA AIO 22D.001 for TxIA communication when on MI. The well is approved for produced water injection only. Most recent MIT-IA was 12th January 2016— passed to 3000 psi. AOGCC-witnessed MIT-IA is due 25th April 2016. • Permit to Drill a CTD sidetrack, S-112L1 (PTD#215-222), was approved 14th January 2016. • Sundry# 316-043 was approved 26th January 2016. The Sundry allowed for combined pre-and post- rig flowback for a period of time greater than 30 days, and delaying the AOGCC-witnessed MIT-IA until post-rig flowback is completed. The wellbore schematic for the proposed CTD sidetrack included in the Sundry application noted a one-way leak from the tubing to the IA at the sliding sleeve (62' above the production packer) when on MI injection. • During the course of the pre-rig work, it became evident that the sliding sleeve had started leaking to fluid. The tubing and IA began tracking when pumping into the well, and the well subsequently failed an 2 • MIT-T, but passed a combination MIT-TxIA, proving competent production casing. The well was declared Not Operable on 26th February 2016 (see e-mail below). • An e-line leak detect log on 2nd March 2016 confirmed the leak at the sliding sleeve. No other leaks were found. • The CTD rig moved off the well on 23rd April 2016. The sidetrack was cut short due to a troublesome fault crossing (unable to drill into the target fault block), and TD was called approximately 1110' shorter than planned. The rig ran a slotted liner rather than the originally planned cemented and perforated completion, and left 10.1 ppg drilling mud in the hole instead of circulating the well to inhibited brine. As a result, the post-rig flowback period, originally planned for 1-2 weeks, has been shortened to approximately 2-6 days. The new objective is simply to produce back the 10.1 ppg drilling mud and solids left in the hole prior to returning the well to injection service. Target is to recover 5000 bbl of fluid. Prior to the flowback, a blanking sleeve would be set in the leaking sliding sleeve, and tested by testing the IA to 2500 psi. Three key changes to the plan in the approved Sundry: 1) Shortened post-rig flowback period 2) Set and test blanking sleeve in leaking sliding sleeve prior to post-rig flowback 3) In the event that the test of the blanking sleeve fails and the sliding sleeve still leaks, would the AOGCC deem it acceptable to proceed with temporarily producing the well with gas lift, just until we recovered the drilling mud left in the hole? Original planned steps from the approved sundry are in black below, with red text added to describe the proposed changes. Plan Foward Testers 1. Produce S-112 in attempt to reduce BHP from 3607psi to 3415psi. a. Flowback 10,000 bbl of fluid in 2 to 4 weeks. b. Complete by end of February 2016. DONE - Pre-rig pre-production completed 5th February Pre Rig Work 2. Complete Pre-Rig work including setting Whipstock, milling XN Nipple, and setting TWC. DONE — Pre- rig work completed 10th April 2016. During the pre-rig work, it became evident that the sliding sleeve (62' above the production packer) had started leaking to fluid. Coil Tubing Drilling 3. Drill S-112L1 from April 3 to April 19, 2016. DONE— Rig moved off 23rd April 2016 Slickline 4. Install blanking sleeve across leaking sliding sleeve. Test IA to 2500 psi to test blanking sleeve. Install generic GLV for flowback. Fullbore 5. Assist Slickline with testing blanking sleeve. Testers 6. Pre-Produce S-112/L1 for 1 to 2 weeks 2 to 6 days (target 5000 bbl of fluiL to clean up well prior to putting on water injection. Slickline 7. Dummy gas lift valves with extended packing 3 • • Fullbore 8. Circulate IA to inhibited brine / diese'� Perform MIT-IA to verify mechanical integrity post valve changeout. Downhole Diagnostics 9. Perform online AOGCC MIT-IA Operations 10. Inject Produced Water for 1 to 2 years. Eline 11. Set Patch to mitigate TxIA communication Operations 12. Put well on MI injection Well Integrity Engineer 13. Evaluate cancellation of AA Alex is the PE, and should be able to provide you with any additional information. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate: Jack Lau) Office: (907)659-5102 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, February 26, 2016 7:37 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Welipad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; Bronga, Jaime; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.regg©alaska.gov) Subject: NOT OPERABLE: Injector S-112 (PTD #2021350) MIT-T Failed All, Injector S-112 (PTD#2021350)currently operates under AA22D.001 for known slow tubing by inner annulus communication,with a passing MIT-IA performed January 12, 2016.The well was scheduled for wellwork which necessitated producing the well prior to sidetracking in order to lower the downhole pressure.The well has begun showing signs of more rapid annulus communication and failed a subsequent MIT-T on February 24, 2016.The well has been reclassified as Not Operable and will not be brought online until well integrity can be restored downhole. Please call with any questions. Thank you, 4 • • Kevin Parks (Alternate: Whitney Pettus) BP Well Integrity Coordinator A Global Weds ILO Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 5 TREE= FMC4-1/16"5MIII WS 112 E LHEAD= FMC GEN 5 lift NOTES:WELL ANGLE>70 @ 7026' H2S ACTUATOR= BAKER JMD DRAFT L1 REACINGS AVERAGE 125 ppm WHEN ON MI WELL OKBELEI/= 69.60' " y REQUIRES A SSSV WHEN ON MI• BF.EI.J=V= ___--I l KOP= 5626' Max Angle= 96' It 7457' 20'X34", H 114' , 2257' -4-1/2"HES X NP,D=3.813" Datum MD= 7031' 215.5 lb/ft.A53 Datum IV D= 6700'SS ERw NSULA I:t) 9-5/8'CSG,40#,L-80,BTC,ID=8.750" --I 2915' —A GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3850 3813 1 KGB2 DOME BK 16 01/14/16 2 5654 5616 1 KGB2 SO BK 20 01/14/16 1 6529 6451 35 KGB2 'DMY BK 0 06/25/07 EXTENDED PACKING Minimum ID = 3.725" @ 6706' I I 6596 4-1/2"BKR SLD SLV,D=3.813" 4-1/2" HES XN NIPPLE *ONE WAY sn,KTOWVVHENONMNJ R F 6658' -7"X 5"BKR PRM PKR,D=3.875' 6685' -4-1/2"I'IcS X NP,D=3.813' ' 6706' --{4-1/2"HES XN NP MLLED TO 3.80"(02/26/16) 4-112"TBG,12.75#,L-80 TCI,.0152 bpf,D=3.958' --1 6718' I 6710' -7'X 5"BKR ZXP LIP,D=4.390' i 'NN 6718' -14-1/2"WLEG,D=3.958" \'(' 6729 H7"X 5'BKR HMC LNR HGR,ID=5.03' 6735 —{5"X 4-1/2 XO BUSHING,ID=3.89" 7"CSG,26#,L-80,D=6.276" --I 6825' • ' PERFORATION SUMMARY 6863 —I4-1/2"MARKER JONT W/RA TAG REF LOG: ANGLE AT TOP PERF: N/A MLLOUT VWNDOW(S-112 L1) 6917-6920' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz SHOT SQZ S-112 6957 -3 625"SHORTY DEPLOY SLV,D=2.370" 3-3/8" 6 6900-6925 0 04/29/03 3-3/8" 6 6960-6976 0 04/29/03 4-1/2" SLTD 7650-8535 SLOT 07/29/02 447(''.*:- - - 5-112 11 1 FISH:MOTOR 2-7/8" SLTD 6989-8054 SLOT 04/21/16 BR FISH 9 4-1/2"HI/CV CEMENTER H 7523' /1:g,r7: '' ..:- 2-7/8'SLID LW, 1 6989'- 6.4#,L-80 HYD 521, 8054' 4-1/2"CEMENTED PAY ZONE ECP,D 7542' =3.937" — 0058 bpf,D=2.441" 5-112 Li ' 4-1/4"OFEN HOLE TD 8097' S-112 4-1/2"LNR, 12.6#,L-80 BTC-M,.0152 bpf,ID=3.958" —4 8535' A , . DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 08/07/02 0-14 INITIAL COMPLETION WELL: S-112 4.141-ib NOti01C2 CTD(S-122 L1) PVI _ T No: 2021350/ 04/28/16 JMD DRLG HO CORRECTIONS API No: 50-029-23099-00/ SEC 35,T12N,R12E,949'FNL&780'FWL BP Exploration(Alaska) • . ,. j /., Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Friday, April 15, 2016 11:15 AM To: Loepp, Victoria T (DOA); Brooks, Phoebe L(DOA) Subject: FW: S-112 Bottom Hole Pressure Follow Up Flag: Follow up Flag Status: Flagged fyi Jim Regg scow APR 2 9 2016 Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Tempel, Troy [mailto:Troy.Tempel@bp.com] Sent: Thursday, April 14, 2016 9:31 PM To: Regg, James B (DOA) Cc: AK, D&C Rig Nordic 2 Well Site Leader; O'Neal, Robert; Perl, John R; Schneider, Kenneth J Subject: S-112 Bottom Hole Pressure Jim, In regards to your question about the bottom hole pressure of S-112,a wireline gauge was ran on 3/26/16 and measured a datum pressure of 3384 psi at 6700'TVDss. Please let me know if you have any additional questions. Thanks, Troy T. Tempel CTD Engineer BP Exploration,Alaska Mobile:907-570-1351 Home:406-207-0766 Trov.Tempel@bp.com 1 p 19 Zv 2—1 3 3 1110 Loepp, Victoria T (DOA) From: Lastufka, Joseph N <Josephiastufka@bp.com> Sent: Thursday,January 21, 2016 11:06 AM To: Loepp, Victoria T (DOA) Subject: S-112 (PTD#202-135) Conversion from Injector to Producer Attachments: 2735_001.pdf Follow Up Flag: Follow up Flag Status: Flagged SCANNED MAY Y 9 2016 Victoria, Here is the proposal for conversion to Producer 10-403 which will be sent to you this afternoon.Can we begin the production of the well since the matrix specifies a 10-404 post conversion?Would a verbal approval be required if we intend to produce immediately? Please let me know if you have any questions, I appreciate your help. Thanks, Joe 1 • • by S-112 Injector Conversion Request BP Exploration (Alaska) Inc. requests approval for flowing back injector S-112 for a period of time greater than 30 days. This request will require the reclassification of S-112 from an injector to a producer. BP also requests a waiver to wait until drilling is complete and pre-production has ceased to complete an updated AOGCC MIT-IA per the AA. Intervention Engineer Jaime Bronga 907-564-4151 Production Engineer Alex Youngmun 907-564-4864 Background Injector S-112 (PTD 2021350) operates under Administrative Approval Area Injection Order (AIO) 22D.001 for tubing by inner annulus communication (TxIA comm) while on miscible injection (MI). S-112 is due for a AOGCC MIT-IA on April 25, 2016. This well is slated for a coil tubing drilling sidetrack adding a lateral spudding on April 3, 2016. The current bottom hole pressure, 3607psi, is above the maximum pore pressure of 9.8 ppg (-3415 psi at datum) for Nordic to sidetrack the well. The well is an Aurora injector located in a tight section of the Kuparuk C-Sands, resulting in low injectivity and slow communication with offset producers. The well has been offline since March 2015 and pressure decline was observed via static bottomhole pressure surveys and fluid level shots from April to December 2015. In December 2015, an increase in fluid level and tubing pressure was observed, indicating an increase in reservoir pressure. This was an unexpected result, but could possibly be explained due to the lack of production from offset producer S-26 in 4Q 2015 and baffled or delayed communication with new producer S- 42A to the north. As a first measure of reducing pressure at S-112, both offset producers (S-26 & S-109) were classified as "must-produce" and both nearby injectors (S-110B and S-123) have been shut in. Even with this measure in place to increase reservoir voidage, current models predict the reservoir pressure will still be too high to drill the well with Coiled Tubing Drilling in April, as currently scheduled. With this in mind, an injector flowback has been selected as the best method to decrease reservoir pressure in S-112 prior to the scheduled sidetrack date: April 3, 2016. On January 14, 2016, Slickline removed the dummy gas lift valves and set a live gas lift valve design modifying the well's mechanical integrity. The Well Integrity Coordinator notified the State via email of the modification as per the AA. The sidetrack is scheduled to finish on April 19, 2016. After the sidetrack the well will be pre-produced post rig for 1 to 2 weeks to clean-up the well prior to putting on water injection. After flowback, the injector will be marked as Not Operable until the well is ready to be placed on injection for an updated AOGCC MIT-IA. This will ensure no injection occurs in the well past the anniversary date of the AA until the well is ready for updated compliance testing. The well will be on water injection for 1 to 2 years prior to remedying TxIA communication and putting the well on MI injection. Objective 1. Pre-produce the well to reduce BHP to within acceptable range for drilling operations, 2. Pre-produce the well post sidetrack to clean up and put on water injection, 3. Obtain a waiver to complete AOGCC MIT-IA once well is put on water injection post sidetrack pre-production. • S Plan Foward Testers 1. Produce S-112 in attempt to reduce BHP from 3607psi to 3415psi. a. Flowback 10,000 bbl of fluid in 2 to 4 weeks. b. Complete by end of February 2016. Pre Rig Work 2. Complete Pre-Rig work including setting Whipstock, milling XN Nipple, and setting TWC. Coil Tubing Drilling 3. Drill S-112L1 from April 3 to April 19, 2016. Testers 4. Pre-Produce S-112/L1 for 1 to 2 weeks to clean up well prior to putting on water injection. Slickline 5. Dummy gas lift valves with extended packing Fulibore 6. Perform MIT-IA to verify mechanical integrity post valve changeout. Downhole Diagnostics 7. Perform online AOGCC MIT-IA Operations 8. Inject Produced Water for 1 to 2 years. Eline 9. Set Patch to mitigate TxIA communication Operations 10. Put well on MI injection Well Integrity Engineer 11. Evaluate cancellation of AA 2 • S TREE= FMC4-1/16'4-1116"5M w� ACTUATOR= BAKER C S w1 ■ - READINGSAVERAGE 125 ppm WN ON hU'"-WELL OKB_aEV= 69.60' REQUIRES A SSSV WHEN ON MI""" BF.BEV= KOP= 5626' Mix Angie= 96'@ 7457' Datum MD= 7031' Datum TVD- 6700'SS ■ L 2257' j--14-1/2-HES X NP,D=3.813" 20"X 34',215.5 D/ft.A53 B W INSULATED --F.-21W ■ 9-518"CSG,40#,L-80,BTC,D=8.750" —{ 2915' .--A GAS LFT M4NDFE.S ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3850 3813 1 Kr,/a7 "DM' BK 0 06725/07 2 5654 5616 1 KGB2 "DMY BK 0 06/25/07 Minimum ID=3.725"@ 6706' 1 6529 6451 35 KGB2 rotor BK 0 06/25/07 4-112" HES XN NIPPLE oc>fTNDeDPAacNG 6596 —[4 112"BKR SLD SLV,D=3.813" 6656' -{7"X5"BKR PRM PKR,D=3,875" ■ 6685" --14-112'1-cm X NP,D.3.813" ,■ { 6706' —4-1/2"HES XN NP,D=3.725" 4-1/2"TBG,12.75#,L-80 TQ.0152 bpf,D=3.958" — 6718' j--1 1:4 6710' —I 7'X 5'BKR ZXP LIP,D=4.390' {•� i 8718' --4-1/2"WLEG,D=3.958" 6729 --{7"X 5"BKR HMC LNR HGR,ID=5.03" 6736 H5"X 4-12 XO BUSHNG,D=3.89' 17"CSG,26#,L-80,13=6276" — 6825' 1--4 6863 R4-12'MARL JOINT W/RA TAG t FEFFORAT1ON SUMMA I 7523 —4-1/2'HMCV CEMENTER �' 7542' 4-12"CEMENTED PAYZONEECP,D=3.937" REF LOG: 777?ON XX/XXDOC '�1 ANGLE AT TOP PERE: 57'_ 690IY Note: Refer b Production DB for historical perf dela SIZE SPF !INTERVAL Opn/Sgz SHOT SQZ 3-3/8' 6 6900-6925 0 04/29/03 ' 3-3/8' 6 6960-6976 O 04/29/03 4-1/2' SLID 7650-8535 SLOT 07/29/02 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958' — 8635' -3—k LATE REV BY COMMENTS DAZE REV BY- COMMENTS AURORA UNIT 08107/02 D-14 INn1AL COMPLETION 01/06/14 JMG/PJC SET BLANKNG SLV(10/31/13) WELL S-112 04/29/03 JF/TP ADPG4 S 01/08/14 PJC TBG/LNR/PERF CORRECTIDNS pour No:12021350 06/15/03 JM'KAK GLV C/O 04/20/15 LECFJMD MND00l110N API No: 50-029-23099-00 06/25/07 SPF/PJC GLV CIO 07/01/15 TBD'JMD RLL ISO SLV/SET PXN PLUG SBC 35,T12N,R12E 949'FI&&780 FV& 02115/11 M3/J1v13 AWJDEDSSSV SAFETY NOTE 09/29/15 NLW/JWD RUB)PXN PLUG(09/26/15) 01/19/12 1144JM) ADDED I-QS SAFETY NOTE 12/16/15 EZ/JM) CHANGED4-1/2"TBG WEIGHT BP 6cploration(Alaska) 3 • TREE= FiK:4-1/16'Sr VELI1FM- NC 6915 S-1 1211 SRf$Y MOTES NELL AINLES n ® "' Ins s MIa ACTUATOR= BRIM CNE/10111165 AV ENA6E 125 ppw WHEN ON 111 les WELL €'°r RequirEsASSSVW ItONOIN1 OKB_REV= 69_67 Imo_ Rini Atilt= 96 745? Delm110= 703t Dablial/D= 67017 SS I I -4111REDRAW.D=3x13' 120r X 34.2155 ML A53 01W swum= 114' 9-5I6'C9v. um.U9C.o=s 7P -1 27115' (- ► GAS LFT INA DREZ S Sr IL IVO DEV TYPE VW LATCH PTJRr DATE L 3 3550 3613 1 KC82 "QTY OK 0 06125107 2 5654 5616 1 KGS 935Y OK 0 06125107 Minis ems =3.723" 6706' 1 6529 6451 315 03182 'OW OK 0 0625107 MED PACKING 4-112-IES XN NIPPLE ° XTE { 65'W -{4112'oat SLO sue:D=astir I ctn -,fie NO,/le.akIC i.A Arlen cn>,.11 in.ietia`i 2 1 Mar Hrxo'NKR FRIIENRD= 4 M' I soy E-4-irr iumxPA D=3813' I 6706' j-4 V2"HES3NP P..D=37715' 6701 -14112.FAR RIR i(08108115) 6716' -TX5'NKR 2]0°L7P,D=4.380' 412'7B%12.BIF.480 lq,10152 fapf.D=3958' 6718 -1---qt 6i -4111Yrl13a,D=3958' MR HTXV'010114L Lt 11GRD=SAW 67 I-5•x1-182xo eusiNG.D=389' 7'GSG.201F L-TOOL D=0578' - MeV I--41 111. ' 66&3 -4NI WAPNER JOINT WI.RA TAG 35 1= BUD 1aero PB 1 I 61 iIr.P ywnd:w -.1-1)2'Tnr: gra Rrr� .rani-nr 13.51, d';z MD TD a 9.216 MD • PSiFt)EiATDNSIMtAKY _ >^x pn=sc.e^__:so__� 9.19D MD•PGTD•ND ceme.• - 100 ???±ON30TDOTDOC ^ooe ... ng valee suC ANGLE ATTOP PFS 57'Q6900 O Cs I Mr H4-1r1'COMMIEDR YZOI*B'.D=3837 1 Mum RGferbI4od o•06 for MAN pertdIi SUE SPF INTERVAL Op&Sgt S601- SOZ 0-.--1 Hwy(8SOIK3t 3315' 6 6900-6925 0 0412903 3-31 6 6960-6976 0 0112963 4-112' SLID 7650-6535 SLOT 07129102 41114W.1Z..IR L-80 07c-y,0152 to.D=war H 6535' }- A---, DATE !NEVEM COMMIS DATE I V BY C001013ITS AURORA i1Q' 9657162 0-14 •TIAL MIMED= 01106114 Amt P'JC SET 6LANKI E SL.V(10131113) 111 131: 5-112 04129103 ifiP ALIS 011061.4 PJC TOGRJIR/RAF CORRECTIONS PER01111oc 2021360 06/15103 ANTAK GLV CID 0412015 LECPJID OBI D CORRECTOR AANoc 50-029-23099.00 0612567 SPI PJC GLV CJO 07101115 111111110 PALL 60 SLVJSET 0101 PLUG SEC 35,7'1711„R12E,843'HU.i 760 FAIL 0215111 AMID MITE)SSSV SAFETY MORE 0111912 TT/YYAD_ADDEO112S SAFETY WIE 6112Espfora iUU pinks) 4 • Boz-lam 11-4S WELL LOG TRANSMITTAL RECEIVED MAR 11 2015 DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. 3/tl4/201( M. K. BENDER AOGCC To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 gancpdc@bp.com and sameAPR 0 8 2016 ProActive Diagnostic Services, Inc. Attn: Diane F. Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 02-Mar-16 S-112 BL/CD 50-029-23099-00 2) Signed : pj oxi.teeet Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TtansmittalSheets\BP_Transmit.docx • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, February 26, 2016 7:37 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5;Zoesch, Eric; Bronga, Jaime;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: NOT OPERABLE:Injector S-112 (PTD #2021350) MIT-T Failed All, Injector S-112 (PTD#2021350)currently operates under AA22D.001 for known slow tubing by inner annulus communication,with a passing MIT-IA performed January 12, 2016.The well was scheduled for wellwork which necessitated producing the well prior to sidetracking in order to lower the downhole pressure.The well has begun showing signs of more rapid annulus communication and failed a subsequent MIT-T on February 24, 2016.The well has been reclassified as Not Operable and will not be brought online until well integrity can be restored downhole. Please call with any questions. Thank you, Kevin Parks (Alternate: Whitney Pettus) MAR 7 206 BP Alaska-Well Integrity Coordinator SCANNEDti GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com 1 STATE OF ALASKA *LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Convert to Producer N7 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-135 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23099-00-00 7. Property Designation(Lease Number): ADL 028257 8. Well Name and Number: PBU S-112 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL 11.Present Well Condition Summary: Total Depth: measured 8642 feet Plugs measured None feet RECEIVED true vertical 6743 feet Junkmeasured None feet FEB7 Effective Depth: measured 8642 feet Packer measured 6654 feet B 12016 true vertical 6743 feet Packer true vertical 6549 feet AC biCfC, Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 117 20"X 34" 36-153 36-153 Surface 2880 9-5/8" 35-2915 35-2878 5750 3090 Intermediate 6793 7" 32-6825 32-6667 7240 5410 Production Liner 1825 4-1/2" 6710-8535 6589-6753 8430 7500 Perforation Depth: Measured depth: 6900-8642 feet True vertical depth: 6711 -6743 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-6718 30-6595 Packers and SSSV(type,measured and 5"Baker PRM Prod Packer 6654 6549 true vertical depth) _-. - 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 500011 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 400 2450 Subsequent to operation: 0 284 1654 1260 2450 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development O Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-043 Contact Bronga,Jaime Email Jaime.Bronga@bp.com Printed Name Joe43 ... Coe c .\ Drilling Technologist Signature ` Phone +1 907 564 4091 Date in /f i Form 10-404 Revised 5/2015 vii- 4t711,1(0, 7//` /G L RBDMS L(„ FEB 1 8 2016 Submit Original Only • • S-112 Well History }ATE ' ®l�" ?�!t LRS Test Unit 4 *** New Well POP ***IL Well S-112, OL Well S-200*** Unit move, RU, SB 1/26/2016 ***Continued on WSR 1/27/16*** LRS Unit 4 ***Continued from WSR 1/26/16*** New Well POP ***IL Well S-112, OL Well S- 1/27/2016 200***SB, RU, PT, Maintenance, POP/Flow well ***Continued on WSR 1/28/16*** LRS Unit 4 ***Continued from WSR 1/27/16*** Flow well to lower BHP ***IL Well S-112, OL 1/28/2016 Well S-200*** Flow well, Startl2hr Test***Continued on WSR 1/29/16*** LRS Unit 4 ***Continued from WSR 1/28/16*** Flowback to decrease BHP***IL Well S-112, 1/29/2016 OL Well S-200*** Endl2hr Test, Flow Well ***Continued on WSR 1/30/16*** LRS Unit 4***Continued from WSR 1/29/16*** Flowback to decrease BHP ***IL Well S-112, 1/30/2016 OL Well S-200*** End 6hr Test, Flow Well ***Continued on WSR 1/31/16*** LRS Unit 4 ***Continued from WSR 1/30/16*** Flowback well to decrease BHP ***IL Well S- 1/31/2016 112, OL Well S-200***6hr Test, Flow Well ***Continued on WSR 2/1/16*** LRS Unit 4***Continued from WSR 1/31/16*** Flowback well to decrease BHP ***IL Well S- 2/1/2016 112, OL Well S-200***6hr Test, Flow Well ***Continued on WSR 2/2/16*** LRS Unit 4***Continued from WSR 2/1/16*** Flowback well to decrease BHP ***IL Well S- 2/2/2016 112, OL Well S-200***6hr Test, Flow Well ***Continue on WSR 2/3/16*** LRS Unit 4***Continued from WSR 2/2/16*** Flowback well to decrease BHP ***IL Well S- 2/3/2016 112, OL Well S-200***6hr Test, Flow Well ***Continued on WSR 2/3/16*** LRS Unit 4***Continued from WSR 2/3/16*** Flowback well to decrease BHP ***IL Well S- 2/4/2016 112, OL Well S-200***6hr Test, Flow Well ***Continued on WSR 2/5/16*** T/I/0=1993/1850/0 Assist testers with freeze protect. Pumped 4 bbls methanol down S- 200 flowline, pressured up to 500 psi per DSO. Pumped 38 bbls methanol down S-112 TBG. Testers in control of well at LRS departure. IA/OA=OTG. GLV=open, 2/4/2016 FWHP=1693/1800/0. Tags hung LRS Unit 4***Continued from WSR 2/3/16*** New Well POP ***IL Well S-112, OL Well S- 2/4/2016 200***6hr Test, Flow Well ***Continued on WSR 2/5/16*** LRS Unit 4***Continued from WSR 2/3/16*** New Well POP ***IL Well S-112, OL Well S- 2/4/2016 200***6hr Test, Flow Well ***Continued on WSR 2/5/16*** LRS Unit 4***Continued from WSR 2/3/16*** New Well POP ***IL Well S-112, OL Well S- 2/4/2016 200***6hr Test, Flow Well ***Continued on WSR 2/5/16*** LRS Unit 4 ***Continued from WSR 2/4/16*** Flowback well to decrease BHP ***IL Well S- 2/5/2016 112, OL Well S-200***RDMO, Weather S/B***Complete on WSR 2/5/16*** TREE= MC 4-1/16"5M • WELLHEAD= FMC GRI 5 Q-1 12 Sir y S NOTES: WELL 125 m WHEN N 7026'"'WELL ACTUATOR= BAKER ppMI DIB.aEV= 69.60' 1 REQUIRES A SSSV WHEN ON MI"' BF.ELEV= . ..._. KOP= 5626' Max Angle= 96°@ 745T Datum MD= 7031' Datum TVD= 6700'SSII225T -{4-112"HES X NP,D=3.813" 20"X 34",215.5 6/ft.A53 ERW INSULA It31 (- 114' 9-5/8"CSG,40#,L-80,BTC,ID=8.750" H 2915' J k GAS UFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT DATE 3 3850 3813 1 KGB2 DOME BK 16 01/14/16 2 5654 5616 1 KGB2 SO BK 20 01/14/16 Minimum ID =3.725" @ 6706' 1 6529 6451 35 KGB2 'DMY BK 0 06/25/07 4-1/2" HES XN NIPPLE 'DCT8'DEDPACKING 6596 -14-1/2"BKR SLD SLV,D=3.813" Z �� 6658' _ 17"X 5"BKR PRM PKR,D=3.875' 6685' H4-1/2"HES X NP,D=3.813" 6685' -4-1/2'X-LOCK w/FLOW THRU SUB &DUAL MEM GAUGE(01/16/16) ll 6706' -14-1/2"HES XN NP,ID=3.725" 4-1/2"TBG, 12.75#,L-80 TCI .0152 bpf,D=3.958" -{ 6718' �+ ►� 6710' -i 7"X 5"BKR ZXP LIP,ID=4.390" 0� 671$' -4-1t2"WLEG,D=3.958" 6729 --I 7"X 5"BKR HMC LNR HGR,ID=5.03" 6735 -5"X 4-1/2 XO BUSHING,ID=3.89" 7"CSG,26#,L-80,D=6.276" -1 6825' }-Lai , 6863 -14-1/2"MARKER JOINT W/RA TAG I I isi -Cil 7523 -+4-1'2"HMCV CEIvENTER R3RFOFtf�T1ON 7542' -�4-1/2"CEMENTED PAYZONE ECP,D=3.937" REF LOG: ????ON XX/XX/XX • ANGLE AT TOP FERE: 57°@ 6900' ' Note: Refer to Aoduction DB for historical pert data ' S(ZE SFF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 6900-6925 0 04/29/03 ' 3-3/8" 6 6960-6976 0 04/29/03 ; 4-1/2" SLID 7650-8535 SLOT 07/29/02 • • • • • • • 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,D=3.958" -1 8535' DATE REV BY COMMENTS DATE REV BY COMB' TS AURORA MT 08/07/02 D-14 IMTIAL COMPLETION 09/29/15 NLW/JMD PULLED PXN PLUG(09/26/15) WELL: S-112 04/29/03 JF/TP ADFERFS 12/16/15 EZ/JMD CHANGE)4-1/2"TBG WEGHT PMIXT No:' 021350 06/25/07 SPF/PJC GLV C/O 02/04/16 JPK/TLH GLV(70(01/14/16) AR No 50-029-23099-00 01/08/14 PJC TBG/LNR/PERE CORRECTIONS 02/04/16 DJS/TLH SET Ivtl3M GAUGE(01116/16) SEC 35,T12N,R12E,949'FNL 8 780'FWL 04/20/15 LECIJMD MN ID CORRECTION 07/01/15 TBD/JM) RLL ISO SLV/SET PXN PLUG BP Exploration(Alaska) I • • v ®F T�� Alaska Oil and Gas w\.....,est THE STATE i 0r, n of jJ AsKA Conservation Commission ice__ ---=-:_: tisi} __ _x__-=s1-..-,01 333 West Seventh Avenue --- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1. rh. Main: 907.279.1433 0F ALAS''Q' Fax: 907.276.7542 www.aogcc.alaska.gov WOO JAN 2 9 2016 Jamie Bronga Well Interventions Engineer ON Dal_ i BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-112 Permit to Drill Number: 202-135 Sundry Number: 316-043 Dear Mr. Bronga: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 5 CathyaVe14/oerster Chair DATED this 2(0 day of January, 2016. RBDMS LL JAN L 6 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Convert to Producer Il • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-135 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service RI• 6. API Number: 50-029-23099-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No lI PBU S-112RECE1 ED 9. Property Designation(Lease Number): 10. Field/Pools: JAN 21, Z0It ADL 028257 ' PRUDHOE BAY,AURORA OIL ' ors 24 'b 11. PRESENT WELL CONDITION SUMMARY AQ CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): V 8642 ' 6743 • 8642 - 6743 - 3607 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 117 20"X 34" 36-153 36-153 Surface 2880 9-5/8" 35-2915 35-2878 5750 3090 Intermediate 6793 7" 32-6825 32-6667 7240 5410 Production Liner 1825 4-1/2" 6710-8535 6590-6753 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6900-8642 6711-6743 4-1/2"12.6# L-80 30-6718 Packers and SSSV Type: 5"Baker PRM Prod Packer Packers and SSSV MD(ft)and TVD(ft): 6654/6549 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary I1 Wellbore Schematic m 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development IvT - Service 0 14.Estimated Date for Commencing Operations: February 1,2016 15. Well Status after proposed work: Oil 10 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: 1/21/2016 GAS 0 WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: Victoria Loepp GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bronga,Jaime be deviated from without prior written approval. Email Jaime.Bronga@bp.com Printed Name Bronga,Jaime Title Well Interventions Engineer / Signature Phone +19075644151 Date 6/f 'rir°l(9 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test'M Location Clearance 0 Other: w4 t-ve` Cr i--avt tr d fo at/04-- ft A X9-43 el C C ,M 1 T ► k f' b "C- c co vv, plc fe�./d Gifu✓ pre-- product,may, 45- Lt-4 d - Post Initial Injection MIT Req'd? Yes rl No ❑ Spacing Exception Required? Yes 0 No I ' Subsequent Form Required: /U--4 O 4 / APPROVED BYTHE Approved by: t�/•� COMMISSIONER COMMISSION Date:/.26...// )fT I /?5-06, ORIGINAL RBD MS JAN 2 6 2016 Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. y /• 2.2 /(v • • by S-112 Injector Conversion Request BP Exploration (Alaska) Inc. requests approval for flowing back injector S-112 for a period of time greater than 30 days. This request will require the reclassification of S-112 from an injector to a producer. BP also requests a waiver to wait until drilling is complete and pre-production has ceased to complete an updated AOGCC MIT-IA per the AA. Intervention Engineer Jaime Bronga 907-564-4151 Production Engineer Alex Youngmun 907-564-4864 Background Injector S-112 (PTD 2021350) operates under Administrative Approval Area Injection Order (AIO) 22D.001 for tubing by inner annulus communication (TxIA comm) while on miscible injection (MI). S-112 is due for a AOGCC MIT-IA on April 25, 2016. This well is slated for a coil tubing drilling sidetrack adding a lateral spudding on April 3, 2016. The current bottom hole pressure, 3607psi, is above the maximum pore pressure of 9.8 ppg (3415 psi at datum) for Nordic to sidetrack the well. The well is an Aurora injector located in a tight section of the Kuparuk C-Sands, resulting in low injectivity and slow communication with offset producers. The well has been offline since March 2015 and pressure decline was observed via static bottomhole pressure surveys and fluid level shots from April to December 2015. In December 2015, an increase in fluid level and tubing pressure was observed, indicating an increase in reservoir pressure. This was an unexpected result, but could possibly be explained due to the lack of production from offset producer S-26 in 4Q 2015 and baffled or delayed communication with new producer S- 42A to the north. As a first measure of reducing pressure at S-112, both offset producers (S-26 & S-109) were classified as "must-produce" and both nearby injectors (S-110B and S-123) have been shut in. Even with this measure in place to increase reservoir voidage, current models predict the reservoir pressure will still be too high to drill the well with Coiled Tubing Drilling in April, as currently scheduled. With this in mind, an injector flowback has been selected as the best method to decrease reservoir pressure in S-112 prior to the scheduled sidetrack date: April 3, 2016. On January 14, 2016, Slickline removed the dummy gas lift valves and set a live gas lift valve design modifying the well's mechanical integrity. The Well Integrity Coordinator notified the State via email of the modification as per the AA. The sidetrack is scheduled to finish on April 19, 2016. After the sidetrack the well will be pre-produced post rig for 1 to 2 weeks to clean-up the well prior to putting on water injection. After flowback, the injector will be marked as Not Operable until the well is ready to be placed on injection for an updated AOGCC MIT-IA. This will ensure no injection occurs in the well past the anniversary date of the AA until the well is ready for updated compliance testing. The well will be on water injection for 1 to 2 years prior to remedying TxIA communication and putting the well on MI injection. Obiective 1. Pre-produce the well to reduce BHP to within acceptable range for drilling operations, 2. Pre-produce the well post sidetrack to clean up and put on water injection, 3. Obtain a waiver to complete AOGCC MIT-IA once well is put on water injection post sidetrack pre-production. • ' Plan Foward Testers 1. Produce S-112 in attempt to reduce BHP from 3607psi to 3415psi. a. Flowback 10,000 bbl of fluid in 2 to 4 weeks. b. Complete by end of February 2016. Pre Rig Work 2. Complete Pre-Rig work including setting Whipstock, milling XN Nipple, and setting TWC. Coil Tubing Drilling 3. Drill S-112L1 from April 3 to April 19, 2016. Testers 4. Pre-Produce S-112/L1 for 1 to 2 weeks to clean up well prior to putting on water injection. Slickline 5. Dummy gas lift valves with extended packing Fullbore 6. Perform MIT-IA to verify mechanical integrity post valve changeout. Downhole Diagnostics 7. Perform online AOGCC MIT-IA Operations 8. Inject Produced Water for 1 to 2 years. Eline 9. Set Patch to mitigate TxIA communication Operations 10. Put well on MI injection Well Integrity Engineer 11. Evaluate cancellation of AA 2 • TREE= FMC 4-1/16"5M • A = FM3GEN 5 S-112 SAFETY pL ACTUATOR= BAK62C GS AVERAGE 125 pm WHEN Ml"'WEL OKB.ELEV 960' REQUIRES A SSSV WHEN ON MI"' BV= saw' BF.BEV KOP= 5626' Max Angle= 96° • 7457' Datum MD= 7031' Datum TVD- 6700'SS 2257 —4-112"FES X NP,D=3.813" 20"X 34",215.5 13/ft.A53 BRW INSULATED — 114' 9-518"CSG,40#,L-80,BTG,D=8.750" —1 2915' GAS LFT MANDRELS ST PA) TVD DEV TY FE VLV LATCH PORT DATE 3 3850 3813 1 KGB2 'DRAY BK 0 06/25/07 2 5654 5616 1 KGB2 'DRAY BK 0 06/25/07 Minimum ID =3.725" @ 6706' 1 6529 6451 35 KGB2 'DMY BK 0 06/25/07 CMG 4-1/2" HES XN NIPPLE •EXTENDED PA 1 I 6596 H4-1/2"BKR SLD SLV,D=3.813' 6658' HT X 5"BKR PRM PKR,D=3.875" ■ 6685' —14-1/2"I C3 X NP,D=3.813" ■' 6706' —4-1/2'HES XN NP,ID=3.725' 4-1/2"TBG,12.75#,L-80 TCI,.0152 bpf,ID=3.958' — 6718' vl ►. 6710' —7'X 5'BKR ZXP LTP,D=4.390' 6718' H4-1/2" EG, =3.958' \ 6729 —17"X 5'MEG, D FMC LNR HGR ID 5.03" \`�I 6735 —5'X 4-1/2 XO BUSHr G,ID=3.89" r CSG,26#,L-80,ID=6.276" H 6825' 6863 -{4-1/2"MARKER JOINT W/RA TAG 1 1 7523 —4-1/2"I- CV CBME TD FEF ORATION SUM4WIZY 1.:417542' H4-112"CE3dETVTED PAY ZONE ECP,D=3.937" REF LOG: ??7?ON XX/XX/XX ANGLE AT TOP FERE: 57'/ 6900' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SI-10T SQZ 3-3/8" 6 6900-6925 0 04/29/03 r , 3-3/8' 6 6960-6976 0 04/29/03 4-1/2" SLID 7650-8535 SLOT 07/29/02 r , • f 4-1/2"LNR 12.6#,L-80 BTC-M,.0152 bpf,ID=3.958' H 8535' 1--4--111. DATE REV BY COPJ€NTS DATE REV BY COMMENTS AURORA L 1T 08/07/02 D-14 INTIAL COMPLETION .01/06/14 JMG/PJC SET BLANC/4G SLV(10/31/13) WELL S-112 04/29/03 JF/TP ADEU1FS 01/08/14 PJC TBG/LNR/PERF CORRECTIONS PERAK No. 2021350 06/15/03 JM'KAK GLV GO 04/20/15-LEf2JMD MN ID CORRECTION AR No: 50-029-23099-00 06/25/07 SPE/PJC GLV CdO ` 07/01/15 TBD'JMD PULL ISO SLV/SET PXN PLUG SEC 35,T12N,R12E 949'FTI_8 780'FWL 02/15/11 NB/JMD ADDED SSSV SAFETY NOTE 09/29/15 NLW/JMD PULLED PXN PLUG(09/26/15) 01/19/12 TMTYJMD ADDEDH2S SAFE I Y NOTE 12/16/15 EZJJMD CHANGED 4-1/2"TBG WEIGHT BP Exploration(Alaska) 3 • II TREE= INC 4-1/16-511 .. WELUEAD= HOZ GEN s S-11211 SAFEIN JIES WELL ANGLE>7I1 ACTUATOR= BAKER CHER BRIGS AVERAGE 125 ppm WIEN ON MN•••WELL OKBEV= 69 ) v.,y1D's al '. .... 'ID OR 'CI REQusidEs A sissv wit Egg 0 N in...... _EL60' HE REV= L KOP= 5626' Nos Asgb= 99 it 7457" 22!il" 2- E5 : - DsllK)= 703r Ds1m1VD= 6707 SS I [ —4-1114XIW:13=3813 ar x 34'.215.5 ibTI_A53 HIW INSULA1ED — 114' 9-5/E"CSG.40/i.L-118,13111C.13=tirir — 2915- —4 ST 10 TUB DEVGASTYPELFT MAIM._pVilaslA11111 PORT DATE 3 3850 3813 1 KGB2 TINY EK 0 06/25107 2 5654 5616 1 PEW TINY EK 0 06125107 Iii= 0=3125-@ 6706' 1 6529 6451 35 1082 TRY EK 0 0625107 •EXTHLED RACKEIG 4-112-FES XN NE1PLE mos —4-112"DKR SID SLV.13=3.813- rinli Note One Atay leak to LA*ben an MI njection Z 0110.4 665W _—r x5ERR MU NOR.I)=WITT I 11505. 1—4-1/2-HES Xie:t 0=3.513' fizow IH 4-117 HES MI Pa,.11=3.725' 0 670W —14-yr PIM 14.1uG(ammo) 4-112"MG.-1211*.L-01 MI 0152 b131-10=3958. — 15718" .-1-14 ip.14 671(F -I 7"X5'DKR.7.XP L1P.13=4.3913' 0 671r H 4-irr INIEG.D=3_958' _ 6729 H r x5"EKR I-ii 1w 1-i .17=503' 6735 H5-7c4-1,127c0 Busi-wiG.13=3_1Er 2"me,.20/t.L-813.13=6276" — 6825- A 6063 —14112.IaltRICER JONI'wr RA TAG ril i 11 35/100 BUR 3-14'Laster to 8 8 TO / I I RA T.s., , t 61 KfC ,rf Wader* 4-92 Thru-smstog ResnevatolewAts)stocic @ 6 912'MD t. TD:A 9 216 MD r'4'420 RetAase Joni PERFORATOR SUMMARY Pt:Parer in*,spaces so:1- -9,180'MD-RSTO-NS cement- cut p.m,69 otAssistoA t trig valve sub laT LO ????011)000(1)Cf ANCIE ATIDP PERE 57"fa 6927 Nob: Relerlo ProcIscfms CS 1ca-lisloskal pal dais SITE SPF IITERVAL OreiSqz SHOT SO2. ( l' - M47 —I 4-1/2-I:MIMED PAYZOPm Ea:ID=3.937' „ 7523 —4-1i2"HTLV amEN1ER 3-381' 6 6900-6925 0 04129103 3-318' 6 6500-6976 0 04/29/03 4-112 SLID 7650-8535 SLOT 0712311:12 . . 1 1 4-112"LW.126ft.L-80 mr.-m..11152 bpi.D=3_958' H 9535' Ai i DATE REV BY COMMENTS DATE REV BY Cl)1110ITS AURORA UNIT 88/87182 0-14 USUAL CUEIRETKIN 0u10&I4 Amu P.IC SET ITIAIWINGSLV(10/31113) WEU: S-112 04129103 KIM ADFERFS 01/08/14 PJC113GI LW PERF CORRECTIMIS PERINI Ikc 2021350 00T15.103 JOIIKAK GLV CA) otaans U3C1110 KIN ID CORRECTION API No:50-029-23099-00 05125/07 SPHPJC GLV CR) 07101115 T110/310 PUL ISO SLV/ T PM RUG SEC 35,T1211,R12E,949 F1K A 700PM. 02115111 IMI.110 AIDED SSSV SAFETY NOTE 01119112 TIMM NEED MS SAFETY NOTE BP Exploration(Ask ) 4 S Wallace, Chris D (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, January 19, 2016 1:26 PM To: AK, D&C Well Integrity Coordinator Cc: Wallace, Chris D (DOA); Lastufka,Joseph N (Joseph.Lastufka@bp.com); john.gorrell@bp.com Subject: RE:Injector S-112 (PTD 2021350) Sundry to convert from injector to producer Since this well has an AA and a waiver is requested, please submit a 10-403 for review and approval of your plan outlined below. Thanx in advance, Victoria SCANNED MAY 2 7 2016 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Tuesday, January 19, 2016 11:51 AM To: Loepp, Victoria T(DOA); Lastufka, Joseph N; Gorrell, John Cc: Wallace, Chris D (DOA); AK, D&C Well Integrity Coordinator Subject: RE: Injector S-112 (PTD 2021350) Sundry to convert from injector to producer My apologies Victoria. See my correction to the plan forward in red below. The well will be placed on water injection for 1 to 2 years prior to MI injection and not be produced. The pre-produced periods will be 2 to 4 weeks prior to rig arrival and then another 1 to 2 weeks post rig departure. Updated Plan Forward: Operations: Flowback(pre-produce)well for 2 to 4 weeks prior to CTD arrival flowback to begin in the next two weeks so pre-produce can be completed by end of February Drilling: Coil sidetrack Operations/Well Testing: Pre-produce post rig for 1 to 2 weeks to clean up well prior to injection Slickline: Dummy gas lift valves with extended packing Fullbore: Perform MIT-IA to verify mechanical integrity post valve change out Downhole Diagnostics: Perform online AOGCC MIT-IA Operations: Pell Inject Produced Water for 1 to 2 years prior to MI injection E-line: Set patch to mitigate TxIA comm Operations: Place well on MI Well Integrity Engineer: Evaluate cancellation of AA Given the updated plan listed above,BP requests permission to have a variance to leave the well type listed as injector and pre-produce the week for up to 60 days without a 10-403 sundry conversion. The current plan is that the well will be flowed no more than 6 weeks (45 days). Once drilling is complete and pre-production has ceased,the injector will be marked as Not Operable until the well is ready to be placed on injection for an updated AOGCC MIT-IA. This will ensure no injection occurs in the well past the anniversary date of the AA until the well is ready for updated compliance testing. Please advise if this plan is sufficient or if any additional paperwork will be required for submission. Thank you and apologies for any confusion, Whitney Pettus 1 • • • (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator a WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, January 19, 2016 9:03 AM To: AK, D&C Well Integrity Coordinator; Lastufka, Joseph N; Gorrell, John Cc: Wallace, Chris D (DOA) Subject: Injector S-112 (PTD 2021350) Sundry to convert from injector to producer Please submit a 10-403 to convert this well from an injector to a producer. Outline the plans for the well and request a waiver to the April 25, 2016 MIT-IA when the well will still be a producer. The AA will remain in effect until the well is back on injection and the TxIA communication to MI is fixed. Please explain why the well will be produced for 1 to 1.5 years. Thanx, Victoria From: Wallace, Chris D (DOA) Sent: Friday, January 15, 2016 11:08 AM To: Loepp, Victoria T(DOA) Subject: Fwd: Injector S-112 (PTD 2021350) Operations and Drilling Plan Forward Original message From: "AK, D&C Well Integrity Coordinator" <AKDCWellIntegrityCoordinator@,bp.com> Date: 01/15/2016 10:55 AM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Cc: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "AK, D&C Well Integrity Coordinator" <AKDCWellIntegrityCoordinator@bp.com> Subject: Injector S-112 (PTD 2021350) Operations and Drilling Plan Forward Chris, As per our conversation, Injector S-112 (PTD 2021350) operates under Administrative Approval Area Injection Order(AIO) 22D.001 for tubing by inner annulus communication(TxIA comm) while on miscible injection (MI). In preparation for upcoming pre-production and coil drilling operations (CTD), live gas lift valves were set in this well on January 14, 2016. The well will be pro-produced in order to reduce the bottom hole pressure within an acceptable range for upcoming drilling operations. ETA for pre-production is within the next two weeks with the sidetrack scheduled to begin early April 2016. The plan forward for this well is as follows: 2 . , . 0 • Plan Forward: 1. Operations: Flowback(pre-produce)well for 2 to 4 weeks prior to CTD arrival flowback to begin in the next two weeks so pre-produce can be completed by end of February 2. Drilling: Coil sidetrack 3. Operations/Well Testing: Pre-produce post rig for 1 to 2 weeks to clean up well prior to injection 4. Slickline: Dummy gas lift valves with extended packing 5. Fullbore: Perform MIT-IA to verify mechanical integrity post valve change out 6. Downhole Diagnostics: Perform online AOGCC MIT-IA 7. Operations: Produce well for 1 to 2 years prior to MI injection 8. E-line: Set patch to mitigate TxIA comm 9. Operations: Place well on MI 10. Well Integrity Engineer: Evaluate cancellation of AA As the well will not immediately be repaired for an estimated 1 to 1.5 years after sidetrack, BP would like permission to retain the current AA and apply for a sundry(or variance) for more than 30 days of pre- production. The well will not be placed on injection until after the sidetrack is completed. BP will contact the state for an updated AOGCC MIT-IA after the well has been tied back in post drilling operations. Please note that the sidetrack is scheduled for completion April 16, 2016 and the anniversary date for the AA is April 25th, 2016. The state witnessed AOGCC MIT-IA will be requested once well tie in(WTI)has been completed which is will most likely occur after the anniversary due date for this well. However, injection on the well will not occur until the well is placed on injection to stabilize for the state witnessed test. Cancelation of the AA will be pursued 1 to 1.5 years after the well has been placed on water injection and after a patch is set to mitigate the TxIA comm previously noted while on MI. Please advise if a different course of action should be taken or recommend an alternative plan forward if this does not meet expectations. A copy of the AA has been attached for reference. Thank you, 3 ( Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. I¿Q ro - 13$ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 111111111111111111 RESCAN DI~AL DATA ~Diskettes, No.-3 o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: BY: Helen® o Other:: Date: /b /1 J D 'f 151 I11P I 1111111111111111111 Date:10l10Lf Isf ~ NOTES: BY: Helen ~ Project Proofing Scanning Preparation BY: 3 x 30 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 43- (Count does include cover sheet) Page Count Matches Number in slanning Preparation: ~ YES NO He'en8 Datel () II / (J t 151 tvtP If NO in stage 1, page(s) discrepancies were found: YES NO Stage 1 BY: BY: Helen Maria Date: /s/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: Isl Comments about this file: Quality Checked II1I111111111111111 8/24/2004 Well History File Cover Page.doc P Na zz (3 ,0 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, April 11, 2012 1:41 PM � G, Jii (v To: 'AK, D &C Well Integrity Coordinator' l Cc: DOA AOGCC Prudhoe Bay Subject: RE: Injector S -112 (PTD #2021350) Due for MIT -IA in 2 weeks and offline currently (AA A1022D.001) due to supply pump issues Since well is on monthly monitoring rpt of TIO Pressures per A10 let's wait until well in placed back on injection „ to do State witnessed MIT. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 SLANNED APR 1 2012 Anchorage, AK 99501 907- 7934236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWellIntegrityCoordinator Cabp.com] Sent: Tuesday, April 10, 2012 7:01 AM To: Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Injector S -112 (PTD #2021350) Due for MIT -IA in 2 weeks and offline currently (AA AIO22D.001) due to supply pump issues Jim, Injector S -112 (PTD #2021350) which is operating under AA A1022D.001 is coming due for it's 2 year MIT -IA on 04/25/2012. The well was shut in on 1/31/2012 due to an injection booster pump leak that is currently waiting on parts to be repaired. Operations has no clear line of site date as to when that repair will be completed. Would you prefer to wait to test the well while it is on injection, or should we perform an MIT with the well not on injection , to maintain our anniversary date? I am enclosing a TIO and injection plot, and a copy of the AA for reference. «S -112 (PTD #2021350) TIO and Injection Plot.doc» «S -112 AA Approval 05- 20- 08.pdf» Thank you for your time, Jerry Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 1 PBU S-112 PTD #2021350 4/10/2012 TIO Pressures Plot Wet S-112 4 con 3,000 flowi ime"L"'"V Tbg Ai- IA Z000 - no On 1,000 - # 10/ 11/11/11 12/12/11 01/12/12 02/12/12 03/14/12 Injection Plot Welt 5-112 2.600 2,000 fl • 2,400 - - 1,800 2,200 - - 1,600 2,000 - 1,800 - 1,400 1,600 - - 1200 - - WHIP - SW 1 A00 - -P 1 II - 1,000 - MI L200- GI ° Other 1 800 ,000 _ On 800 - - 6130 600 - - 400 400- 200 - - 200 10/11/11 11/11/11 2/12/11 01/12/12 02/12/12 03/14/12 MEMORANDUM To: Jim Regg '~~T ~ 5~ 1 ~ ~~G P.I. Supervisor EROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Apri128, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-112 PRUDHOE BAY UN AURO 5-112 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN AURO 5-112 API Well Number: 50-029-23099-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100423170322 Permit Number: 202-135-0 Inspection Date: 4/23/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-tti~ ype Inj. W `~TVD 6552 ~ IA 1320 3600 3540 3520 ~ P.T.D 2021350 • ~---- TypeTCSt SPT Test psi 3600 / QA 485 740 730 720 Interval REQvAR p/F P ~ Tubing 2720 272o z7zo 2720 Notes: ~~ u ZZ ~ : ~'~ 1 - 2c~~ n.1.~->-~ -Fz2 Ma-f~ Gi-~ti-~;'~c,~~? ~n~ P .~s~~U~ .t% r ` f i Wednesday, Apri128, 2010 Page 1 of 1 • • June 25, 2009 ~-y c, f ~~~-s~~~3~~f~~~~~ Mr. Tom Maunder ~~L ~ ~„ 2009 Alaska Oil and Gas Conservation Commission ~r~~~~-~ p~! ~~~,~ ~~n~e ~~~r~~~~iA~ 333 West 7~~ Avenue ~r~~~~~g~~~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad ~~~~ t~~ ~ "`..~ ! . Dear Mr. Maunder, 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, ~''I'~qy~~qry-y~~~'~~~f~L~~ ;U~ {: `' 20C~~ ~`~~ii~ Yr iy Y~Y.~ 4 Torin Roschinger BPXA, Well Integrity Coordinator ~ • BP Expioration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report ot Sundry Operations (10-404) &pad r Aafn fJ95/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top ofi date Cortosion inhi6ltor COff0510l1 inhibitod sealant date ft bbls ft na al 5-018 1952020 0.25 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25l2009 S-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 1957890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA O.s 5/26/2009 5-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-08B 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31I2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-11B 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 S-~3 1821350 8 NA 8 NA 55.3 6/7l2009 S•15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/7/2009 S-78A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-/9 1861160 0.75 NA 0.75 NA 2.2 5/79/2009 S-20A 2010450 025 NA 025 NA 1.3 5/19l2009 S-2t 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 0.25 NA 025 NA 1.7 5/25/2009 5-248 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.~5 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31l2009 S-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.7 5/37/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 1920990 125 NA 1.25 NA t7.9 5/27/2009 5-38 1921270 0.25 NA 025 NA 102 5/27/2009 S-47 1960240 1.5 NA 1.5 NA 17.1 5/30/2009 S42 1960540 0 NA 0 NA 0.9 5/30/2009 S-a3 7970530 0.5 NA 0.5 NA iJ 5/28/2009 S-44 1970070 025 NA 025 NA ~.7 5/28/2009 S•700 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001750 725 NA 125 NA 11.9 5/29/2009 5-102L7 2031560 725 NA 125 NA 77.7 5/31/2009 S-103 2001680 1.5 NA t.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 75.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2070120 1625 NA 1625 NA tI4.3 6/2/2009 S-t07 2071130 2.25 NA 2.25 NA 28.9 5/18/2009 S-708 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-70s 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-i i t 2050510 2 NA 2 NA 19.6 5/30/2009 S-1t2 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/78/2009 S-71aA 2021980 1.25 NA 125 NA 10z 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-176 2031810 1.5 NA 1.5 NA 13.6 5728/2009 S-tt7 2030120 1.5 NA 1.5 NA 75.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-t27 2060410 4.5 NA 4.5 NA 53.6 5/28/2~9 S-722 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 17.9 5/26/2009 S-i25 2070830 2.25 NA 225 NA 20.4 5/28/2009 S•126 20770970 125 NA 1.25 NA 15.3 6/1/2009 5-200 1972390 1.25 NA 125 NA 14.5 5/28/2009 5-207 2001840 0 NA 0 NA 0.85 6/79/2009 S-273A 2042130 2 NA 2 NA 73.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6l1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-a0t 2060780 16 NA 16 NA 99.5 6/2/2009 S-SOa 0 NA 0 NA 0.85 5/28/2009 OPERABLE - 5-112 (PTD #2021350) Passing AOGCC MITIA Page l~ Regg, James B (DOA • • From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ ~IzIO~ Sent: Friday, April 25, 2008 7:14 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Young, Jim; Fleckenstein, Robert J (DOA); Newman, Michael E Cc: NSU, ADW WI Tech; NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: OPERABLE - S-112 (PTD #2021350) Passing AOGCC MITIA Attachments: MIT PBU S-112 04-25-08 .xls ,.~ All, ,/~ r~~` tcr~s5~~~ ~ ~F~- Well 5-112 {PTD #2021350} passed an AOGC essed MITIA on 04{25108. An AA request far continued produced water injection will folloW.. Please see the attached MIT form for test details. «MIT PBU S-112 04-25-08 .xls» Please call With questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~ MAY ~ ~ 200 From: ,ADW Well Integrity Engineer Sent: Sunda , ebruary 24, 2008 11:11 AM To: 'Regg, James DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr W (GC2/WRD); NSU, ADW Well Operations Supervisor; R berg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Pr ontrollers; Young, Jim; 'Fleckenstein, Robert J (DOA)'; Newman, i ael E Cc: Townsend, S. Eliot; NSU, ADW ech; NSU, ADW Well Integrity Engineer Subject: OPERABLE - 5-112 (PTD #2021 0) Passing MITIA i ail, Weil 5-112 {PTD #2021350) has been reclassified a rabie with a passing MITIA on 02119108. The MITIA form is attached for reference. Given the well was shut-in to swap to water remained shut-i ue to activity on the pad, it was decided to first conduct the test with the well shut-in and schedule n AOGCC Witnessed tes nce the well is back on injection. The MITIA passed allowing the Wefl to be reclass~ ~ d as Operable. The increase in bing pressure during the test is thought to be due to ballooning affects against a ~ce plug in the tubing. Plans progress t Isar the ice plug, place the Well on injection, and conduct an AOGCC Witnes d MITIA for an AA request. Please let me know if y have any questions. Thank you, ,~nna e, ~'. E. Well Int itv Coordinator Group 5/2/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~ h~2 FIELD /UNIT /PAD: Prudhoe Bay /PBU / S-Pad I~ ~'~ ~ ' DATE: 04/25/08 OPERATOR REP: Andrea Hughes AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well S-112 T e In'. W TVD ''6,552' Tubin 2,470 2,470 2,470 2,480 Interval O P.T.D. 2021350 T e test P Test si x'3600 Casin 440 X620 3540 3520 P/F P Notes: MIT-IA for AA Request. OA 790 1160 1140 1130 Witness declined b C. Scheve. 4.4 bbLs of methanol to achieve test ressure. Well T pe In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. Ty e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In". TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes 1=Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU S-112 04-25-08 .xls OPERABLE - 5-112 (PTD #2020) Passing MITIA • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ' 1Q~~ ~~ 75 ~~~ Sent: Sunday, February 24, 2008 11:11 AM I 1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD}; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Young,. Jim; Fleckenstein, Robert J (DOA); Newman, Michael E Cc: Townsend, S. Eliot; NSU, ADW WI Tech; NSU, ADW Well Integrity Engineer Subject: OPERABLE - S-112 (PTD #2021350) Passing MITIA Attachments: MIT PBU S-112 02-19-08.x1s Hi ali, Well 5-112 (PTD #2021350} has been reclassified as Operable with a passing MITIA on 02119108. The MITIA form is attached for reference. «MIT PBU S-112 02-19-08.x1s» Given the well was shut-in to swap to Water and remained shut-in due to activity on the pad, it was decided to first conduct the test with the Well shut-in and schedule an AOGCC Witnessed test once the well is back on injection. The MITIA passed allowing the well to be reclassified as Operable. The increase in tubing pressure during the test is thought to be due to ballooning affects against an ice plug in the tubing. Plans progress to clear the ice plug, place the well on injection, and conduct an AOGCC witnessed MITIA for an AA request. Please let me know if you have any questions. Thank you, ,~11rt[l ~Z161Q, ~ E. Weil Integrity Coordinator GPB ells Group Phone: (9t37) 659-~ Pager: {907) 659-5100 x1154 >~~~~NE~ FEB ~ ~ 2008 From: NSU, ADW Well Integrity Engineer Sent: Friday, January 18, 2008 1:25 PM To: Regg, James B (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; Tom_Maunder@admin.state.ak.us; Ohms, Danielle H Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: UNDER EVALUATION - 5-112 (PTD #2021350) for TxIA Comm on MI Injection Hi all, Well S-112 (PTD #2021350) is exhibiting TxIA communication on MI injection. The well is now classified as Under Evaluation. Please swap the well to water injection. The plan forward includes: 1. Oper: Swap the well to water injection 2. FB: AOGCC MITIA 3. WIC: Apply for AA to limit well to water injection due to TxIA Comm on MI injection A wellbore schematic and TIO plot have been included for reference. 2/25/2008 OPERABLE - 5-112 (PTD #202 0) Passing MITIA • Page 2 of 2 The well has been added to the Moi Injection Report. 2/25/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~ ~~ ~s~~'SI d '~ FIELD /UNIT /PAD: Prudhoe Bay /PBU / S Pad DATE: 02/19/08 OPERATOR REP: Anna Dube AOGCC REP: Packer De t Pretest Initial 15 Min. 30 Min. Well S-112 Ty e Inj. N TVD 6 52' Tubing 1,750 2,150 2,050 1,950 Interval O P.T.D. 2021350 Type test P Test si 1638 Casing 420 3,600 3,520 2,480 P/F P Notes: MITIA Passed while well shut-in. OA 0 0 0 0 Plan to conduct MITIA again with well on injection for AA re uest to limit well to PWI due to slow TxIA when on MI. Well T e Inj. TVD Tubing Interval P.T.D. T petest Test si Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: OA Well Ty e Inj. TVD Tubing Interval P.T.D. Ty e test Test si Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU S-112 02-19-O8.xls UNDER EVALUATION - 5-11~TD #2021350) for TxIA Comm on MI njection Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj~!~~~ ~ I ~~ Sent: Friday, January 18, 2008 1:25 PM \~ To: Regg, James B (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; Maunder, Thomas E (DOA); Ohms, Danielle H Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: UNDER EVALUATION - S-112 (PTD #2021350) for TxIA Comm on MI Injection Attachments: S-112.pdf; S-112 TIO PIot.B/ Hi all, Well S-112 (PTD #2021350) is exhibiting TxIA communication on M1 injection. The well is now classified as Under ;i Evaluation. Please swap the well to water injection. The plan forward includes: 1. Oper: Swap the well to water injection / 2. FB: AOGCC MITIA 3. WIC: Apply for AA to limit well to water injection due to TxIA Comm on MI injection A wellbore schematic and TIO plot have been included for reference. «S-112.pdf» «S-112 TIO PIot.BMP» The well has been added to the Monthly Injection Report. I<~~~ .lAN 3 ~. 2008 1 /24/2008 ~,aaa 3,aaa ~,oaa ~ ,aaa Gus-<<z ..~.~~.mm___~,_.~....~ti~.__, 5-11 TIC Plat a ~ are ar~aa~ -i- Tbg IR -~ a~ oo~ ooc~ ~ ~ rzr~aa~ ~ ~,~ ~~aa~ ~ ~r~naa~ ~ 211 sraa~ 1 r~r~aa$ ~ ~t ar~aas ar~r~aaa TREE = FMC 4-1 f 16" 5n'# WELLHEAD = FMC GEN 5 ACTUATOR = ~~..~ ,. , ....w~ ,~,. KB. ELEV = 8E=. EIEV = ..,.~-,~.m....-.~ 69.60' ~. _~...-,~ ..,-n . P.~-+x Angle = __ _ ~~, ; ~ I~57` Datum MD --. ~ .703' Datum T4ID = 8700' SS 20" X 34'°, 215.5 Ibi##. A53 ERW INSULATED 9-5i8" CSG: 40#, L-80, BTC, IU = 8.750„ 1L '14 2915' ~11'11P'1'It7i71 ~ = 3.~~~rti ~{)~ 4-112" HES XN IPPLE SAFETY P1OTES: 4-1+'2° HES X NIP, ED = 3.813„ GAS LEFT MANDRELS 5T NPD TVD DE~J TYPE VLV LATCH PORT DATE 3 3850 3813 1 KBM "'DMY BK 0 06(25!07 2 5654 5617 1 KBM `DMY BK 0 06/25f07 1 6529 6451 35 KBM "DMY BK 0 b6f25f07 LY I tNl}ImLt F',4(;KINCa $~$ 4-1t2" BKR SLIDING SLV 6658` ~ 7°' X 5" SKR E'RM PKR, ID = 3.875" 4-1t2" TBG, 12.6#, L-80, .0152 bpf, id = 3.958" I--~ 6717° 7" CSG, 26#, L-80, (Q = 6.276" I--{ 6825' $$~~--~4-1!2" HES X NIP, ID = 3.813" , 6706' 4-1i2" HES XN NIP, ID = 3.725° 67'1 S" X 7° BKRLXPLNR TOP F'fCR, ID = 4.390" 671$ 4-1,•'2° WE.E-G, ID=3.958„ 6863 ~--{a-1t2"sHORT~oINTwi RATaG S-112 4-112" LNR, 12.6#. L-80< .0'152 bqf, !17 = 3.958" ( 7650' , PERFORATION SUt;fiIvtARY REF LOG: aNGLE a~r TOP I~-~~~; 57° ~ s9oo' Note: Refew try Productlc~f ~ DB in r r~istori; al perfi ctz#a SIZE SPF INTERVAL OprrtSgr DATE 3-3t8" 6 6900 - 6925 O 04r29i03 3-3t8" fi 6960 - 6926 O 04i29i03 SLID 7650 - 8:;35 O ~ t 4-1 i2" SLTD LNR. 12.f>?, L-80, .0152 kSg~P, ID = 3.958" $535-'- - - - -` 7542® ,--{4-1!2" GECvtEMED PAYZONE ECP, ID = 3.937" - _ _ -.. DATE REV BY COMivtENTS DATE REV BY 48/47/42 JDMfKA OWGINAL GONIPLETIt3N 06t25i07 SPFlPJC GLV C.%O 08115102 RLiTP GLV CIO .~ 11/18102 GG7KAK AQD BKR SLIDING SLV 04129103 JF; ~P ADP 06115t03 JNUKAK GLV AURORA UNIT WELL: 5-112 PERMIT No: 2021350 APE No: 50-029-23099-00 SEC 35, T12N, R12E, 4332` FSL & 4501' FEt_ sP Exploration (Alaska) . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ . KefI7(1~(07 DATE: Wednesday, July 11,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-112 PRUDHOE BAY UN AURO 5-112 Src: Inspector "L/ \?;b d-,{)CT FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,S&c- Comm Well Name: PRUDHOE BAY UN AURO S-112 Insp Num: mitCS070709163949 ReI Insp Num: API Well Number: 50-029-23099-00-00 Permit Number: 202-135-0 Inspector Name: Chuck Scheve Inspection Date: 7/8/2007 Packer Depth / Well! S-112 !Type Inj. I w i TVD:- 6552 ' 1 IA ~i 2021350 .ITypeTest : SPT j Test psi 1- _ 1638_-.J_OA Interval OTHER P/F P ,/ Tubing Notes: Test performed prior to swapping well to gas injection. ./ Pretest Initial 15 Min. 30 Min. 45 Min. 3900 1 3900 -T- i -L I 375 I I 60 Min. 700 I 4000 i -----L...__~ 50 I 375 ! I.. -- 375 -- 2325 2325 2325 I ----L 2325 ~-~ 5CANNED JUL 2 0 2007 Wednesday, July 11,2007 Page I of I . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: S-106_PB1, S-112, S-205, C-01A, 2T-218, P2-57A. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 S-106_PB1: ;;01-0/;) tt 1¿/3~ Digital Log Images: 50-029-22999-00, 70 1 CD Rom S-112: U::c:c.,.. QO;) -13S- ;.þ J'-/;çµ.,j Digital Log Images: 50-029-23099-00 S .9/~· /-4.10 e.,l ed w roV\~ - S 2G5! U.:J::.Q...f)Od- 1'2}~ tt /t.../39-;;) Digital Log Images: 50-029-23107-00 1 CD Rom 1 CD Rom C-01A: 963-Ò/O :{r 14~Ö Digital Log Images: 50-029-20121-01 SCANNED JAN 3 0 2007 1 CD Rom 2T-218: 963 -01-+ ¡:t. ILI3-::J-1 Digital Log Images: 50-029-20449-00 1 CD Rom P2-57 A: dO d- - d I~ 'it /L./3(f1 Digital Log Images: 50-029-22183-01 1 CD Rom S-ll2 (PTD #2021350) Slow IA Repressurization while on MI Winton and Jim, Well 8-112 (PTD #2021350) exhibits slow IA repressurization while on MI. Currently the well is on water injection. Our plan forward for this well is to obtain an M for continued water injection. Please call with any questions or concerns. Thank you, Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ,.c:.;.k'P' ~.~AW~. T \:..,'~1;1::¡ ;~.. ,~>."'~~.;- / r ~J lof! 10/26/2006 3 :03 PM e e WELL LOG TRANS MITT AL VIC ~OJ~135 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 1"3LdJl RE: MWD Formation Evaluation Logs S-112, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 S-112 : LAS Data & Digital Log Images: 50-029-23099-00 1 CD Rom ~ . . ·..·······r.···.······················ .t~~'-:. _ ',' "'_ 1;,- .t , .~, ,. .~.. .J' jrt~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker.doc S-112 (PTD #2021350) Slow IA repressurization e e ,,-;)? L k1r IVp{)I{)~ Suh,jcct: S-112 (PTD F.2(21350) Slow IA reprcssurization From: "NSlJ, ADW Wdllnlegrily Engineer" <NSUADWWelllnlcgrityEnginccr(à?13P.com> Datl~: Su.n, 02 Ocl2005 21 :57:14 -0800 To: "AOGCC Winton Auhc11 (E-mail)..<\\I·inton_aubert~~~admin.slale.ak.us>. "AOGCC Jim Rcgg (E-mail)..<jinlJegg(~i·.admin.statc.ak.us> CC: "NSlJ, AD\\' Well Integrity Engineer" <NSUAD\\'WclllntegrityEnginecr(¿¡/BP.com:>, "GPH, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPß, Oplimizalion Engr" <GPßOptimizationEngr~.l!.ßP.com>, "Young, Jim" <YoungJ3@ßP.com>, "Lenig, David C" <LcnigDC(~.i)BP.com>, "Winslow, Jack L." <Lyons\v~l.~BP.com> Hi Jim and Winton, S-112 (PTO #2021350) is exhibiting slow IA repressurization on MI. With your approval, the well be swapped to water prior to being shut-in. A MIT-IA will then be conducted and the well evaluated for communication. A wellbore schematic has been included for reference. The well will be added to the monthly injection report. «S-112.pdf» Please let us know if you have any questions. Thank you, ftnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 oj 8-1 Content-Description: S-112.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 12/30/200511:51 AM lREE= IlllELLHEA D = AClUATOR= KB. ELE\! = BF. ELE\! = KOP- Max Angle- Datum IIt1D - Datum 1V D - FI'o£ 4-1/16" 5M FMC GEN 5 69.60' 5-112 5626' 96 @ 7457' 7233' 6700' SS 120" X 34", 215.5Ib/ft. A53 ERW INSULA TED I 19-5/8" CSG, 40#, L-80, BTC, ID-8.750" I Minimum ID = 3.725" @ 6706' 4-112" HES XN NIPPLE IT' CSG. 26#, L-80, ID= 6.276" I 14-1/2" TOO, 12.6#, L-80, .0152 bpf, ID = 3.958" I 4-112" LNR, 12.6#, L-80, .0152 bpf, ID - 3.958" 7650' Note: SIZE 3-3/8" 3-3/8" PERFORATION SUMlAARY REF LOG: ANGLEATTOPÆRF: 58@6900' Refer to Production DB for historical perf data SPF NTERVAL Opn/Sqz ()l\ TE 6 6900 - 6925 0 04/29/03 6 6960 - 6926 0 04/29/03 SL TD 7650 - 8535 0 14-112" SLTDLNR, 12.6#, L-80, .0152bpf, ID= 3.958" H 8535' ~:- - - -_: DA TE REV BY 08107/02 JDM/KA 08/15/02 RLlTP 11/18/02 GC/KA K 04109/03 DRSlTP 04/29/03 JF/TP 06/15/03 JM/KA K COMMENTS ORIGINAL COMPLETION GLV CiO ADD BKRSLlDING SLV TVD/1It1D CORRECTIONS ADPERFS GLV CiO REV BY DATE 1 I I SAFETY NOTES: 2257' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DE\! TYPE VLV LATCH FDRT DATE 3 3850 3813 1 KBM3-M DMY BK 0 08/15/03 2 5654 5617 1 KBM3-M DMY BK 0 06115/03 1 6529 6451 35 KBM3-M DMY BK 0 06115/03 6586 4-112' BKR SLIDING SLV 6658' 6685' 4-112' HES X NIP, ID = 3.813" 6706' 4-1/2' HES XN NIP, ID = 3.725" 5" X 7" BKR ZXP LNR TOP A<R, ID = 4.390" 4-1/2"WLEG, ID= 3.958" ELMD TT NOT LOGGED I COfIfMENTS 6863 4-1/2" SHORT JOINTW/ RA TAG 7542' 4-1/2' CEMENTED F¥l.YZONE ECP, ID= 3.937" AURORA UNrr W8..L: S-112 ÆRMTNo: 2021350 API No: 50-029-23099-00 SEC 35, T12N, R12E, 4332' FSL & 4501' F8.. BP Exploration (Alaska) MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg .v., ,?ILdo~ P.I. Supervisor I,~t~\ . DATE: Wednesday, March 02, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-112 PRUDHOE BAY UN AURO S-112 ao~-[~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ;-roCJ) P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN AURO S-112 API Well Number: 50-029-23099-00-00 Insp Num: mitCS050224165948 Permit Number: 202-135-0 Rei Insp Num: Inspector Name: Chuck Scheve Inspection Date: 2/24/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-112 Type Inj. P TVD 6552 IA 260 4000 3940 3940 P.T. 2021350 TypeTest SPT Test psi 1638 OA 0 200 200 200 Interval OTHER PIF P Tubing 1750 1750 1750 1750 Notes: MIT performed pre WAG swap to gas. SC!\NNEe MAR J. ~\. '200:J Wednesday, March 02,2005 Page 1 of 1 I M. ~\.1j v¡ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 .3p!A c~ ),) tJ0 ~ ~IN) ~ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23099-00-00 -" ---"-",I~ currentStat~~-~ //" UIC Y . .J ~~--:-:~;:::==::::=-:::: Permit to Drill 2021350 Well Name/No. PRUDHOE BAY UN AURa S-112 MD 8642 ~ TVD 6743 / Completion Date 8/7 /2002 ~ Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, USIT, DEN, NEW, ASI, ASGR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ED D ~ ~ Rpt ~D Rpt ~ ED D Rpt ED D Rpt reD C Asc ED C Pdf Log Log Run Scale Media No 1 Name Directional Survey J,onic '-C..!emperature Directional Survey tJ;t517 LIS Verification 5 5 Col Col LIS Verification ~mma Ray 5 Col Directional Survey Directional Survey Directional Survey Directional Survey "':11999 LIS Verification 11999 Induction/Resistivity 1,2,3 25 Final 25 Final 25 Final 25 Final 25 Final 25 Final (ED C Pdf V99 I nduction/Resistivity L/ ED C Pdf 11999 Density ED C Pdf 11999 Density ED C Pdf 11999 Neutron JD C Pdf 11999 Neutron Directional Survey Yes ------~---~--,--~-~ -~-~------~_._--~-----~.- - (data taken from Logs Portion of Master Well Data Maint) Interval OHI Start Stop CH Received Comments ~-_._--------_._-~--- 0 688 Open 8/27/2002 <lY&L-- 2850 6689 Case 8/20/2002 2850 6689 Case 8/20/2002 0 8642 Open 8/27/2002 J:C r:-:: fL.. 515 8587 Case 2/18/2003 515 8587 Case 2/18/2003 2850 6689 Case 8/20/2002 0 8642 Open 8/27/2002 ]1 r- ß.., 0 8642 Open 8/27/2002 MWD 0 8642 Open 8/27/2002 MWD 0 688 Open 8/27/2002 GYRO 515 8641 Open 6/2/2003 114 8641 Open 6/2/2003 MWD-ROP, NGP, DGR, EWR-MD 114 6743 Open 6/2/2003 MWD-NGP, DGR, EWR- TVD 114 8641 Open 6/2/2003 MWD-DGR, SLD, CTN-MD 114 6743 Open 6/2/2003 MWD-DGR, SLD, CTN- TVD 114 8641 Open 6/2/2003 MWD-DGR, SLD, CTN-MD 114 6743 Open 6/2/2003 MWD-DGR, SLD, CTN- TVD ----~--"------,--~------~- ~-~~ Permit to Drill 2021350 MD 8642 TVD 6743 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? y(B) Chips Received? y Y / N Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. PRUDHOE BAY UN AURa S-112 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23099-00-00 Completion Date 8/7/2002 Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops ~ Current Status 1-01L UIC Y Sample Set Number Comments &N &)/N ~~--,----- ---------~~--- ------- - ~ Date: ') q (' - 7FJ-~"-J~~:=~=:'~:~.- t7L ~~~~~---~ .--\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOrRECEIVFn 1. Operations Performed: Abandon 0 Repair WellO PluÇJ PerforationsD Stimulate 0 ~E~2 S~oorro WAG Alter CasingD Pull TubingD Perforate New PoolD WaiverD Tiroe ~xtE}{1.~i9.n J AlaSka UfI &~S Cons. Commission Change Approved ProgramD Operation ShutdownD Perforate [K] Re-enter Suspended Well h or~ 5. Permit to Drill Numjer: Exploratory D 202-1350 6. API Number 50-029-23099-00-00 4. Current Well Class: Development ]] 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 69.60 8. Property Designation: ADL-0028257 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 5-112 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool Service D Total Depth measured 8642 feet true vertical 6742.7 feet Plugs (measured) None Effective Depth measured 8642 feet true vertical 6742.7 feet Junk (measured) None Casing Conductor Liner Production Surface Length 80 1825 6794 2881 Size 20" X 34" 215.5# A53 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 MD TVD 34 114 34.0 - 114.0 6710 - 8535 6589.7 - 6753.4 31 - 6825 31.0 - 6666.8 34 - 2915 34.0 - 2878.4 Burst Collapse 8430 7500 7240 5410 5750 3090 Perforation decth: Measured depth: 6900 - 6925, 6960 - 6976, 7649.6 - 8294.91, 8333.72 - 8533.3 True vertical depth: 6711.01 - 6724.29,6741.39 - 6748.51,6772.52 - 6759.56,6759.22 - 6753.55 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 29 6714 Packers & SSSV (type & measured depth): 4-1/2" Baker ECP Packer 4-1/2" Baker PRM Packer 4-1/2" Baker ZXP Packer @ 7542 @ 6654 @ 6710 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 13 Prior to well operation: Subsequent to operation: Oil-Bbl 503 0 0.5 0 13 -477 Tubing Pressure 278 Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron jj~~ WAG ŒI GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 303-124 Title Production Technical Assistant Signature Phone 564-4657 Date 9/22/04 ORIGINAL .~ "4 Form 10-404 Revised 4/2004 ( S-112 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/29/03 Perforate 69601-69761 6 SPF, 6900'-69251 6 SPF, 69001-6925' 6 SPF OS/26/03 First day of WAG Injection BBLS 110 36 146 60/40 Methanal Diesel TOTAL FLUIDS PUMPED Page 1 1REE= WELLI-EA D = 'ÄCiüÄi'Ö'R'= " 1<8. 8..BI ~ BF. ElBi'~' KOP=' , MiïxJ\ngiè'=' D3tum ~ = ' ....................... . .m. D3tum TVD= FtvC 4-1/16" 5M FMC GEN 5 69.60' 5626' 9Ëf@mj 4Kl' 7233' 6700' SS 120" X 34", 215.5Ib/ft. A53 ERW INSULATED H 114' 19-5/8" CSG, 40#, L-80, BTC, ID = 8.750" H 2915' Minimu m ID = 3.725" @ 6706' 4-112" HES XN NIPPLE 14-1/2"TBG, 12.6#, L-80, .0152bpf,ID=3.958" H 6717' ( 8-112 I SAFETY NOTES: I 1 ~ :8: 17" CSG, 26#, L-80, ID= 6.276" H 6825' ~ 14-1/Z' LNR, 12.6#, L-80, .0152 bpf. ID = 3.958" H 7650' PERFORATION SUWMARY REF LOG: A NGLE AT TOP ÆRF: 58 @ 6900' I\bte: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DA TE 3-3/8" 6 6900 - 6925 0 04129/03 3-3/8" 6 6960 - 6926 0 04129/03 SL TD 7650 - 8535 0 14-112" SLTDLNR, 12.6#, L-80, .0152bpf, ID= 3.958" H 8535' DA TE REV BY COMI\tENTS 08107/02 JDM/KAK ORIGINAL COMPLETION 08/15/02 RL/lP GLV 00 11/18/02 GC/KA K A DO BKR SLIDING SL V 04/09/03 DRSlTP TVD/1'vO CORRECTIONS 04129/03 JF/lP AIFERFS 06/15/03 JM/KAK GLV 00 I I I I J--I- - - - _I DATE REV BY ~ I 2257' H 4-1/2" HES X NIP, ID = 3.813" 1 I It. L ST I'vO 3 3850 2 5654 1 6529 GAS LIFT MANI:R8..S TVD DBI TYPE VLV LATCH 3813 1 KBrv'G-M DMY BK 5617 1 KBrv'G-M DMY BK 6451 35 KBrv'G-M DMY BK FORT DA TE 0 06/15/03 0 06/15/03 0 06/15/03 I I I 6586 H4-1/2" BKR SLlONG SLY I ~ 6658' H 7" X 5" BKR PRM PKR, ID = 3.875" 1 6685' H4-1/Z' HES X NIp, ID = 3.813" 1 6706' H4-1/Z' HES XN NIP, ID =3.725" I 6710' H 5" X 7" BKR ZXPLNR TOP A<R, ID = 4.390" 1 6718' H 4-1/2" WLEG,ID= 3.958" 1 I ELMDTTNOT LOGGED 1 ~ 6863 H 4-1/2" SHORT JOINTW/ RA TAG ~ 7542' H4-1/Z' C8IIIß\JTI3) PA YZONE ECP, ID = 3.937" COWMENTS ALRORA UNIT WB..L: S-112 ÆRMT No: 2021350 API No: 50-029-23099-00 SEC 35, T12N, R12E, 4332' FSL & 4501' FB.. BP Exploration (Alaska) ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): l' "" 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 69.60 8. Property Designation: ADL-0028257 11. Present Well Condition Summary: Total Depth measured 8642 true vertical 6742.7 feet None Repair WellD PluQ PerforationsD Pull Tubing D Perforate New Pool D Operation Shutdown D Perforate D Stimulate 00 OtherD WaiverD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 202-1350 6. API Number 50-029-23099-00-00 4. Current Well Class: Development D Exploratory 0 Service ŒJ Stratigraphic D 9. Well Name and Number: S-112 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool feet Plugs (measured) Junk (measured) None Effective Depth measured 8642 feet true vertical 6742.7 feet Casing Conductor Li ner Production Surface Length 80 1825 6794 2881 Size 20" X 34" 215.5# A53 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 MD TVD Burst Collapse 34 114 34.0 - 114.0 6710 - 8535 6589.7 - 6753.4 8430 7500 31 - 6825 31.0 - 6666.8 7240 5410 34 - 2915 34.0 - 2878.4 5750 3090 RECE\VED True vertical depth: 6711.01 - 6724.29,6741.39 - 6748.51,6772.52 - 6759.56,6759.22 - 6753.55 SEP 2 1 1.004 C Commission 6714 A\.aka Oi' & Gas .' øns~ Anchorage Perforation depth: Measured depth: 6900 - 6925,6960 - 6976,7649.6 - 8294.91,8333.72 - 8533.3 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 29 Packers & SSSV (type & measured depth): 4-1/2" Baker ECP Packer 4-1/2" Baker PRM Packer 4-1/2" Baker ZXP Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 -571 250 0 -1626 500 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ):1 úMLf C-.~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations. ! Signature Form 10-404 Revised 4/2004 @ 7542 @ 6654 @ 6710 Oil-Bbl 0 0 Tubing Pressure 1898 1766 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ WAG D GINJD WINJŒ] WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 303-336 Title Production Technical Assistant Phone 564-4657 9/16/04 Date ORIGINAL RBDMS L SEP2? , I. . S-112 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/14/03 HEAT FRAC TANKS TO 105*FI FREEZE PRETECT FLOWLINE WI 5 BBLS NEAT METH & TBG WI 38 BBLS 60/40 METH 11/16/03 HEAT DIESEL IN TRANSPORT TO 90*. MAINTAIN 2500 PSI ON IA DURING FRAC. Pumped 3 stages per program. 8400# rock salt diversion pumped in gelled diesel, 10057# of 16/20 carbo-lite in slickwater and cross linked gel. All stages overflushed into formation. Recovered all tree saver cups. Freeze protected with 20 bbls diesel. FLUIDS PUMPED BBLS 7 1407 104 145 175 1838 Diesel Sea Water w/Slick agent GUARJ877 Sea Water wlSlick agent GUARJ877 and 1 ppg 16/20 Carbo-lite Gelled Diesel wI 2 ppg rock salt 2 ppg 16/20 Carbo lite in YF130LG TOTAL Page 1 ( November 12, 2003 BP Exploration (Alaska) Inc 900 E Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage, AK 99501 Re: Sundry Notice for S-112 HPBD Dear Tom: A High Pressure Breakdown (HPBD) will be performed to stimulate injector S-112i. The HPBD will use fracturing equipment to provide short-term 40-50Mb/d Injection rates with viscous fluid and establish increased fracture conductivity to reservoir. Rock salt will be used to divert injection to more reservoir and achieve multiple fractures for maximum injectivity. If you have any questions, please contact Jim Young, Aurora Petroleum Engineer at 564- 5754 or by email atYoungj3@bp.com. SinCerelY.,] . ; ~'\\. O~ Jim Young \ Aurora Petroleum Engineer Gc l~~/\\E. I ~'\..., \lED AI I), ¿'OO~J ¡'¡'t~, ûB8 C ons. Com. Enclosures (2) in duplicate ( STATE OF ALASKA" ALASKA Oil AND GAS CONSERVATION cOJI...dSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: 0 Suspend 0 Operation Shutdown 0 Abandon Alter CasinQ 0 Repair Well 0 PluQ Perforations 0 ChanQe Approved" ProQram 0 Pull TubinQ 0 Perforate New Pool 0 Perforate D Stim ulate [X] VarianceD Annular Disposal 0 Time Extension 0 OtherD Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 202-1350 BP Exploration (Alaska), Inc. Development D Exploratory CJ Stratigraphic D Service []] 9. Well Name and Number: 5-112 10. Field/Pool(s): Prudhoe Bay Field / AURORA Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 6742.7 8642 6673.1 Size MD TVD 6. API Number 50-029-23099-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 69.60 KB 8. Property Designation: ADL-0028257 3. Address: 11. Total Depth MD (ft): 8642 Casing Length Plugs (md): None Burst Junk (md): None Collapse Conductor Liner Production Surface Perforation Depth MD (ft) 6900 - 8294.9 6960 - 8533.3 7649.6 - 6925 8333.72 - 6976 Packers and SSSV Type: 4-1/2" Baker ECP Packer 4-1/2" Baker PRM Packer 4-1/2" Baker ZXP Packer 12. Attachments: Description Summary of Proposal IX) Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Ope ratio 16. Verbal Approval: Commission Representative: 80 20" X 34" 215.5# A53 1825 4-1/2" 12.6# L-80 6794 7" 26# L-80 2881 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6773 - 6759.56 6759 - 6753.55 6711 - 6724.29 6741 - 6748.51 top 34 6710 31 34 bottom top 114 - 8535 - 6825 - 2915 Tubing Size: 34.0 6589.7 31.0 34.0 bottom 114.0 6753.4 6666.8 2878.4 Tubing Grade: L-80 8430 7240 5750 Tubing MD (ft): 29 7500 5410 3090 4.5 " 12.6 # 6714 '''ED Packers and SSSV MD (ft): Date: 6654 ~f " ^ I . Ini')' 671Æ C:~tJ;J 7542'\<:'~~~ i~)ji ,'j;¡, {;Û\S C" .. , 13. Well Class after proposed work: 4nf'\~ ' tillS. Co, ExploratoryD Development D t~"'~t~e IX) 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD WAG D GINJD WINJOO WDSPLD Perpared by Garry Catron 564-4657. November 16, 2003 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ",~es ,oung {w..\(~ Title Contact Jim Young Petroleum Engineer 564-5754 11/11/03 Signature Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry NY~Ö3 . 3:3 /¿;; I Plug Integrity D BOP TestD Mechanciallntegrity TestD Location Clearance D Other: Subsequent Form Required: Approved by: /' ~. þ . Form 1 0-40t!:v se~ ~ ~ 40'-/ 8)MSBfL NOV 19 20(fj BY ORDER OF THE COMMISSION Date: (l (il()~ SUBMIT IN DUPLICATE STEP # COMMENTS S112i HPBD Pump Schedule FLUID TYPE Stage #1 HPBD 1 HPBD/SDT Slick Water (1 gpt J313) 2** 1 ppa 16/20 Slick Water (1 gpt J313) 3** HPBD/Flush Slick Water (1 gpt J313) Perform a SDT during last 10 bbls, SD and obtain ISIP Stage #2 Diversion/HPBD/Scour 4 2 ppg Rock Salt Gelled Diesel 5 GD Spacer Gelled Diesel 6 2 ppg Rock Salt Gelled Diesel 7 GD Spacer Gelled Diesel 8 HPBD Slick Water (1 gpt J313) 9 1 ppa 16/20 Slick Water (1 gpt J313) 10 HPBD/Flush Slick Water (1 gpt J313) Perform a SDT during last 10 bbls, SD and obtain ISIP Stage #3 Diversion/HPBD/Scour 11 2 ppg Rock Salt Slick/Gelled Diesel 12 GD Spacer Slick/Gelled Diesel 13 2 ppg Rock Salt Slick/Gelled Diesel 14 GD Spacer Slick/Gelled Diesel 15 HPBD Slick Water (1 gpt J313) 16 HPBD YF130LG 17 1 ppa 16/20 YF130LG 18 HPBD/Flush Slick Water (1 gpt J313) TOTALS RATE FRICTION PRESSURE 39 97 168 242 322 423 510 605 PUMP RATE (BPM) 40 40 40 10 10 10 10 15-20 20-25 40 STAGE (BBL) DIRTY VOLUME CUM (BBL) DIRTY VOLUME STAGE CUM (GAL) (GAL) PROPPANT/DIVERTERS CLEAN VOLUME PPA STAGE CUM PROP CUM RS GROSS GW (LBS) (LBS) (LBS) (BBL) (BBL) 200 50 200 -"-- ---~-- -- 200 8400 8400 200 200 10500 -~-~~~-_._---~---- 250 2100 2011 2011 48 48 ~-_. ___-_~n 450 8400 18900 200 200 ----~-- --~------------- 480 1260 20160 2 2520 2520 28 ~-~----~------------- - 490 420 20580 10 ---------"---_._._--_..~- 510 840 21420 2 1680 4200 18 21840 - ---~._----~------~- 520 420 10 645 5250 27090 125 125 -------------- 695 2100 29190 2011 4023 48 48 --~-_._---------_.--- - ...-.\ 855 6720 35910 160 160 --------------- ------ ----- 30 10 20 10 125 50 160 10 20 875 10 10 885 10 15 900 10 10 910 15-20 125 1035 40 100 1135 20-25 75 1210 40 120 1330 1330 840 36750 2 1680 5880 18 420 37170 10 630 37800 2 1260 7140 14 ~-~-_._.____M___- ------- . 420 38220 -----------. 10 ~-~~----'-'------ 5250 43470 125 125 ~----- - 4200 47670 100 100 3150 50820 2 6034 10057 72 72 55860 --~------------- 5040 120 120 EST Pipe WHTP Time 2528 21,8 2587 10,9 2657 7,3 2731 5,5 2812 4.4 2912 3,6 3000 3 3094 2,7 «60 deg Seawater f/CPF2 «bring 150 bbls « bring 12,000# «bring 9000# 55860 1316 1198 FRICTION FACTOR 5 0,0058 10 0,0145 15 0,0250 20 0,0360 25 0,0480 30 0,0630 35 0,0760 40 0,0900 TANKS REQUIRED= 2,7 GD REQUIRED= 121 PROPPANT REQUIRED= 10057 ROCK SALT REQUIRED= 7140 NOTES: 1. Pump HPBD at MAX rate possible. **Only pump if deemed necessary from SDT 2. The diversion stages should be modified as appropriate, pending success of the rock salt slugs. «for slick water with J313 10057 7140 WELL AND TREATING PRESSURE INFORMATION FRAC GRADIENT= 0,65 BHTP= 4762 FLUID GRADIENT= 0.443 HYD HEAD= 2973 MD TO Tbg Tail = 6717 PERF FRIC= 700 TVD TOP A SAND PERF= 6711 MD TOP A SAND PERF= 6900 TUBING HANGER= 0 UPPER TUBING SIZE= 4,500 MIDDLE TUBING SIZE= 4,500 LOWER TUBING SIZE= 4,500 LENGTH OF MIDDLE TBG= 0 LENGTH OF LOWER TBG= 0 CASING SIZE= 7,000 FLUSH VOLUME TO TOP PERF= 109,2 0,0152 bbls./ft 0,0152 bbls./ft 0,0152 bbls./ft 0,0382 bbls./ft State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy RUedriCh'- ) J DATE: June 24,2003 Commissioner k 7 ¿ Da /"; .,¡ 1\ c\l02"? S BJECT: Mechanical Integrity Tests THRU: Jim Regg '(Jt'4¿¡ \ BPX P.I. Supervisor' ,,\ S & E pad S-112 & E-103 FROM: Lou Grimaldi Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON. CONFIDENTIAL MEMORANDUM Packer Depth Pretest Initial 15 Min. 30 Min. Well 5-112 Type Inj. 5 T.V.D. 6551 Tubing 2000 2000 2000 2000 P.T.D. 2021350 Type test P Test psi 1638 Casing 200 1815 1795 1780 Notes: Initial test after production flowback. Observed pretest conditions for thirty minutes. Well E-103 Type Inj. F T.V.D. 7885 Tubing 750 750 750 750 P.T.D. 2012000 Type test P Test psi 1971 Casing 1000 2120 2110 2105 Notes: Initial test after workover Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Interval I f 0./ / P/F Interval I ..--/ P/F f Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I met Teresa Paterson and Troy 8now (BPX DHD) on 8 pad and witnssed the initial MIT on 8-112. The test went very well with a negligable loss of pressure (35 psi non-linear). We moved to E-I03 and, after rigging up, performed an MIT on this recent conversion after Workover. This test also went well with a 15 psi decline. Both wells were properly prepped and teres a provided the needed information to make these wells easy to perform the tests. M.I.T.'s performed: Two Attachments: None Number of Failures: None Total Time during tests: 4 hours cc: Anders/Cubbin (BPX) MIT report form 5/12/00 L.G. 2003-0624_MIT _PBU_E-1 03_lg.xls 7/9/2003 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / S 06/24/03 Anna Dubel Teresa Patterson Lou Grimaldi fYJv'¡7).!t0 Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Well S-112 Type Inj. S MD/TVD 6,658' 6,551' Tubing 2000 2000 2000 2000 Interva I P.T.D. 2021350 Type test P Test psi 1,638' Casing 200 1815 1795 1780 P/F P Notes: Post Inj. MITIA Well Type Inj. MD/TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. MD/TVD Tubing Interva P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0624_MIT _PBU_S-112.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depths (ft.) Pretest Well 5-112 Type Inj. N MDITVD 6,658' 6,551' Tubing 1,400 P.T.D. 2021350 Type test P Test psi 1,638 Casing 140 Notes: Initial MITIA, pre-injection start. Another MITIA will be conducted post-injection start. Well Type Inj. MD/TVD Tubing P.T.D. Type test Test psi Casing Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 Type Inj. Type tesl Type Inj. Type test Type Inj. Type test BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / S Pad 06/18/03 Joe Anders MD/TVD Test psi MD/TVD Test psi MD/TVD Test psi TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Initial 15 Min. 30 Min. 1,400 1 ,400 1 ,400 Interva I 3,000 2,960 2,960 P/F P Interva P/F Interva P/F Interva P/F Interva P/F AUrV'CL Tubing Casing Tubing Casing Tubing Casing 2003-0618_MIT _PBU_S-112j)reinject.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) !)ŒJ -05 \ l q~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 21,2003 RE: MWD Fonnation Evaluation Logs: S-112 AURORA, AK-MW-22107 S-112 AURORA: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exp]oration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~O~~9--I\~~ E E'V~" JUN 0 2 2003 ~~~'\'{\~ Alaska o¡.! &. Gas Cons, Commitaioo Anch~Je \JGA- Drys ~1S) 4-/ l..,-I z...o 0 ''$ 1-1 2- z- (() ~"? -J '1 ~\()j I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Packers & SSSV (type & measured depth) 7" x 5" Baker PRM PKR @ 6658'. 5" x 7" BKR ZXP Liner Top Packer @ 6710'. 4-1/2" HES 'X' Nipple @ 2257'. 13. Attachments Description summary of proposal_X Detailed operations program- 14. Estimated date for commencing operation 15. Status of well classification as: June,2003 ( 16. If proposal was verbally approved 1. Type ofrequest: Abandon- Alter casing - WAG INJECTION CONVERSION 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Suspend- Repair well - Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service- 948'FNL,4500'FEL,Sec.35, T12N,R12E,UM At top of productive interval 943' FNL, 3716' FEL, SEC 35, T12N, R12E, UM At effective depth 225' FNL, 2159' FEL, SEC 35, T12N, R12E, UM At total depth 225' FNL, 2159' FEL, SEC 35, T12N, R12E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 618930,5980535) (asp's 619714,5980553) (asp's 621258, 5981296) (asp's 621258,5981296) 8642 feet 6743 feet 8642 feet 6743 feet Plugs (measured) Effective depth: measured true vertical Casing Length Size Conductor 120' 20" Surface 2882' 9-5/8" Production 6791' 7" Liner 1825' 4-1/2" Junk (measured) Cemented 260 sx AS (approx) 506 sx AS III Lite, 211 sx Class 'G' 218 sx LiteCrete, 184 sx Class 'G' 112 sx Class 'G' Perforation depth: measured Slotted Liner 7650'-8535'. true vertical Slotted Liner 6772' - 6753' Tubing (size, grade, and measured depth 4-1/2" 12.6#, L-80 @ 6717'. Oil- Re-enter suspended well - Time extension - Stimulate - Variance - Perforate _X 6. Datum elevation (OF or KB feet) RKB 69.6 feet 7. Unit or Property name CONVERSION Other _x Prudhoe Bay Unit 8. Well number S-112 /' 9. Permit number /approval number 202-135 ./ 10. API number 50-029-23099-00 /' 11. Field / Pool Prudhoe Bay Field I Aurora Pool Measured Depth 154' 2916' True vertical Depth 154' 2879' 6825' 6666' 6589' - 6753' 6710' - 8535' RECEIVED APR 1 8 2003 Alaska Oil & Gas Cons. Commission Anchorage BOP sketch - Gas- Suspended - Name of approver Date approved Service WAG INJECTION 17. I hereby certifyth(allhe fO"'1in, ,is true and correct to the best of my knowledge. Questions? Call Jim Young@564-5754. Signed ,~ ~ Title: Aurora Surveillance Engineer Date April 15. 2003 Jim Young Prepared by DeWayne R. Schnorr 564-5174 J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical I n't;g rity TestX - Subsequent form required 10- I Approval no. .3c '3v- í 'd-i-/ tfo1 Æ,~,. ~ +:t,.. t:.1rA ~ommiSSioner ~[¡£¡j~ ~ l< 'f~ub~ Approved by order of the Commission Form 10-403 Rev 06/15/88 . Date IßJj¿>~ SUBMIT IN TRIPLICATE bp April 15, 2003 (~ ... .",.,". -...,~ ~....- ~..- ~..~ ....~ F"-' .'I'''I\~ ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for S-112 conversion to WAG injection well BP Exploration Alaska, Inc. proposes to convert well S-112 to WAG injection. ~' Additional perforating is proposed for Aurora development well S-112 to increase rate prior to converting the well to injection. Water injection will commence in mid-June. --- A USIT/GR log was run on this well during the initial completion. The cement bond is good across the interval that will have WAG injection. The procedure includes the following major steps: Category S E 0 0 Step 1 2 3 4 Description D & T with Dummy Gun. (3.375" gun, bottom 6976' md). Jewelry Log / Ad Perf. (POP immediately). D & T, DGLV'S, SBHP's. (1-2 weeks after perf cleanup). MITIA and Injectivity Test (300 bbls). (Injector Conversion). ,./ 1)~~per attached form. POP with 2MM GL T, test & flow 2-weeks for perf ~~p. 2) Install DGL Vs & SBHPs per attached. (verify well SI at least 5-days before SBHPs) 3) MITIA to 3000psi in perform injectivity test at 2000 and 2800psi. a. Need 300bbls water (tubing vol +75bbls at each pressure, 30 bbls 60/40 meoh) AOGCC witnessed MITIA within 1-2 weeks following injection startup. / Last Test: FBHP: Max. Deviation: 04-06-03,6 SOPD, 30 SWPD, 1734 Mscf Gas. To be taken. 96° @ 7457' md Deviation at top perfs: 95° Perfs: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: ( , Gl\- '7(,50 ~ Present Perfs (slotted liner) 7856' to 8535' MD /' One----3.725" XN nipple @ 8397', see schematic. 8535' . Tubing Tail Plug @ 6691' for SBHP survey, 08/13/2002. < 10 ppm Sperry MWD GR (08/01/2002) Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. S(:IV~ Jim)Y oung Greater Prudhoe Bay Aurora Development Engineer I S-,,1- aU:í D~. W a...-~J ~n?Y'e-- ~ ~v EP ç twtz')v\...wJ¡- CQIA.~\¡VVÙ ï M r ~ 4.) I IJ;JII~ 'k. /to a.. . 1£.-1 (1 ~-.:r '-I/~ '1.. )~o~ (' J 112 (. ( I" PERFORATING PROCEDURE Well: Date: API #: 50-029-23099-00 Prod Engr ..~!~..!~~~~................_.._.._. Office Ph: 564-5754 --''''''''''.''''''''''''''''''''''''''.''''''''''''''''''''''''''''''''''............... Home Ph: 248-0133 5-112 ....................,...........................................-................... 4/8/03 ............................-..............,....................................... ............................,................................................",'n"""""" Ver 4,0 06/04/01 H2S Lev.'" Ij <10ppm Cell/Pager. ................................~~~.~!.........................,..,',. CC or AFC: AUD5M0055 Detail Code: 9335-070-770 Description::~~Ç§:Tç§:~~Ç~~§.~::?,::~~~~~::.....................-......................::::::::::::::::::::::::::::::::::::::::::~:::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::,..........................................................,,,,,.,,,,,,,.,,,,,,,,,,,,,.. lOR 1500 WBL Entries Work Desciption cleanout tubing, memGR/CCUflag, perforate underbalanced Type E Well Objectives and Loaaina Notes: Tie-in and shoot in 2-trips, top shots first. Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log MWDGR ,.................,................ 8/1/2002 Tie in Log CCL Add 0 .......................................................... to the tie-in log to be on depth with the reference log. Log: Date: Company: ..................,................ .~.e~r.!Y.................... memory ...............,............... r Depths (from-to) 6,960 6,976 Depths (from-to) 6,960' - 6,976' Feet 16' SPF 6 SEE Phasing 60 ...................................... .................................... ........................,.......... .....,.............................. "."'".''''''.''''''''''''''' .......................................................... /6,900' 10.................................. ................................... "".'."""""'.'."""""'.'" ...............,............... .......................................................... 6,925' 6,900' 6 6,925' 25' 60 DIAGRAM ...............,............... BELOW .....................................,.................... ............................,......... ..........................,......... ..................,................. -.................................. ............................,......... ................................... .................................... """'"''''''''''''.''''''.''''''''' ............................... ......................................,.................... ...................................... ..................,................ ........................,........... """""."""""""""""'" ..............,................ ......................................,................... Gas Jetting Expected? No At what Depth? ......,............................. Requested Gun Size: ,...........~.:.~~~.~........... Charge: Desired Penetration: feet Zone Ad/Re/lperf C Iperf ......,.......................................................................,. """"""""""""""""",,"""""""'.'".....................,. .........~...............................~p..~~..................... ............................................................................. ...........,.................................................................. N/A ................................................ MAX Swell=3.66" in GAS Entry Hole Diam: ................................. Max Penetration 3506POWERJET ................................................. >20. Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping is installed) (e,g, N2 Lift, HardJine Lift Gas, Gas Lift. Flow Well, Backflow Through Drain or Hardline) POOH & POP W /2MMGL T ..~.~~y'~..~.~~~..~!..~..~~gg.!..~.~~~.~~§.~i..................................................................................................... .................................................."................................................................................................................................................. Tie in to Jewelry @ Minimum ID: Tail Depth: 6863 .................................... 3.725 ................,................... 6718 in ..~~.~.~!.~.9..~~!.~!..~~..~~~........................................................................................................................................ ,..........................................~:.~.~~!:~.~........................................' @ .....~.?~.~..... 'MD MD in Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ ftMD .................................... 4,5 "'.n.........""""'.'."" ..........?.:~~9......... MD is Last Tag: HAW ft MD on .................................... .................................... Perforation Summary Well: Date: S-112 -------------........--. API#: 50-029-23099-00 ....................?~~~. psi PBTD Prod Engr: ","n.....'mmn......,......."'"'''''''''''''''''''''''''''''''''''''''''''''''''' Anch Prod Engr P.O. Center Summary Dist Town: ................................... .........................................,........................ ........................................................, General Comments: ....................................................,..............""""",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,................................................................''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''...,................. ................................................................,.""""""""""""""""""""""""""""""""".......,............................................"".........."""""""""""""""""""""""""""""""""..............................................................,.......................".................. Balance Depths Referenced to BHCS Orient. SPF Phasing Gun Dia. O/B/U O/B/U O/B/U O/B/U 00 00 LW Name: DRILL PAD S NO 112 API: 500292309900 Spud Date: ~~ e~Qllrement Ref. ~ J:! ..................................., ...............,.................... .................................... .............,.,.............. ...................................' "............,..................... .................................... .n."""",'"'''''''''''''' """""'''''''''''''''''''''''''' ,,'n..........'"'''''''''''''''''' .....,.............................. """""'''''''''''''''''''' .................,,,..............," .......,............................ ................................... ....,.........,.........,..... Zone Aperf/Reperf """"""""'"''''''''''''''''''''''''''''-''''''''''''''''''''''''''''' """"""""""""""",,,,,,,''''''''''''''''......................., ..,......,.....,.........................,........,.......................... ""''''''''''''''''''''''''''''''''''''''''''''''''''''..................." TRH; = FWÞ:: 41/1a"5M WELLHEA D = FMC GEN 5 'Ac ruÃTOlf;;_m_",__,.._,..,..__m,m,....._m,.. 'ï<ìf"ELB¡ ;;.. 69.60' '.B~F'~' Eï::B:I-.;..~_..n"""'.~'h,"....~.,~,-",.w~"..m....~'m..' 'ï«)'p';;""'^""""'" , ,,' "'''''''''''-5626' M3x'Ä~gi~~" ...,.. '" "OO"@'7467ì i)';tü¡:;:¡-w" ;;;;',.., '''''m,,__no_..-m-7233' "-'.""'''.'''-~'~.",..."..",.mH. """.,-<,,-,...~...~^~..~~..,. D~tum lV D = 13700' S S 8-112 I I ~ 120" X.34'. 215.5 Iblft.A53 ERW NSULATED H 114' 19-5/8" eSG.40ff!. L-ao. BTC. ID = B.7E{J" H 2915' Minim u m ID = 3.725" @ 6706' 4-11l" HES XN NIPPLE :8: 141/2" TBG.12.6#, L.SD, .D152 bpf, ID= 3.953" H 6717' 17" CS(), 26#, L-eo, ID = 6.:276" H 68Z5' ~ . 41f2" LNR, 12.6ff!. 1.:80. .0152 bpf. ID = 3.Q5S" H 7650" PER FO RA TlON SUMMARY REF LO~: ANGLE AT TOP PERF: 85 @ 765[)1 NQN: Refu to PrQduction DB fQr histQrio~1 plirf d..t.. SIZE S PF INTBW AL 0 ¡;>n/S<:z DA TE SL TD 7650 - 13535 0 I I I I 14112" SL TD LNR. 12.6#. I.: 8D, .D152 b pf, ID = 3.958" 1-1 8535' t----- - - - - I DA TE RBI BY COMtvENTS 08107/02 JDMlKAK ORIGINAL COMPLETION 08115/02 RUT? GLV c/o 11/1aJ02 GC/KAK ADD BKR SLÐIN~ SLV 04IQ~/03 DRSrrp TVD/tvD CORRECTIONS DA TE REV BY I I .. L (' I SAFETY NO TES: Ii.. 2251" H 41/2" HES X NIP. ID = 3.813" I ST MD 3 3850 2 5654 1 6529 GAS un MANDRELS TVD DEV TYPE VLV LATCH 3813 1 KB~- M DOLlE BK 5617 1 KBMG- M DO~ BK 6451 35 KBMG-M 50 BK PORT DATE 18 OaJ1~02 16 0B/13/02 20 OB/13/02 I I I 6586 H41f2" BKR SLIDING SLV I ~ 6658" H 7" X5" BKR PRM PKR, ID = 3.875" I .. . COMtJENTS 6685" H4112" HES X NIP, ID = 3.813" I 6706" H41/2" HES XN NIP.ID = 3.725" I 6710" H 5" X 7" BKR zx.p LNR TDP PKR. ID = 4.a9D" 1 6718" 1-1 4 1/:2" W LEG. ID = 3.858" I I EUv1D TT NOT LOGGED I 6863 1-1 4112" SHORT JOINTW/ RA TAG 7542" 1-I41/'Z' C 8\A8'I TED PA yz 0 NE EC P. ID = 3.937" AURORA UNIT WELL: S-112 PERMT No: 2021350 API No: 50- C2G- 2308e- 00 SEC 35. T12N. R12E, 4332' FSL& 4601' Fa. BP EXploration (Alaska) ( Aurora Area Injection Oraodification 12/9/2002 (' W optimizing parameters such as WAG ratio, slug volume, optimum MI start-up time, and the required volume of MI. Surveillance Plan To ensure the efficient allocation of MI for the Aurora EOR project, rate and pressure response to injection will be monitored. Production fluid samples will be taken at least annually to assess pattern efficiency based on the returned MI (RMI) ratio. Injection of MI into patterns that do not achieve minimum recovery levels based on comparison to all patterns (i.e., marginal patterns) will be discontinued until recovery issues are resolved. A significant amount of surveillance has been completed to assess producer-injector connectivity. This work has included static pressure monitoring, material balance estimates and acquisition of repeat-formation tester (RFf) data to assess layered depletion effects prior to initiation of water injection. Due to strategic placement of injection wells using this data, all injection wells planned for MI have confirmed communication to offset producers. Injector well pressures' will be closely monitored to identify any patterns that exhibit a lack of communication to production. Mechanical Condition of Wells Within a One-quarter Mile Radius of Injectors 20 AAC 25.402(c)(15) Five injection wells are proposed for MI service: Wells S-lOli, S-104i, S-107i, S-112i and S-114i. A map showing all penetrations through the AOP, and wells within a one- quarter-mile radius of the injection wells are shown on Exhibit 1-2. A report on the mechanical condition of each well that has penetrated the injection zone within a one- quarter mile radius of a proposed injection well is included as Exhibit VI-I, with a copy of the most recent schematic diagram for each well included as Exhibit VI-2. Mechanical integrity has been established for the subject wells based on calculated cement tops being at an adequate height above the injection zone to prevent fluid that is injected into the AOP from flowing into other zones or to the surface. Exhibits VI-l and VI-2 contain mechanical integrity data only for wells within a one-quarter mile radius of the injectors. However, static pressure and repeat formation tester data support the conclusion that the completions in offset wells beyond this radius are sufficient to contain 8/9 ( Aurora Area Injection Ord.odification ( -' 12/9/2002 high pressure fluids, including gas, within the AOP. Although injection pressure will exceed average AOP reservoir pressure, reservoir modeling indicates rapid reservoir pressure falloff away from the injector during water and MI injection. Reservoir modeling indicates a radius of pressure influence less than 1000 feet from the injector at the end of the MI cycle. List of Exhibits 1-1 Aurora Pool Location 1-2 Top Structure Map with offset penetrations II-I Affidavit 111-1 111-2 III - 3 111-4 111-5 IV-l V-I S-101i Completion Schematic S-104i Completion Schematic S-107i Completion Schematic S-112i Completion Schematic S-114i Completion Schematic Aurora and Prudhoe Bay Oil, MI Properties Production and Recovery Profiles for Miscible gas Injection VI -1 a Offset Integrity: Wells Within 1,4 mile of Injectors VI-lb Mechanical condition of Wells Within 1,4 mile of Injectors VII-I-12 Schematics of Wells Within 1,4 mile of Injectors 9/9 Exhibit VI-1 Offset Well Integrity: Wells within 1320' of injection S-112i only current AOP injector w/offsets within IA mi. radius ,Well: ' , -- '¡rVïëas: Subsea-' " ¡Toe ,,' 'Ést.(30c%) 'd U';joh'UTCommeni:-"othe-r---' ¡ I~a~e I~~~~: IWell Status Desc 1~0~ (~; 1;0~ ~~) 1~~et,~:~~~Shl~~~:(;\a~o: ~1:~S~~~:~:;;~t. I S~~~2 -@L~~i> P~e-Prod. Inj-Heel . 6,852» 6,614,>1 3,168ii '3,685l.JSlm~Or:)@)3250'! ~~~~ ~~~ ~~:::~~~~~¥S . ~1}~- ~~~. ~:;;: "--"--~.. -+---"~~----""I IS-33 "GL-O :Oil Well On Gas-Lift: 6,725 6,620 564: 4,666 2,059; ¡ , , ' , ' " , ,,- u( ,S-38 "GL-O ',Oil ~ell On Gas-Lift 6,863 6,620 568 ,4,584, ?,~!~: -..n i. ..,..n__, -, S-24 P&A P&A '7,282' 6,620' 617 4,933 ,2,349: ' ,-, , S-10A .SI-S ,T/A' : 6,801; 6,620, 843; 5,288 ; 1,5'13)' , - ..-.., . _.. , t..~_:~~m"~__H GL-O 'oft Well On Gas~Lift 6,938' '6,620'" 846, '2,08'0' 4,a'S8" -- " - ¡" H _.. --,-- ,__n'_" ; IS-42 Gc:õ=#-löiI "Yell On Ga~-Lift ,7,210 6,620 883 2,962 4,?4åi'~-r-"--^>M"~~--~_.'-'"-"~-'l ,S-32 ,81-0 ,Oil VV~IIOn Gas~Lift:, 7,454, 6,6201, 925~ 5,097 , 2',357; '1-- 8-37 GL-O 'Oil Well On Gas-Lift: 6,787 6,620: 1,139 4,526 , 2,261, -35 GL-O n Gas-Lift 7,2 6,6 1,192 , 81~r=="=»='~"'.-»"~"-2,423"'--->- (8-:26'-- SI-O Oil Well On Gàs-Uft 6,850 6,620 1 ,280 4,32:rr---~"""-~-2:526!" S-112 GL-O Pre-Prod.lnj-Toe 8,550 6,620 1,723 3,168 , . '" â" &:~ aca-/35 J /5/1 WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 17, 2003 RE: MWD Fonnation Evaluation Logs S-112, AK-MW-22107 1 LDWG fonnatted Disc with verification listing. ~I#: 50-029-23099-00 PLEASE ACKNOWLEDGE RECEIPf BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: s~, tJ&.pJ RECEIVEr) FEB 18 A1al:!:lr~ U"\.~ .11, r;:, ,-", , " '" . . ' ,;¡¡f¡,,¡a .. I.h v'tiíi:! \. "I l' '<1rn~<!'<JI.."'ì'f"1 -""..'¡.è",.w""~v~, Anchor~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 10/17/02, Put on Production ( ( 1. Status of Well IBI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4331' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 4336' NSL, 3716' WEL, SEC. 35, T12N, R12E, UM At total depth 5054' NSL, 2159' WEL, SEC. 35, T12N, R12E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 69.6' ADL 028257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/22/2002 8/1/2002 8/7/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8642 6743 FT 8642 6743 FT IBI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, USIT, DEN, NEU, ABI, ABGR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" X 34" 215.5# A53 Surface 120' 48"260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 2916' 12-1/4" 506 sx AS III Lite, 211 sx Class 'G' 7" 26# L-80 31' 6825' 8-3/4" 218 sx Litecrete, 184 sx Class 'G' 4-1/2" 12.6# L-80 6710' 8535' 6-1/8" 112 sx Class 'G' ~'L«fl~ ~~l,' ~! "sWl'J¿~-, L -_.~ ~, ' ~... ',,' - '. I::) ¡ ~~~ Classification of Service Well Pre-Produced Injector 7. Permit Number 202-135 8. API Number 50- 029-23099-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-112i 11. Field and Pool Prudhoe Bay Field / Aurora Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2257' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 6718' PACKER SET (MD) 6658' MD 7650' - 8533' TVD 6772' - 6754' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7485' - 7488' Cement Payzone Packer at 7542' with 28 Bbls Class 'G' through perfs Freeze Protected with 136 Bbls of Diesel 8535' - 8642' 6-1/8' Open Hole, Non Productive HRZ Shale 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 7, 2002 Gas Injection, Shut-In Date of Test Hours Tested PRODUCTION FOR OIL-BBL 10/7/2002 4 TEST PERIOD 705 Flow Tubing Casing Pressure CALCULATED OIL-BBL Press. 24-HoUR RATE 28. CORE DATA No co~n:~::~::~:ft::~Ogy, po~, hcllires, apparent dips and presence of oil, gas ~::a SU:jiliì 'V 10 '1 q 0 M 5 B F L '- OC1 2"\ 2002 O,~& Gas IOns. CQmtr,.\ NøÞ" MèM~e GAs-McF 371 GAs-McF WATER-BBL -0- WATER-BBL CHOKE SIZE 1760 OIL GRAVITY-API (CORR) GAS-OIL RATIO 526 Form 10-407 Rev. 07-01-80 ~ Ij ~ II ~ '\1 ~ I L. Submit In Duplicate (' 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Schrader Bluff M Sands 4794' 4757' Schrader Bluff N Sands 4986' 4949' Schrader Bluff 0 Sands 5104' 5067' Base Schrader Bluff I Top 5390' 5353' Colville HRZ 6774' 6634' Kuparuk C 6896' 6709' Kuparuk B 6998' 6758' Kuparuk A 7027' 6768' Kuparuk A (Inverted) 7456' 6787' Kuparuk B (Inverted) 7611' 6776' Kuparuk C (Inverted) 8560' 6751' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ Hu..ß6'& Hie Technical Assistant Date /0 "/7 -0:>""" S-112i 202-135 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L:~~i~~~[,~~~~~.~~~~~EC. 35, T12N, R12E, UM f\' cm~~':),~~T,tñj,Ñl", ',:'1!',ÔCA ,. ~~'l'(:'"',.,, At to,P of produc~lve Interval , [{9'7:0Z. ~ ;", VE91fl~:(~ 4336 NSL, 3716 WEL, SEC. 35, T12N, R12E, UM " ,--, \ ~~o':f 10. Well Number 5~~¡~~k~~~\h59' WEL, SEC. 35, T12N, R12E, UM - 'J)ØL:t.! --\ i$~f .' ,- ---~.......,-~, ..:.... - ~ "''''7;.'.~....,-Jt;,,:....\-.I,.~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 69.6' ADL 028257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/22/2002 8/1/2002 817/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8642 6743 FT 8642 6743 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, US IT, DEN, NEU, ABI, ABGR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" X 34" 215.5# A53 Surface 120' 48" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 2916' 12-1/4" 506 sx AS III Lite, 211 sx Class 'G' 7" 26# L-80 31' 6825' 8-3/4" 218 sx Litecrete, 184 sx Class 'G' 4-1/2" 12.6# L-80 6710' 8535' 6-1/8" 112 sx Class 'G' Classification of Service Well Pre-Produced Injector 7. Permit Number 202-135 8. API Number 50- 029-23099-00 9. Unit or Lease Name Prudhoe Bay Unit S-112i 11. Field and Pool Prudhoe Bay Field / Aurora Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2257' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 6718' PACKER SET (MD) 6658' MD 7650' - 8533' TVD 6772' - 6754' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7485' - 7488' Cement Payzone Packer at 7542' with 28 Bbls Class 'G' through perfs Freeze Protected with 136 Bbls of Diesel 8535' - 8642' 6-1/8' Open Hole, Non Productive HRZ Shale 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RÄllO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBl GAs-McF WATER-BBl OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core cQj~s~"" ~;:¡{\ t..:: No core samples were taken. Form 10-407 Rev. 07-01-80 t t' ~ , Î A L ( IJ M 5 & t l SIT' I I ~bmit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Schrader Bluff M Sands 4794' 4757' Schrader Bluff N Sands 4986' 4949' Schrader Bluff 0 Sands 5104' 5067' Base Schrader Bluff / Top 5390' 5353' Colville HRZ 6774' 6634' Kuparuk C 6896' 6709' Kuparuk B 6998' 6758' Kuparuk A 7027' 6768' Kuparuk A (Inverted) 7456' 6787' Kuparuk B (Inverted) 7611' 6776' Kuparuk C (Inverted) 8560' 67511 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble -(~ ~ Title Technical Assistant S-112i 202-135 Well Number Permit No. / Approval No. Date Oq.O(p.O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ~ ~ Legal Name: S-112i Common Name: S-112i Test Date 7/27/2002 7/30/2002 8/212002 LOT FIT FIT Test Type Test Depth (TMD) 2,915.0 (ft) 6,854.0 (ft) (ft) BP EXPLORATION Leak-OffTestSummary TestHDepth (TVD) 2,878.0 (ft) 6,680.0 (ft) (ft) AMW 9.30 (Ppg) 9.80 (ppg) (ppg) Surface Pressure 1,080 (psi) 770 (psi) (psi) Leak Off Preuure (BHP) 2,470 (psi) 4,171 (psi) (psi) Page 1 of 1 'EMW 16.52 (ppg) 12.02 (ppg) 12.02 (ppg) ,~ -" Printed: 8/12/2002 2:42:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 1 of 9 BPEXPI.ORATION Operati()nS~tlml11aryRep()r1 S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Spud Date: 7/22/2002 End: 817/2002 Start: 7122/2002 Rig Release: 817/2002 Rig Number: Date . From..To Hours ',. ',Task Code NPT Phase Description. of Operations 7/22/2002 00:00 - 03:00 3.00 DIVRTR P SURF Held PJSM. N 1 U Diverter and Diverter Line, Riser and Flow Line. 03:00 - 04:30 1.50 DIVRTR P SURF Loaded Pipe Shed wi 4" Drill Pipe. R 1 U 4" Drill Pipe Handling Equipment. 04:30 - 05:00 0.50 DIVRTR P SURF Function Tested Diverter System, OK. Koomey Test, OK. Witnessing of Diverter Function Test waived by AOGCC Rep John Spaulding. 05:00 - 07:30 2.50 DRILL P SURF M 1 U and Stood back in Derrick 30 Stands of 4" HT 38 Drill Pipe. 07:30 - 09:00 1.50 DRILL P SURF M 1 U and Stood back in Derrick 7 Stands of 5" HWDP. 09:00 - 10:30 1.50 DRILL P SURF M 1 U and Stood back in Derrick 5 Stands of 5" Drill Pipe and 1 Stand of Flex Collars. 10:30 - 12:00 1.50 DRILL P SURF Held PJSM. M 1 U BHA #1. 12-114" HTC MX-C1 Bit, Ser# 6001617, dressed w/1x12, 1x14, 2x20 jets, 8" SperryDrill Lobe 6n 4.0 stg Motor, Float Sub, 12" Undergauge Integral Blade Stabilizer, XO, Orienting Sub and Drilling Jars. Total BHA Length - 73.54'. 12:00 -13:00 1.00 DIVRTR P SURF Held PJSM. Filled Diverter and Riser, checked for Leaks, OK. Tested Surface Lines to 3,000 psi, OK. 13:00 - 14:00 1.00 EVAL P SURF Held PJSM. R 1 U Schlumberger Equipment fl Gyro Runs. 14:00 - 00:00 10.00 DRILL P SURF Held PJSM. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 120' to 500'. WOB 5,000# -10,000#, RPM 60, Motor RPM 68, Torque Off Bottom 2,000 ft Ilbs, Torque On Bottom 2,000 ft Ilbs, Pump Rate 450 gpm, SPP Off Bottom 450 psi, On Bottom 550 psi. Took GyroData Surveys every 90'. ART = 1.67 hrs, AST = 4.18 hrs. Krevs = 29. 7/23/2002 00:00 - 01 :30 1.50 DRILL P SURF Held PJSM. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 500' to 585'. WOB 5,000# - 8,000#, RPM 60, Motor RPM 68, Torque Off Bottom 2,000 ft Ilbs, Torque On Bottom 2,000 ft Ilbs, Pump Rate 450 gpm, SPP Off Bottom 580 psi, On Bottom 690 psi. String Weight Up 72,000#, String Weight Down 72,000#, String Weight Rotating 72,000#. Took GyroData Survey at 585'. 01 :30 - 02:00 0.50 DRILL P SURF Circulated Bottoms Up, Pump Rate 450 gpm, 575 psi. POOH from 585' to Surface. 02:00 - 03:00 1.00 DRILL P SURF M 1 U MWD Tools to BHA #1. 03:00 - 03:30 0.50 DRILL P SURF RIH to 585'. No Fill. 03:30 - 10:00 6.50 DRILL P SURF Directionally drill f/585' to 958'. WOB 5 K - 1 K, RPM 60, Motor RPM 68, TO: Off Btm 2 K, On Btm 2 K, Pump Rate 500 gpm, SPP Off Btm 1,100 psi, On Btm 1,250 psi. 10:00-11:00 1.00 DRILL P SURF Circulate. Pump up survey. Problem with detection. 11 :00 - 11 :30 0.50 DRILL P SURF RD Schlumberger. POOH to 770'. 11 :30 - 14:00 2.50 DRILL P SURF Change out Saver Sub to 4" HT 38. 14:00 - 00:00 10.00 DRILL P SURF Directionally drill f/958' -1800'. WOB: 35 K, RPM: 75, TO: 5 K on btm, 2 K off btm. Pump rate 570 gpm, SPP: 2200 on btm, 2100 off btm. ART:8.35 hr, AST: 3.86 hr, ADT: 12.21 hr. 7/24/2002 00:00 - 03:00 3.00 DRILL P SURF Directionally drill f/1800' - 2111'. WOB:15 -30, RPM: 60, TO: 5 K on btm, 2 K off btm. 150 SPM, 3300 psi on btm. 03:00 - 03:30 0.50 DRILL P SURF Circulate bottoms up. 650 GPM, 60 RPM, 3200 PSI. 03:30 - 06:00 2.50 DRILL P SURF Wiper trip to 771'. Backream through tight hole @ 1720'- 1630'. Pulling 25 K over string weight. TIH wash through same spot. Minimal fill on bottom. 06:00 - 13:00 7.00 DRILL P SURF Directionally drill fl 2111' - 2878'. Printed: 8/12/2002 2:42:59 PM ( Page 2 af9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: 817/2002 Rig Number: Spud Date: 7/22/2002 End: 81712002 7124/2002 13:00 - 13:30 0.50 DRill N RREP SURF Trouble shoot generator problem. (Having heating problems) 13:30 - 14:30 1.00 DRill P SURF Directionally drill f/2878' - 2925'. TD hole section. WOB:15- 20 K RPM:60, TO: 5 K on btm, 2 K off btm. 152 SPM, 3100 psi on btm. (AST: 2.84 hr, ART: 5.09 hr, ADT: 7.93 hr. since last report.) 14:30 - 15:30 1.00 DRill P SURF Circulate bottoms up. 650 GPM, 60 RPM, 3200 PSI. 15:30 - 17:00 1.50 DRill P SURF Wiper trip to 1550'. Work 15-25 K overpull from 1,720 to 1,600 with intermittent swabbing. No adverse hole conditions or fill on trip in hole. No pumping or reaming required while wiping overpull sections. 17:00 -18:00 1.00 DRill P SURF Circulate and clean hole with sweeps. 154 SPM, 3100 PSI. 18:00 - 19:00 1.00 DRill P SURF POOH for 9 5/8" casing. SlM with no corrections. No adverse hole conditions on trip out to run casing. 19:00 - 20:00 1.00 DRill P SURF Rack back HWDP & Jars. 20:00 - 21 :00 1.00 DRIll P SURF lD BHA #1. Break and grade bit: 6 4 FC A E 2 WT TD 21 :00 - 23:30 2.50 CASE P SURF Clear rig floor of all vendors excess equipment. RU for 9 5/8" casing. 23:30 - 00:00 0.50 CASE P SURF PJSM. MU shoe track and baker-Iok. 7/25/2002 00:00 - 03:00 3.00 CASE P SURF TIH w/9 5/8" casing to 1929'. 03:00 - 03:30 0.50 CASE P SURF Circulate bottoms up @ 71 SPM, 480 PSI while reciprocating pipe. 03:30 - 04:00 0.50 CASE P SURF Continue TIH with 9 5/8", 40 #/ft, l-80, BTC casing. Total of 70 jts casing, float shoe, float collar, TAM collar, & 27 bow spring centrilizers. 04:00 - 04:30 0.50 CASE P SURF M I U casing hanger and landing jt. land hanger. Circulate and condition mud @ 80 SPM 450 PSI with fill-up tool. 04:30 - 05:00 0.50 CASE P SURF lID fill-up tool. M I U cement head. 05:00 - 07:00 2.00 CASE P SURF Circulate and condition mud prior to cement job @ 110 SPM, 500 PSI. Reciprocate pipe. PJSM. 07:00 - 09:30 2.50 CASE P SURF Cement 9 5/8" surface pipe. Pump 5 BBlS CW-1 00. Test lines to 4000 PSI. Pump 5 BBlS CW-100. Pump 75 BBlS 10.2 ppg Mud Push Xl wI dye. Drop bottom plug. Pump 400 BBlS 10.7 ppg, 4.44 ft^3 I sx (506 sxs) AS III Lite lead cement @ 8 BPM 850 PSI final pressure. Pump 44 BBlS 15.8 ppg, 1.17 ft^3/sx (210 sxs) "G" cement wI 0.3% BWOC D065 + 0.36 % BWOC D167 + 0.8 % BWOC S001 + 0.2 % BWOC D046 @ 5 BPM, 870 PSI max pressure. Displace lines with 5 BBlS water. Switch to rig pumps. Displace with 210 BBlS 9.5 ppg mud @ 9 BPM, 730 PSI max pressure. Slow pumps to 3 BPM prior to bumping plug. Bump plug to 1500 PSI. Bleed pressure. Floats holding. 20 BBlS cement in returns. 09:30 - 10:30 1.00 CASE P SURF RID cement head, landing jt, and casing tools. 10:30 - 11 :00 0.50 CASE P SURF M I U stack washer and flush diverter stack. 11 :00 - 13:30 2.50 CASE P SURF N I D diverterstack. 13:30 - 00:00 10.50 CASE N SFAl SURF Found the 5 degree metal (primary) seal face on the 9 5/8" mandrel casing hanger had been damaged during the casing I cementing operations. The seal area had 2 good sized scrapes and was slightly out of round. Heat up mandrel casing hanger seal area and pound into shape. Buff out damaged area. Set well head on casing hanger. N I U tubing spool and BOP stack. Set stack weight on hanger to energize seal. Pressure test failed. Set back tubing spool and BOP stack. Pull well head. Made two attempts to weld, buff. and Printed: 8/12/2002 2:42:59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: 817/2002 Rig Number: Spud Date: 7/22/2002 End: 817/2002 7125/2002 13:30 - 00:00 10.50 CASE N SFAL SURF test damaged area with out success. P I U casing elevators and long bails. P I U landing joint and M I U to casing hanger. P I U 180 K. Cut out 12" section of 20" conductor below the landing ring. 7/26/2002 00:00 - 08:30 8.S0 CASE N SFAL SURF Weld 20" landing ring. Set contingency slips. Cut mandrel casing hanger from 9 S/8" casing. Dress 9 S/8" stub. Install transition bell nipple. Pre heat with "Hot Head" per FMC specs and weld outside and inside. Wrap with insulation and allow head to cool down. 08:30 - 09:00 O.SO CASE P SURF LID 5 stands 5" DP from derrick while head cooling. 09:00 - 11 :00 2.00 CASE P SURF P I U 42 jts 4" DP from pipe barn and rack in Derrick. 11 :00 - 13:00 2.00 CASE N SFAL SURF Test transition bell nipple to 800 psi @ 300 deg F. Allow to cool to 1S0 deg F. 13:00 - 17:00 4.00 CASE P SURF Install speed head and test to 1000 psi 110 min. PJSM. N I U BOP stack. 17:00 - 23:30 6.S0 CASE P SURF Install test plug in head. R I U test equipment. Inspect lock downs. Test BOPE. Test Annular to 2S0 psi low 15 min, 2500 psi high I 5 min. Test all choke manifold, floor valves, stand pipe manifold, & stack valves to 250 psi low I 5 min, 3500 psi high I 5 min. Test witnessed by Chuck Scheve, AOGCC. Pull test plug. Install wear bushing. RID test equipment. Blowdown choke lines. M I U bell guide on top drive. 23:30 - 00:00 O.SO DRILL P INT1 P I U BHA #3 and 8 3/4" bit. 7/27/2002 00:00 - 02:30 2.S0 DRILL P INT1 Continue P I U BHA #3. Load MWD data. Surface test MWD I Mud Motor. 02:30 - 04:00 1.S0 DRILL P INT1 TIH picking up 4" DP from pipe shed. Rotate through TAM collar @ 986'. Test casing to 1000 psi to verify TAM closed. Continue TIH. Tag TOC @ 2824'. 04:00 - 04:30 O.SO DRILL P INT1 Drill cement to top of float collar @ 2839'. 04:30 - OS:OO O.SO DRILL P INT1 Circulate and conditon mud one round. OS:OO - 05:30 O.SO DRILL P INT1 Test 9 5/8" casing to 3500 psi for 30 min. OS:30 - 08:00 2.50 DRILL P INT1 Slip drill line and spool new line on drum. 08:00 - 09:00 1.00 DRILL P INT1 Perform DS Well kill drill. Drill float collar, shoe track, and float shoe. Wash I Ream old hole to TD @ 292S'. Drill 20' new formation to 294S'. 09:00 - 09:30 O.SO DRILL P INT1 Circulate and condition mud for LOT. Establish base line ECD @ 9.4 ppg. 09:30 - 10:00 0.50 DRILL P INT1 Pull into casing shoe and perform LOT. MW: 9.3 ppg, TVD: 2878', Leak off pressure: 1080 psi, EMW: 16.S2 ppg. 10:00 - 20:00 10.00 DRILL P INT1 Directionally drill fl 2945' - 4925'. Pump sweeps as required. WOB: 10-15 K, ROT: 100 rpm, SPM: 144, Pmp Press: 3430 psi, ECD: 11.0 ppg. 20:00 - 21 :00 1.00 DRILL P INT1 Circulate bottoms up for wiper trip. Get SPR. 21 :00 - 23:00 2.00 DRILL P INT1 Wiper trip to casing shoe @ 2915'. Hole in good conditon with a few tight spot but no backreaming. Max pull 30 Kover. TIH slick. 23:00 - 00:00 1.00 DRILL P INT1 Directionally drill f/4925' - S020'. wos: S - 12 K, ROT: 100 rpm, SPM: 144 , Pmp Press: 3430 psi. AST: hr, ART: hr, ADT: hr, ECD: 11.04. 7/28/2002 00:00 - 20:30 20.S0 DRILL P INT1 Directionally Drill f/5020' - 6822'. RPM: 0 - 70, wos: 5 - 12 K, SPM: 140, Pmp Press: 4000 psi. 20:30 - 21 :00 0.50 DRILL P INT1 Circulate bottoms up for cuttings sample per geology. 21:00 - 21:15 0.2S DRILL P INT1 Directionally Drill f/6822' - 6834'. AST: 10.04 hr, ART: 7.32 hr, Printed: 811212002 2:42:59 PM (' ( BPEXPLORA TfON . " - OperatiC)n,~ummary Report Page4 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: 8n 12002 Rig Number: Spud Date: 7/22/2002 End: 8/7/2002 Frorn..To HoUfs"'. .'Task Code 'NPTPhâse 7/28/2002 21:00 - 21:15 0.25 DRILL P INT1 ADT: 17.36 hr. 21 :15 - 22:30 1.25 DRILL P INT1 Circulate bottoms up for cuttings sample per geology. Call TO hole section @ 6834'. Base of HRZ +1- 6825'. 22:30 - 00:00 1.50 DRILL P INT1 Flow check. Wiper trip to 4711'. Tight @ 4890' - 4809'. Wipe out tight spot without rotating or circulating. TIH to 636S'. 7/29/2002 00:00 - 00:30 0.50 DRILL P INT1 Continue TIH (wiper trip). Hole Slick. 00:30 - 02:00 1.50 DRILL P INT1 Circulate sweep around and condition mud. Spot 100 bbl E-Z glide casing pill on bottom. 02:00 - 03:00 1.00 DRILL P INT1 POOH to 5500'. SLM. 03:00 - 03:30 0.50 DRILL P INT1 Spot 200 bbl "Steel Seal" casing pill fl 5500' - 2925'. 03:30 - 06:00 2.50 DRILL P INT1 POOH to BHA. SLM, no correction. 06:00 - 08:00 2.00 DRILL P INT1 LID BHA #3. 08:00 - 10:00 2.00 CASE P INT1 Change out top pipe rams to 41/2" x 7" for casing run. Test bonnet to 1000 psi. RU casing equipment. 10:00 - 11 :00 1.00 CASE P INT1 PJSM. M I U shoe track. Check floats. 11 :00 - 20:00 9.00 CASE P INT1 TIH with 7", 26#/ft, L-8-, BTC-Mod casing. Total 168 jts casing, 1 pup jt, float collar, & float shoe. Circulate bottoms up at the 9 5/8" casing shoe (2925'). Break circulation every 15 jts. Circulate down @ 5 bpm, 2 min per joint from 4200' - 4600' & 5500' - 5900'. M I U casing hanger and landing jt. 20:00 - 20:30 0.50 CASE P INT1 Circulate bottoms up & condition mud while reciprocating casing. 60 spm, 530 psi. 20:30 - 21 :00 0.50 CASE P INT1 N I D casing fill-up tool. N I U cement head. 21 :00 - 23:30 2.50 CASE P INT1 Circulate and condition mud prior to cement job. YP = 15. 60 spm, 530 psi. PU = 220 K, SO = 165 K. Batch mix tail cement while circulating. 23:30 - 00:00 0.50 CASE P INT1 Cement 7" casing. Pump 5 bbls CW-100. Test lines to 3500 psi. Pump 35 bbls CW - 100 @ 5 bpm 650 psi. Pump SO bbls 11.0 ppg Mud Push XL @ 5 bpm, 673 psi. Drop bottom plug. Pump 93 bbls (217 sxs) 12.0 ppg LiteCRETE lead cement. Yield = 2.39 ft^3/sx. Pump 38 bbls (184 sxs) 15.8 ppg tail cement. Yield = 1.16 ft^3/sx with 0.45 %BWOC 0167 + 0.30 %BWOC 0065 + 0.10 %BWOC 0800 +0.20 %BWOC D046. Drop top plug. Displace with 5 bbls water. Initial pump pressure = 1186 psi @ 5.7 bpm. Final pump pressure = 776 psi @ 5.7 bpm. 7/30/2002 00:00 - 01 :00 1.00 CEMT P INT1 Finish pumping cement. Displace with 5 bbls water. Switch to rig pumps. Continue displacement with 252 bbls, 10.3 ppg mud @ 7 bpm, max pressure 1S00 psi. Slow pumps to 3 bpm prior to bumping plug to 2100 psi. 01 :00 - 01 :30 0.50 CEMT P INT1 Bleed pressure. Check floats. N I D cement head. Back out landing joint & LID. 01 :30 - 02:30 1.00 CEMT P INT1 PI U pack off and setting tool. Set 7" x 9 5/8" pack off. Test pack off to SOOO psi 110 minutes. 02:30 - 03:30 1.00 CEMT P INT1 Change out upper pipe rams to 2 7/8" x 5". RID casing tools. 03:30 - 07:30 4.00 CEMT P INT1 Install test plug. R I U test string. Test BOP stack, Choke manifold, Standpipe manifold, and related floor valves to 250 psi low 15 min, 3500 psi high I 5 min. Test annular to 250 psi low I 5 min & 2500 psi high I 5 min. AOGCC Chuck Sheave waived witnessing test. 07:30 - 08:00 O.SO CEMT P INT1 Pull test plug and RID test equipment. Set wear bushing. R I U floor for BHA. 08:00 - 11 :00 3.00 DRILL P PROD1 M I U BHA #4. Load MWD data and RA source. Printed: 8/12/2002 2:42:59 PM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: an 12002 Rig Number: Spud Date: 7/22/2002 End: an/2002 7/30/2002 11 :00 - 11 :30 0.50 DRILL P PROD1 Surface test MWD & Mud motor. 11 :30 - 12:00 0.50 DRILL P PROD1 TIH w/ BHA #4 picking up 4" DP from pipe shed. 12:00 - 12:30 0.50 DRILL P PROD1 Service Rig. 12:30 - 13:30 1.00 DRILL P PROD1 TIH picking up 4" DP from pipe shed. PU total 66 jts. 13:30 - 16:00 2.50 DRILL P PROD1 Continue TIH with 4" DP stands from derrick. 16:00 - 17:00 1.00 DRILL P PROD1 Cut and slip drill line. 17:00 - 18:00 1.00 DRILL P PROD1 R / U & Test 7" casing to 3500 psi for 30 min. 18:00 - 19:00 1.00 DRILL P PROD1 Drill float collar & shoe track. 19:00 - 21 :30 2.50 DRILL P PROD1 Pump 2 spacers (total 55 bbls) ahead of new 9.8 ppg Baridril Mud. SPR's for pump 1 & 2. Clean old hole and drill 30 ' new formation after new mud around bit. Circulate bottom up. 21 :30 - 22:00 0.50 DRILL P PROD 1 Pull into casing shoe and perform FIT. 9.8 ppg MW, 6667' TVD, 770 psi, 12.0 ppg EMW. 22:00 - 00:00 2.00 DRILL P PROD1 Dircectionally drill f/6864' - 6904'. WOB: 7 - 10 K, RPM: 80, SPM: 60, Pmp Pressure: 2230 psi off btm, 2450 psi on bottom, TQ: 3.5 K off bottom, 5 K on bottom. AST: 1.21 hr, ART: 1.03 hr, ADT:2.24 hr. 7/31/2002 00:00 - 17:30 17.50 DRILL P PROD1 Directionally Drill f/6904' -7683'. WOB: 6 - 8 K, RPM: 60, SPM: 60, Pmp Press: 2400 psi on btm, 1920 psi off btm, TO: 5 K off btm, 6 K on btm. ECD: 11.3 ppg. 17:30 - 19:30 2.00 DRILL P PROD1 Re-Log interval f/ 7550' - 7683' @ 100 fph due to poor log quality while drilling. 19:30 - 21 :30 2.00 DRILL P PROD1 Directionally Drill f/ 7683' - 7855'. 21 :30 - 22:30 1.00 DRILL P PROD1 Re-Iog interval 7685' - 7784' due to poor and/or intermittent log data. 22:30 - 00:00 1.50 DRILL P PROD1 Directionally Drill f/7855' - 7913'. WOB: 6 - 8 K, RPM: 60, SPM: 60, Pmp Press: 2460 psi on btm, 2240 psi off btm, TO: 5 K off btm, 6 K on btm. ECD: 11.4 ppg. AST: 9.53 hr, ART: 3.89 hr, ADT: 13.42 hr. 8/1/2002 00:00 - 13:30 13.50 DRILL P PROD1 Directionally Drill f/7913' - 8642'. TD well. RPM: 80, WOB: 10-12 K, SPM: 60, GPM: 250, Pmp press: 2590 off bottom, 2820 psi on bottom, TO: 5 K off bottom, 5.5 K on bottom. ECD: 11.4 ppg. AST: 3.49 hr, ART: 5.3 hr, ADT: 8.79 hr. 13:30 - 15:00 1.50 DRILL P PROD1 Circulate sweep around. Flow check. 15:00 -16:30 1.50 DRILL P PROD1 Wiper trip to 7" casing shoe @ 6825'. Tight spots f/7520'- 7400' on trip out. Slick on trip in. 16:30 - 18:00 1.50 DRILL P PROD1 Circulate sweep around. Spot liner pill 120 bbls new mud on bottom. 18:00 - 22:30 4.50 DRILL P PROD1 Flow check. POOH to BHA. SLM DP. 22:30 - 00:00 1.50 DRILL P PROD1 Remove RA source. L / D BHA #4. 8/2/2002 00:00 - 00:30 0.50 DRILL P PROD1 Finish L / D BHA #4. 00:30 - 01 :30 1.00 CASE P PROD1 L / D handling tools. R / U 4.5" liner equipment. 01 :30 - 03:30 2.00 CASE P PROD1 Run 4.5" "Bonzai" liner: Guide shoe, 22 jts slotted liner, Payzone ECP, HMCV cementer, 15 Jts solid liner, Marker jt (w/ RA tag), 3 jts solid liner. 03:30 - 04:00 0.50 CASE P PROD1 R / U for 278" FOX inner string. 04:00 - 05:30 1.50 CASE P PROD1 Run 2.875" FOX inner string with "Bonzai" liner tools. 05:30 - 06:30 1.00 CASE P PROD1 M / U HMC liner hanger & ZXP packer to inner string and liner. Circulate @ 2 bpm, 180 psi. 06:30 - 09:30 3.00 CASE P PROD1 TIH with 4.5" liner on 4" DP to 7" casing shoe @ 6825'. 09:30 -10:00 0.50 CASE P PROD1 Circulate 30 bbls @ 2 bpm, 490 psi. 10:00 - 11 :00 1.00 CASE P PROD1 Continue TIH w/ 4.5" liner to 8535'. R / U cementing equipment. liner wt = 22 K, Work String wt = 7 K. PU at 7" Printed: 8/1212002 2:42:59 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: an 12002 Rig Number: Spud Date: 7/22/2002 End: an/2002 8/2/2002 10:00 - 11 :00 1.00 CASE P PROD1 shoe = 140 K, SO = 160 K. 11 :00 - 11 :30 0.50 CASE P PROD1 Circulate and conditon mud @ 2 bpm, 520 psi. PJSM. 11:30 -15:00 3.50 CASE P PROD1 Test lines to 5000 psi. Drop 2 stage pump down plug & displace to catcher sub. Pressure to 1600 psi to shear inner string plug. Displace plug to bottom of cup tool (RPC). Pressure up to 1500 psi to set Liner hanger. Hold pressure 5 min. Bleed pressure. Set wt down on liner hanger. Release running tool. Took several attempts to release running tool. Set down wt f/ 25 K - 60 K with 0 - 2900 psi & Pick up weights of 175 K -180 K (string PU = 167 K, SO = 123 K). Pick up and close PPIT and ZXP setting dogs out. Position cup seals in blank pipe and test to 1000 psi. PU to ECP indicator sub. Inflate ECP packer with 1500 psi, 0.1 bbl mud. PU to HMCV indicator. Pressure up to 1300 psi for 2 min to release closing sleeve safety in HMCV. Increase presssure to 2150 psi to open HMCV. Saw pressure drop when HMCV opened. Shut down. Attempted to pump more mud and string pressured up to 2300 psi, 2900 psi & 3000 psi. Appeared HMCV valve closed. Reposition cups & attempt to open HMCV again failed. 15:00 - 19:00 4.00 CASE P PROD1 POOH to 7495'. Flow check. Break circulation @ 2 bpm, 520 psi. Continue POOH to liner running tool and 2 7/8" inner string. 19:00 - 20:00 1.00 CASE P PROD1 L / D hanger running tool. R / U for 2 7/8" inner string. 20:00 - 21 :00 1.00 CASE P PROD1 POOH laying down 2 7/8" inner string and "Bonzai" tools. 21 :00 - 23:00 2.00 EVAL P PROD1 Install shooting flange. R / U Schlumberger Electric line. 23:00 - 00:00 1.00 EVAL P PROD1 RIH with USIT logging tools. 8/3/2002 00:00 - 02:30 2.50 EVAL P PROD1 Run USIT log from 6690' - 6825'. POOH. R / D logging tools and shooting nipple. 02:30 - 07:30 5.00 CASE N DFAL PROD1 M / U EZSV cement retainer on 2 7/8" PAC DP. BHA 941.94': EZSV, Running tool, 30 jts 2 7/8" PAC DP, xIo, circulating sub, xIo. TIH. & set @ 7587'. P / U with no overpull. Set down weight 10 K. Go thru setting procedure. P / U with no over pull again. Set down weight 25 K. Determined EZSV released without shearing normal 30 K over pull. 07:30 - 08:30 1.00 CASE N DFAL PROD1 Slip and cut drill line. 08:30 - 11 :00 2.50 CASE N DFAL PROD1 POOH. 11 :00 - 12:00 1.00 CASE N DFAL PROD1 L / D EZSV running tools. 12:00 - 20:00 8.00 CASE N DFAL PROD1 PJSM. M / U TCP guns. 4 SPF, 60 deg phased, total 12 shots for 3' interval. BHA 961.66': TCP, DCI, FH, xIo, 30 jts 2 7/8" PAC DP. xIo, circulating sub, & xIo. TIH to 7488'. Pressure up to activate FH to 2500 psi, bleed pressure wait 8 minutes for gun to fire. No positive indication. Pressure up to 2800 psi, bleed pressure, wait 8 min for gun to fire. No positive indication. Assume guns fired. Top shot @ 7485 ft 20:00 - 00:00 4.00 CASE N DFAL PROD1 POOH. L / D 5 jts 2 7/8" PAC DP. All shots fired. R / D TCP tools. 8/4/2002 00:00 - 03:00 3.00 CEMT N DFAL PROD1 M /U Fas Drill cement retainer and running tool. 03:00 - 04:00 1.00 CEMT N DFAL PROD1 TIH. Fas Drill prematurely set @ 7137' as TIH (planned depth @ 7445'). Set down 25 K, pull 20 K over to verify tool set. Pull 35 K over to shear from running tool. R / U for cementing. 04:00 - 06:00 2.00 CEMT N DFAL PROD1 Sting out of Fas Drill and establish circulation rate @ 4 bpm, 1150 psi. Sting into cement retainer and establish circulation through perforations in 4.5" liner @ 7488', 1bpm, 1450 spi. Printed: 8/1212002 2:42:59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: an /2002 Rig Number: Spud Date: 7/22/2002 End: anl2002 8/4/2002 04:00 - 06:00 2.00 CEMT N DFAL PROD1 Circulating @ 2 bpm, 950 psi prior to cement job. Batch mudpush and cement. 06:00 - 08:30 2.50 CEMT N DFAL PROD1 Pump 4.5" liner cement. Pump 5 bbls CW-1 00. Test lines to 3500 psi. Pump 25 bbls CW-100 @ 2 bpm 1140 psi. Pump 25 bbls 11.0 ppg Mudpush XL @ 2 bpm, 1015 psi. Pump 28 bbls (137 sxs) 15.8 ppg, "G" cement. 1.17 ft^3/sx yeild w/O.04% BWOC DOS5 + 0.02% BWOC B115 + 2 gal/ sx D600G + 0.2 gallsx D047. 2 bpm, 980 psi. Displace with 65.7 bbls 9.9 ppg mud @ 1 - 3 bpm, Final pumping pressure:;: 2495 psi. POO retainer. Circulate 20 bbls with Dowell. Drop circulating sub dart. Switch to rig pumps and circulate out excess. 50 bbls contaminated mud. 08:30 - 11 :00 2.50 CEMT N DFAL PROD1 Flow check. POOH. 11 :00 - 11 :30 0.50 CASE N DFAL PROD1 L / D Fas drill running tool. P / U ZXP packer and running / setting tool. 11 :30 - 15:30 4.00 CASE N DFAL PROD1 TIH w/ ZXP packer / setting tool to top of liner top ZXP packer. Set existing ZXP packer. Test to 2500 psi /10 min. 15:30 - 16:00 0.50 CASE N DFAL PROD1 POOH to 5000'. 16:00 - 16:30 0.50 CASE N DFAL PROD 1 Service Rig and Top Drive. 16:30 - 18:00 1.50 CASE N DFAL PROD1 Finish POOH. 18:00 - 18:30 0.50 CASE N DFAL PROD1 L / D ZXP packer and setting tool. 18:30 - 19:00 0.50 CASE N DFAL PROD1 R / U for 27/8" PAC DP. 19:00 - 19:30 0.50 CASE N DFAL PROD1 P / U drilling BHA 1911.84': 5 bladed junk mill bit, 3.125" mud mtr, float sub, 60 jts 2.875" PAC DP, xIo, 4.75" jars, circulating sub, & xIo. 19:30 - 23:00 3.50 CASE N DFAL PROD1 TIH w/ 8 stds of 2.875" PAC DP from derrick, P / U 36 jts 2.875" PAC DP from pipe shed, and 4" DP from derrick to 7110'. Tag TOC. 23:00 - 00:00 1.00 CASE N DFAL PROD1 Break circulation. Wash down to hard cement @ 7130'. Drill cement to top of Fas Drill cement reatainer @ 7137'. Drill retainer and cement to 7182'. SPM: 40 (4 bpm), Pmp Press: 2440 psi off, 2710 psi on bottom, TO: 3 on, 3 off bottom, ROT: 40 rpm, WOB: 8 -15 K, ROP: 60 - 90 fph. PU wt:;: 167 K, SO wt:;: 125 K, ROTwt:;: 137 K. 8/5/2002 00:00 - 04:00 4.00 CASE N DFAL PROD1 Drill cement f/7182' - 7500'. Wash down to top of EZSV @ 7587'. Drill EZSV and push to bottom @ 8534'. SPM: 40 (4 bpm), Pmp Press: 2440 psi off, 2710 psi on bottom, TO: 3 on, 3 off bottom, ROT: 40 rpm, WOB: 8 - 15 K, ROP: 60 - 90 fph. PU wt:;: 167 K, SO wt:;: 125 K, ROT wt:;: 137 K. 04:00 - 07:00 3.00 CASE P PROD1 Circulate sweep around. Drop dart and open circulating sub @ 6622'. Pump Hi /Iow sweeps around and displace with 10 ppg brine. 07:00 - 08:00 1.00 CASE P PROD1 Cut and slip drill line. Service Top Drive. 08:00 - 15:00 7.00 CASE P PROD1 POOH L / D DP & BHA. LID handling equipment and service tools. 15:00 - 17:00 2.00 RUNCOI\tP COMP Pull wear bushing. R / U Tubing handling equipment. Change out bails. R / U TO turn equipment. Function Blinds. 17:00 - 17:30 0.50 RUNCOf\P COMP PJSM. Go over running order and jewelry. 17:30 - 00:00 6.50 RUNCOf\P COMP M / U bottom hole jewelry. Tail pipe assembly, "X" nipple assembly, PRM production packer assembly, and Sliding Sleeve assembly (SS). TO failure on SS. Back out and re TO, failed. Change out collar. Re TO ok. M / U GLM #3. TO failure. Re TO failed. Change out collar, TO failed. Galled Printed: 8/12/2002 2:42:59 PM (^ Page 8 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: 817/2002 Rig Number: Spud Date: 7122/2002 End: 81712002 815/2002 17:30 - 00:00 6.50 RUNCOf\P COMP threads on XO pup it when backing out collar. Change out XO pup it. Change pipe dope. Continue in hole with Completion string. 8/6/2002 00:00 - 10:30 10.50 RUNCOI\-P COMP Held PJSM. RIH wI a Total of 168 its 4-1/2" 12.6# L-80 TC-II Tubing. Torque Turned each Connection. M I U Torque 3,500 ft Ilbs. 10:30 - 12:00 1.50 RUNCOf\P COMP Spaced out Tubing. M I U Space out Pup Joints. M I U Tubing Hanger and Landing Joint. Landed Tubing Hanger in Wellhead, RILDS. Completion Equipment Set at the Following Depths: Item Length Depth WLEG 1.38' 6,718.30' XN Nipple Assembly 20.80' 6,696.12' X Nipple Assembly 20.89' 6,675.23' 7" x 4-1/2 PRM Packer Assembly 26.76' 6,648.47' 1 Jt 4-1/2" 12.6# TC-II L-80 Tbg 38.34' 6,610.13' Sliding Sleeve Assembly 23.68' 6,586.45' 1 Jt 4-1/2" 12.6# TC-II L-80 Tbg 40.61' 6,545.84' #1 GLM Assembly wI RP Shr Vlv 26.18' 6,520.66' 22 Jts 4-1/2" 12.6# TC-II L-80 Tbg 849.03' 5,670.63' #2 GLM Assembly 26.54' 5,644.09' 46 Jts 4-1/2" 12.6# TC-II L-80 Tbg 1,776.90' 3,867.19' #3 GLM Assembly 26.58' 3,840.61' 41 Jts 4-1/2" 12.6# TC-II L-80 Tbg 1,572.62' 2,267.99' X Nipple Assembly 20.77' 2,247.22' 56 Jts 4-1/2" 12.6# TC-II L-80 Tbg 2,152.03' 95.19' 4-1/2" 12.6# TC-II L-80 Pup Jts 23.41' 71.78' 1 Jt 4-1/2" 12.6# TC-II L-80 Tbg 40.31' 31.47' Tubing Hanger 2.41' 28.95' 12:00 - 14:30 2.50 RUNCOIVP COMP Held PJSM. R I U Circulating Equipment. Reverse Circulated Corrosion Inhibited Brine Down 7" x 4-1/2" Annulus. Pump Rate 3 bpm, 390 psi. 14:30 - 16:00 1.50 RUNCOrvP COMP Held PJSM. Dropped BallI Rod Assembly. Pressured up on Tubing to 4,200 psi to set Packer. Tested Tubing to 3,500 psi fl 30 Minutes. OK. Bled Tubing Pressure Down to 1,500 psi. Pressure Tested IA to 3,500 psi fl 30 Minutes, OK. Bled Down Tubing Pressure Sheared RP Valve. Bled Down All Pressure. 16:00 -16:30 0.50 RUNCOIVP COMP Set TWC in Tubing Hanger Profile. Tested TWC from Below to 3,000 psi. 16:30 - 17:30 1.00 RUNCOIVP COMP Cleaned and Cleared Rig Floor. 17:30 - 19:00 1.50 BOPSUR P COMP Held PJSM. N I D BOPE. 19:00 - 20:30 1.50 WHSUR P COMP Held PJSM. N I U Adapter Flange and Production Tree. FMC Tested Adapter Flange to 5,000 psi f/10 minutes. R I U and Tested Tree to 5,000 psi, OK. 20:30 - 21 :00 0.50 WHSUR P COMP Held PJSM. R I U DSM Lubricator, Pulled TWC. RID DSM 21 :00 - 00:00 3.00 WHSUR P COMP Held PJSM. R I U Little Red Hot Oil. Tested Lines to 3,000 psi, OK. Pumped 136 bbls of Diesel Down 7" x 4-1/2" Annulus to Freeze Protect. Pump Rate 1.7 bpm, 2,100 psi. 81712002 00:00 - 03:30 3.50 WHSUR, P COMP Held PJSM. U-Tubed Diesel between IA and 4-1/2" Tubing. 400 psi on Wellhead due to Hydrostatic Underbalance. 03:30 - 06:00 2.50 WHSUR P COMP Held PJSM. R I U DSM Lubricator, Set BPV, Bled down Lubricator, Shut in Master Valve. RID DSM. 06:00 - 07:00 1.00 WHSUR P COMP Removed 2nd Annulus Valve, Installed Tree Cap & Gauges. Installed Blind Flange on Annulus Valve. Secured Well. Printed: 8/1212002 2:42:59 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-112i S-112i DRILL +COMPLETE DOYON DOYON 14 Start: 7/22/2002 Rig Release: an 12002 Rig Number: Spud Date: 7/22/2002 End: an/2002 817/2002 06:00 - 07:00 1.00 WHSUR P COMP Released Rig @ 07:00 Hrs, 08 / 07 /2002. Printed: 6/12/2002 2:42:59 PM aCB-J3S 27 -Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-112 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD (if applicable) 'MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED AUachment(s) AUG 27 2002 Alaska Oif & Gas Cons Comm' , Anchorag~ '8SJOn North Slope Alaska BPXA PBU_WOA S Pad, Slot S-112 S-112 Gyro Surveyed: 1 August, 2002 () ~~~ rl/~ ~ SURVEY REPORT 14 August, 2002 Your Ref: API 500292309900 Surface Coordinates: 5980535.15 N, 618929.92 E (700 21' 19.7044" N, 149002' 02.9673" W) Kelly Bushing: 69. 60ft above Mean Sea Level 1111 ',.-,r--raY-Sul1 0 A I LL IN GS & AV' c: e s A Halliburton Company Survey Ref: svy11269 Sperry-Sun Drilling Services Survey Report for S-112 Gyro Your Ref: API 500292309900 Surveyed: 1 August, 2002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) ì......... 0.00 0.000 0.000 -69.60 0.00 100.00 0.420 133.760 30.40 100.00 178.00 0.500 185.860 108.40 178.00 269.00 0.880 136.220 199.39 268.99 360.00 1.560 121.950 290.37 359.97 451.00 3.430 88.4 70 381.28 450.88 537.00 5.350 77.180 467.03 536.63 596,00 7,250 76.450 525.67 595.27 688,00 7.970 73.970 616.86 686.46 Local Coordinates Northlngs Eastings (ft) (ft) Global Coordinates Northlngs Eastings (ft) (ft) 0.00 N 0.00 E 5980535.15 N 0.258 0.26E 5980534;90 N 0.798 0.44 E 5980534.37 N 1.698 0.88E 5980533.47 N 2.858 2.41 E 5980532.34 N 3.43 8 6.19 E 5980531.82 N 2.47 8 12.67 E 5980532.88 N 0.99 S 18.97 E 5980534.46 N 2.13 N 30.74 E 5980537.77 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-112. Northings and Eastings are relative to 8-112. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from S-112 and calculated along an Azimuth of 73.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 688.00ft., The Bottom Hole Displacement is 30.82ft., in the Direction of 86.036° (True). Survey tool program for 5-112 Gyro From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 688.00 686.46 AK-1 BP _HG ------~ 14 August, 2002 - 15:14 Page 2 0'2 618929.92 E 618930.19 E 618930.37 E 618930.83 E 618932.38 E 618936.16 E 618942.63 E 618948.90 E 618960.63 E . ~~ BPXA <.~~ PBU_WOASPad Dogleg ~~J~ent Rate sectl;¡ J (0/100ft) 0.00 AK-1 P _HG 0.420 0.18 0.526 0.19 0.741 0.36 0.813 1.50 2.523 2.438 3,223 0.860 4.95 11 .44 17.90 30,08 DrillQuest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-112 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window I Kickoff Survey Projected Survey: 'MD , M D (if applicable) 8,642.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 2 7 2002 Alaska Olf & Gas Coos. Commission Anchorage 27 -Aug-02 q íbì-J3S North Slope Alaska BPXA PBU_WOA 5 Pad, Slot 5-112 5-112 Job No. AKZZ22107, Surveyed: 1 August, 2002 () ~~~ rlì~ ~ SURVEY REPORT 14 August, 2002 Your Ref: API 500292309900 Surface Coordinates: 5980535.15 N, 618929.92 E (70021' 19.7044" N, 149002' 02.9673" W) Kelly Bushing: 69. 60ft above Mean Sea Level ~ SpII"''''Y-BUI1 OAU..LINGS&AVac:eS A Halliburton Company Survey Ref: svy11282 Sperry-Sun Drilling Services . Survey Report for S-112 Your Ref: API 500292309900 Job No. AKZZ22107, Surveyed: 1 August, 2002 () ~~ BPXA North Slope Alaska ~U_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical ~~ Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section C ~> (ft) (ft) (ft) (ft) (ft) (ft) (ft) (~100ft) , ~ ',:, 688.00 7.970 73.970 616.86 686.46 2.13 N 30.74 E 5980537.77 N 618960.63 E 30.08 AK-6 BPJFR-AK 703.68 8.410 75.830 632.38 701.98 2.71 N 32.90 E 5980538.38 N 618962.77 E 3.275 32.31 800.95 8.660 86.520 728.58 798.18 4.90 N 47.11 E 5980540.79 N 618976.94 E 1.649 46.55 899.95 10.190 96.040 826.24 895.84 4.43 N 63.26 E 5980540.58 N 618993.10 E 2.201 61.90 994.29 10.630 100.170 919.03 988.63 2.01 N 80.12 E 5980538.44 N 619010.00 E 0.918 77,38 1091.39 13.110 102.040 1014.05 1083.65 1.87 S 99.71 E 5980534.87 N 619029.65 E 2.584 95.05 1187.67 12.970 104.270 1107.85 1177.45 6.81 S 120.86 E 5980530.26 N 619050.87 E 0.542 113.92 1282.96 13.580 108.040 1200.59 1270.19 12.91 S 141.86E 5980524.50 N 619071.97 E 1.111 132.32 1379,32 13.680 108.900 1294.24 1363.84 20.10 S 163.40 E 5980517.65 N 619093.62 E 0.235 150.91 1474.06 14.040 101.600 1386.23 1455.83 26.04 S 185.26 E 5980512.05 N 619115.57 E 1.883 170,18 1570.66 13.060 99.190 1480.14 1549.74 30.14 S 207.51 E 5980508.31 N 619137.88 E 1.171 190,34 166G,91 14.240 98.000 1573.67 1643.27 33.53 S 229.97 E 5980505.28 N 619160.39 E 1.260 210.91 1762.89 13.970 99.310 1666.75 1736.35 37.04 S 253.09 E 5980502.13 N 619183.57 E 0.436 232.07 1859.16 13.820 98.470 1760.21 1829.81 40.62 S 275.93 E 5980498.92 N 619206.46 E 0.261 252.95 1954.40 12,800 97.630 1852.89 1922.49 43.69 S 297.64 E 5980496.19 N 619228.22 E 1.090 272.89 2051.24 10.690 1 00.200 1947.70 2017.30 46.71 S 317.11E 5980493.48 N 619247.74 E 2.244 290.70 2146.02 7.880 103.020 2041.23 2110.83 49.73 S 332.10 E 5980490.70 N 619262.77 E 3.002 304,20 2242.66 6.410 104.160 2137.11 2206.71 52.54 S 343.78 E 5980488.07 N 619274.50 E 1.528 314.60 2338.03 3.520 102.300 2232.11 2301.71 54.47 S 351.81 E 5980486.27 N 619282.55 E 3.035 321.75 2433.77 1.050 150.470 2327.78 2397.38 55.86 S 355.11 E 5980484.94 N 619285.88 E 3.056 324,52 2529.80 1.520 245.250 2423.79 2493.39 57.16 S 354.39 E 5980483.63 N 619285.17 E 1.997 323.45 2626.24 1.750 258.220 2520.19 2589.79 57.99 S 351.79 E 5980482.75 N 619282.58 E 0.450 320.72 2721.50 1.790 268.290 2615.41 2685.01 ~8.33 S 348.88 E 5980482.36 N 619279.68 E 0.329 317.83 2816.22 1.720 266.960 2710.08 2779.68 8.45 S 345.98 E 5980482.20 N 619276.78 E 0.085 315.02 2861.96 1.810 270.450 2755.80 2825.40 58.48 S 344.57 E 5980482.14 N 619275.38 E 0.306 313.66 2939.29 1.640 270.000 2833.10 2902.70 58.47 S 342.24 E 5980482.12 N 619273.05 E 0.221 311.43 3034.52 1.870 280.860 2928.28 2997.88 ~8.18 S 339.35 E 5980482.36 N 619270.15 E 0.424 308.75 3129.97 1.920 274.450 3023.68 3093.28 57.76 S 336.23 E 5980482.73 N 619267.02 E 0.228 305.87 3226.78 2.070 284.270 3120.43 3190.03 57.21 S 332.92 E 5980483.24 N 619263.70 E 0.385 302.86 3322.41 2.340 285.670 3215.99 3285.59 56.25 S 329.37 E 5980484.13 N 619260.14 E 0.288 299.72 - --_._.~-_._.- 14 August, 2002 - 15:13 Page 20'6 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for S-112 Your Ref: API 500292309900 D~~ Job No. A KZZ221 07, Surveyed: 1 August, .2002 ~l) BPXA North Slope Alaska I~S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical "l:: Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/1 OOft) 3416.19 0.630 267.960 3309.73 3379.33 55.76 S 327.01 E 5980484.59 N 619257.77 E 1.866 297,60 ~, 3513.77 1.410 113.250 3407.31 3476.91 56.25 S 327.57 E 5980484.11 N 619258.35 E 2.047 298.01 3608.45 1.540 113.480 3501.96 3571.56 57.21 S 329.81 E 5980483.18 N 619260.60 E 0.137 299.88 3705.74 1.110 100.970 3599.22 3668.82 57.92 S 331.93 E 5980482.51 N 619262.73 E 0.530 301 .71 3801.65 1.190 106.190 3695.11 3764.71 58.37 S 333.80 E 5980482.09 N 619264.61 E 0.137 303,37 3897.88 1.150 109.860 3791.32 3860.92 58.98 S 335.67 E 5980481.51 N 619266.49 E 0.088 304.99 3993.85 1.110 118.880 3887.27 3956.87 59.75 S 337.39 E 5980480.76 N 619268.22 E 0.190 306.42 4090.62 1.240 120.800 3984.02 4053.62 60.74 S 339.11 E 5980479.80 N 619269.95 E 0.140 307.79 4185.52 1.230 132.480 4078.90 4148.50 61.95 S 340.74 E 5980478.61 N 619271.60 E 0.265 309.01 4281.82 1.300 134.890 4175.18 4244.78 63.42 S 342.28 E 5980477.17 N 619273.16E 0.091 310.06 4377.49 0.850 141.490 4270.83 4340.43 64.74 S 343.49 E 5980475.87 N 619274.40 E 0.487 310.85 4172.49 0.960 148,610 4365.82 4435.42 65.98 S 344.34 E 5980474.65 N 619275.27 E 0.165 311.31 4568.58 0,920 164.760 4461.89 4531.49 67.41 S 344.97 E 5980473.23 N 619275.91 E 0.278 311.50 4664.86 0.510 151.940 4558.17 4627.77 68.53 S 345.37 E 5980472.11 N 619276.34 E 0.455 311.57 4761.00 0.330 19.510 4654.31 4723.91 68.65 S 345.66 E 5980472.00 N 619276.63 E 0.803 31182 4857.27 0.410 351.520 4750.57 4820.17 68.05 S 345.71 E 5980472.60 N 619276.66 E 0.203 312,03 4951.46 0.550 5.860 4844.76 4914.36 67.26 S 345.70 E 5980473.38 N 619276.65 E 0.195 312,25 5049.42 0.520 330.950 4942.72 5012.32 66.41 S 345.54 E 5980474.24 N 619276.47 E 0.329 312.33 5146.08 0,740 334.550 5039.37 5108.97 65.46 S 345.05 E 5980475.18 N 619275.97 E 0.231 312.14 5241.54 0.700 310.540 5134.82 5204.42 64.52 S 344.35 E 5980476.10 N 619275.25 E 0.316 311.73 5337.52 0.720 294.670 5230.80 5300.40 63.89 S 343.35 E 5980476.72 N 619274.24 E 0.205 31 0.96 5433.55 0.830 279.130 5326.82 5396.42 63.53 S 342.12 E 5980477.06 N 619273.00 E 0.246 309.88 5530.32 0.790 286.860 5423.58 5493.18 63.22 S 340.79 E 5980477.34 N 619271.67 E 0.120 308,69 5626.38 1.050 259.860 5519.63 5589.23 63.19 S 339.29 E 5980477.36 N 619270.17 E 0.519 307.26 5721.96 1.090 251.510 5615.19 5684.79 63.63 S 337.56 E 5980476.89 N 619268.45 E 0.168 305.48 5816.90 1.170 241.270 5710.11 5779.71 64.38 S 335.86 E 5980476.11 N 619266.76 E 0.228 303.63 5913.68 1.320 96.230 5806.88 5876.48 64.98 S 336.10 E 5980475.52 N 619267.01 E 2.454 303.69 6008.46 8.250 82.380 5901.27 5970.87 64.19 S 343.93 E 5980476.42 N 619274.83 E 7.360 311.43 6104.70 12,840 82.200 5995.86 6065.46 61.83 S 361.38 E 5980479.07 N 619292.24 E 4.769 328.83 6199.33 17.510 81.470 6087.17 6156.77 58.28 S 385.89 E 5980483.00 N 619316.69 E 4.939 353.33 14 August, 2002. 15:13 Page 3 of6 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services D . Survey Report for S-112 ~ Your Ref: API 500292309900 Job No. AKZZ22107, Surveyed: 1 August, 2002 ;¡::¡ At,..", 111/£ BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6295.78 22.990 80.970 6177.62 6247.22 53.17 S 418.87 E 5980488.63 N 619349.58 E 5.684 386.40 6389.98 27.370 80.700 6262.85 6332.45 46.78 S 458.42 E 5980495.65 N 619389.03 E 4.651 426.14 6486.73 32.500 79.240 6346.67 6416.27 38.33 S 505.94 E 5980504.86 N 619436.40 E 5.355 474.09 6583.32 38.210 80.650 6425.41 6495.01 28.62 S 560.95 E 5980515.43 N 619491.26 E 5.971 529.59 6679.24 43.400 80.310 6497.99 6567.59 18.25 S 622.75 E 5980526.79 N 619552.88 E 5.416 591.78 6765.90 47.630 82.040 6558.71 6628.31 8.80 S 683.83 E 5980537.20 N 619613.80 E 5.084 653.03 6852.27 52.580 81.730 6614.09 6683.69 0.56N 749.41 E 5980547.60 N 619679.23 E 5.738 718.56 6883,51 55.990 81.990 6632.32 6701.92 4.14 N 774.51 E 5980551.59 N 619704.27 E 10.936 743.65 6915.28 58.050 81.510 6649.61 6719.21 7.97 N 800.89 E 5980555.83 N 619730.58 E 6.607 770.02 6947.15 61 . 1 50 80.780 6665.74 6735.34 12.20 N 828.04 E 5980560.50 N 619757.67 E 9.926 797.26 6978.53 64.810 81.570 6679.99 6749.59 16.49 N 855.66 E 5980565.22 N 619785.21 E 11.877 824.95 7009,59 67,960 82.560 6692.43 6762.03 20.41 N 883.85 E 5980569.59 N 619813.33 E 10,554 853,09 7041.94 71.450 81.680 6703.65 6773.25 24.58 N 913.90 E 5980574.23 N 619843.31 E 11.086 883.08 7073.91 75.490 80.630 6712.75 6782.35 29.29 N 944.17 E 5980579.43 N 619873.51 E 13.023 913.44 7106.46 79,720 79.590 6719.73 6789.33 34.75 N 975.48 E 5980585.38 N 619904.73 E 13.365 945.01 7137.83 84.200 77.920 6724.12 6793.72 40.81 N 1005.94 E 5980591.92 N 619935.09 E 15.222 975,93 7170.06 85,070 74.570 6727.13 6796.73 48.44 N 1037.10 E 5980600.05 N 619966.12 E 10.695 1007.98 7205.66 85,810 70.690 6729.96 6799.56 59.03 N 1070.97 E 5980611.18 N 619999.81 E 11.061 1043.46 7236.12 87.780 67.540 6731.67 6801.27 69.87 N 1099.37 E 5980622.4 7 N 620028.05 E 12.183 1073.78 7269.29 90.740 65.680 6732.10 6801.70 83.04 N 1129.81 E 5980636.11 N 620058.27 E 10.539 1106.70 7300.58 92.220 61 .680 6731.29 6800.89 96.90 N 1157.84 E 5980650.42 N 620086.08 E 13.626 1137.52 7332.11 95.050 59.940 6729.29 6798.89 112.25N 1185.31 E 5980666.20 N 620113.30 E 10.530 1168.22 7362.66 95.240 59.410 6726.55 6796.15 127.61 N 1211.57 E 5980681.98 N 620139.31 E 1.836 1197.77 7412.05 95.850 57.280 6721.78 6791.38 153.41 N 1253.42 E 5980708.43 N 620180.74 E 4.467 1245.22 7457.48 95.490 58.280 6717.29 6786.89 177.51 N 1291.66 E 5980733.14 N 620218.60 E 2.329 1288.75 7508.14 91.720 59.900 6714.10 6783.70 203.47 N 1335.03 E 5980759.79 N 620261.55 E 8.097 1337.72 7555.36 95.050 62.410 6711.31 6780.91 226.21 N 1376.31 E 5980783.18 N 620302.4 7 E 8.825 1383.76 7601.25 95.170 62.290 6707.23 6776.83 247.42 N 1416.80 E 5980805.03 N 620342.61 E 0.369 1428.61 7654.86 95.050 62.310 6702.45 6772.05 272.24 N 1464.08 E 5980830.60 N 620389.49 E 0.227 1481,00 7700.49 93.140 62.970 6699.19 6768.79 293.16 N 1504.50 E 5980852.16 N 620429.57 E 4.427 1525.70 14 August, 2002 - 15:13 Page 4 0'6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services DE~/A¡/'> - . Survey Report for 5-112 Your Ref: API 500292309900 Job No. AKZZ22107, Surveyed: 1 August, 2002 . II/E:' BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7745.29 93.760 62.170 6696.50 6766.10 313.76 N 1544.19 E 5980873.38 N 620468.93 E 2.257 1569.61 7787.91 93.820 63.100 6693.68 6763.28 333.31 N 1581.95 E 5980893.53 N 620506.38 E 2.182 1611.38 7840.45 93.750 63.010 6690.21 6759.81 357.06 N 1628.69 E 5980918.02 N 620552.73 E 0.217 1662.95 7892.28 89.630 63.020 6688. 68 6758.28 380.57 N 1674.85 E 5980942.26 N 620598.51 E 7.949 1713.88 7936.65 87.290 62.870 6689.88 6759.48 400.74 N 1714.34 E 5980963.05 N 620637.69 E 5.285 1757.49 7984.95 86,980 63.150 6692.29 6761.89 422.63 N 1757.33 E 5980985.63 N 620680.32 E 0.864 1804.93 8031.91 87.170 63.680 6694.69 6764.29 443.62 N 1799.27 E 5981007.28 N 620721.92 E 1.198 1851.11 8078,70 87.420 64,070 6696.90 6766.50 464.20 N 1841.23 E 5981028.52 N 620763.55 E 0.989 1 8~7, 1 9 8129.60 90.180 61.950 6697.96 6767.56 487.29 N 1886.57 E 5981052.33 N 620808.52 E 6.837 1947.23 8177.67 93,570 61.870 6696.39 6765.99 509.91 N 1928.95 E 5981075.62 N 620850.53 E 7.054 1994.30 8226.12 94.560 61.410 6692.95 6762.55 532.87 N 1971.48 E 5981099.25 N 620892.69 E 2.252 2041.60 8;67,16 91840 62,320 6690.66 6760.26 552.19 N 2007.61 E 5981119.14 N 620928.51 E 6,O88 2081.73 8323,29 90,250 62.520 6689.64 6759.24 578.17 N 2057.35 E 5981145.91 N 620977.83 E 2.855 2136.81 8371.89 88.770 62.860 6690.06 6759.66 600.46 N 2100.53 E 5981168.89 N 621020.65 E 3.125 2184.56 8418.47 01 .4 80 62.700 6689.95 6759.55 621.77 N 2141.95E 5981190.85 N 621061.73 E 5.828 2230.32 8467.09 91,540 62.450 6688.67 6758.27 644.15 N 2185.09 E 5981213.91 N 621104.51 E 0.529 2278,05 8514,36 95.480 63.710 6685.78 6755.38 665.51 N 2227.15 E 5981235.94 N 621146.22 E 8.749 2324.45 8574,72 95.800 62.590 6679.85 6749.45 692.64 N 2280.74 E 5981263.91 N 621199.37 E 1.921 2383,55 ~, 8642,00 95.800 62.590 6673.05 6742.65 723.46 N 2340.16 E 5981295.67 N 621258.30 E 0.000 2449,28 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-112. Northings and Eastings are relative to 5-112. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 5-112 and calculated along an Azimuth of 73.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8642.00ft., The Bottom Hole Displacement is 2449.44f1., in the Direction of '72.821° (True). 14 August, 2002 - 15:13 Page 50f6 DrillQuest 2.00.08.005 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 5-112 Your Ref: API 500292309900 Job No. AKZZ22107, Surveyed: 1 August, 2002 D 'I:/YJi fJo>' BPXA ., VI r/~tBU-WOAS Pad . Comments -""'-..,.. Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) ~- Comment 8642.00 6742.65 723.46 N 2340.16 E Projected Survey Survey tool program for 5-112 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 688.00 0.00 686.46 688.00 8642.00 686.46 AK-1 BP _HG (S-112 Gyro) 6742.65 AK-6 BP _IFR-AK (S-112) ----------- 14 August, 2002 - 15:13 Page 60f6 DrillQuest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-112 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD I MD (if applicable) 8,642.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) RECEIVED AUG 2 7 2002 Alaska Oii & Gas Cons. Commission Anchorage 27 -Aug-02 ~~- IdS \~. North Slope Alaska BPXA PBU_WOA S Pad, Slot 8-112 5-112 MWD Job No. AKMW22107, Surveyed: 1 August, 2002 ,-, SURVEY REPORT 14 August, 2002 Your Ref: API 500292309900 Surface Coordinates: 5980535.15 N, 618929.92 E (70021' 19.7044" N, 149002' 02.9673" W) Kelly Bushing: 69.60ft above Mean Sea Level 51:811"""Y-IIUI1 DFULLING SERVICES A Halliburton Company Survey Ref: svy11283 Sperry-Sun Drilling Services . Survey Report for S-112 MWD Your Ref: API 500292309900 Job No. AKMW22107, Surveyed: 1 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 688.00 7.970 73.970 616.86 686.46 2.13 N 30.74 E 5980537.77 N 618960.63 E 30.08 MWD Magnetic 703.68 8.410 75.710 632.38 701.98 2.71 N 32.90 E 5980538.39 N 618962.77 E 3.220 32.31 800.95 8.660 86.100 728.58 798.18 4¡.97 N 47.10 E 5980540.86 N 618976.94 E 1.604 46.57 899.95 10.190 95.250 826.24 895.84 4.67 N 63.26 E 5980540.83 N 618993.10 E 2.159 61.97 994.29 10.630 99.990 919.03 988.63 2.40 N 80.14 E 5980538.82 N 619010.01 E 1.020 77.51 1091.39 13.110 102.300 1014.05 1083.65 1.50 S 99.72 E 5980535.23 N 619029.65 E 2.600 95.17 1187.67 12,970 104.490 1107.85 1177.45 6.53 S 120.85 E 5980530.54 N 619050.86 E 0.533 113.99 1282,96 13,580 108,230 1200.59 1270,19 12.71 S 141.83 E 5980524.70 N 619071.93 E 1.105 132,34 1 :~l') ~2 j :J;,(~() 10a,(j[)0 1294,24 1363.84 19.96 S 163.35 E 5980517.78 N 619093.56 E 0.226 150.90 1474.06 14.040 101.550 1386.23 1455:83 25.92 S 185.20 E 5980512.17 N 619115.50 E 1.933 170.15 1570,66 13,060 99.110 1480.14 1549.74 30.00 S 207.45 E 5980508.45 N 619137.82 E 1.174 190.33 1666,91 14,240 98.040 1573.67 1643.27 33.37 S 229.91 E 5980505.43 N 619160.33 E 1.254 210.90 1762,89 13,970 99.420 1666.75 1736.35 36.92 S 253.03 E 5980502.25 N 619183.51 E 0.449 232.05 1859,16 13.820 99.000 1760.21 1829.81 40.62 S 275.85 E 5980498.91 N 619206.38 E 0.188 252.87 1954.40 12,800 98.100 1852.89 1922.49 43.89 S' 297.53 E 5980495.99 N 619228.11 E 1.093 272.73 2051,24 10,690 100.380 1947.70 2017.30 47.02 S 316.99 E 5980493.17 N 619247.62 E 2.231 290,49 2146,02 7,880 102.750 2041.23 2110.83 50.04 S 331.98 E 5980490.39 N 619262.65 E 2.991 304,00 2242.66 6.410 103.850 2137.11 2206.71 52.79 S 343.68 E 5980487.82 N 619274.39 E 1.528 314.43 -, 2338.03 3.520 101.800 2232.11 2301.71 54.66 S 351.71 E 5980486.08 N 619282.46 E 3.036 321.60 2433,77 1.050 150.030 2327.78 2397.38 56.02 S 355.03 E 5980484.77 N 619285.79 E 3.057 324.39 2529.80 1.520 245.020 2423.79 2493.39 57.32 S 354.31 E 5980483.46 N 619285.10 E 2.000 323.33 2626.24 1.750 257.900 2520.19 2589.79 58.17 S 351.71 E 5980482.57 N 619282.51 E 0.448 320.60 2721.50 1.790 268.050 2615.41 2685.01 58.53 S 348.81 E 5980482.17 N 619279.61 E 0.331 317.71 2816.22 1.720 266.860 2710.08 2779.68 58.66 S 345.91 E 5980481.99 N 619276.72 E 0.083 314.90 2861.96 1.810 270.610 2755.80 2825.40 58.69 S 344.50 E 5980481.94 N 619275.31 E 0.320 313.54 2939.29 1.640 269.720 2833.10 2902.70 58.68 S 342.17 E 5980481.91 N 619272.98 E 0.223 311.31 3034.52 1.870 280.510 2928.28 2997.88 58.40 S 339.28 E 5980482.14 N 619270.09 E 0.422 308.62 3129.97 1.920 273.930 3023.68 3093.28 58.01 S 336.16 E 5980482.49 N 619266.95 E 0.234 305.73 3226.78 2.070 283.660 3120.43 3190.03 57.48 S 332.84 E 5980482.96 N 619263.63 E 0.382 302.70 3322.41 2.340 285.220 3215.99 3285.59 !>6.56 S 329.28 E 5980483.82 N 619260.05 E 0.289 299.55 14 August, 2002 - 15:17 Page 20'6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for S-112 MWD Your Ref: API 500292309900 Job No. AKMW22107, Surveyed: 1 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3416.19 0.630 267.700 3309.73 3379.33 56.08 S 326.91 E 5980484.26 N 619257.68 E 1.866 297.42 .~,~ 3513.77 1.410 112.860 3407.31 3476.91 56.57 S 327.48 E 5980483.79 N 619258.26 E 2.048 297,83 3608.45 1.540 113.230 3501.96 3571.56 57.52 S 329.73 E 5980482.87 N 619260.52 E 0.138 299.71 3705.74 1.110 100.980 3599.22 3668.82 58.22 S 331.85 E 5980482.21 N 619262.66 E 0.527 301.55 3801,65 1.190 106.430 3695.11 3764.71 58.68 S 333.72 E 5980481.78 N 619264.53 E 0.141 303.21 3897.88 1.150 110.000 3791.32 3860.92 59.29 S 335.59 E 5980481.19 N 619266.40 E 0.086 304.82 3993.85 1.110 118.530 3887.27 3956.87 60.06 S 337.31 E 5980480.45 N 619268.14 E 0.180 306.25 HV-'f)G~ 1710 170,G70 l084,O2 4053,62 61.05 S 339.03 E 5980479.49 N 619269.88 E 0,1112 :in? ,fì? tlWC,;:;2 1::;U 1 :'2,CI~¡O 407B,UO 4148,50 62.25 S 340.67 E 5980478.31 N 619271.54 E O,¿~J~) : ~(J ~ ; . ,\ -; ~) 4281.82 1.300 134.680 4175.18 4244.78 63.71 S 342.21 E 5980476.88 N 619273.10 E 0.094 309.92 4377.49 O,8S0 141.510 4270.83 4340.43 65.03 S 343.43 E 5980475.58 N 619274.34 E 0.488 310,70 4472.49 OP'30 148,850 4365,82 4435.42 66.27 S 344.28 E 5980474.36 N 619275.21 E 0.168 311,17 4568.58 0,920 165.070 4461.89 4531.49 67.70 S 344.89 E 5980472.93 N 619275.84 E 0.279 311.35 4664.86 0,510 152.260 4558.17 4627.77 68.83 S 345.29 E 5980471.81 N 619276.26 E 0.454 311.41 4761.00 0,330 19.490 4654.31 4723.91 68.94 S 345.58 E 5980471.70 N 619276.55 E 0.804 311.66 4857.27 0.410 351.640 4750.57 4820.17 68.34 S 345.63 E 5980472.30 N 619276.59 E 0.202 311.87 4951.46 0.550 6.030 4844.76 4914.36 67.56 S 345.62 E 5980473.09 N 619276.57 E 0.195 31 2,09 5049.42 0,520 330.980 4942.72 5012.32 66.70 S 345.46 E 5980473.94 N 619276.39 E 0.330 312.17 ,.-, 5146.08 0,740 334.830 5039.37 5108.97 65.75 S 344.98 E 5980474.88 N 619275.90 E 0.232 311 .99 5241,54 0.700 310.540 5134.82 5204.42 64.82 S 344.27 E 5980475.81 N 619275.18 E 0.320 311.58 5337.52 0,720 295.080 5230.80 5300.40 64.18 S 343.28 E 5980476.43 N 619274.18 E 0.200 310.81 5433.55 0.830 279.180 5326.82 5396.42 63.81 S 342.05 E 5980476.78 N 619272.94 E 0.250 309.73 5530.32 0.790 287.200 5423.58 5493.18 63.50 S 340.72 E 5980477.06 N 619271.61 E 0.124 308.54 5626.38 1.050 259.810 5519.63 5589.23 63.46 S 339.22 E 5980477.08 N 619270.11 E 0.524 307.12 5721.96 1.090 251.400 5615.19 5684.79 63.91 S 337.50 E 5980476.61 N 619268.39 E 0.169 305.34 5816.90 1.170 241.110 5710.11 5779.71 64.67 S 335.79 E 5980475.82 N 619266.70 E 0.229 303.49 5913.68 1.320 95.860 5806.88 5876.48 65.26 S 336.04 E 5980475.24 N 619266.95 E 2.456 303.55 6008.46 8.250 82.110 5901.27 5970.87 64.43 S 343.87 E 5980476.18 N 619274.77 E 7.359 311.30 6104.70 12.840 81.650 5995.86 6065.46 61.93 S 361.30 E 5980478.96 N 619292.16 E 4.770 328.72 6199.33 17.510 80.980 6087.17 6156.77 58.17 S 385.77 E 5980483.11 N 619316.57 E 4.938 353.25 14 August, 2002 - 15:17 Page 3 of6 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 5-112 MWD Your Ref: API 500292309900 Job No. AKMW22107, Surveyed: 1 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6295.78 22.990 80.650 6177.62 6247.22 52.83 S 418.71 E 5980488.97 N 619349.42 E 5.683 386.35 -- 6389.98 27.370 80.450 6262.85 6332.45 46.25 S 458.24 E 5980496.18 N 619388.84 E 4.651 426.11 6486.73 32.500 78.920 6346.67 6416.27 37.56 S 505.71 E 5980505.63 N 619436.16E 5.360 474.09 6583.32 38.210 80.420 6425.41 6495.01 27.59 S 560.68 E 5980516.47 N 619490.97 E 5.979 529.62 6679.24 43.400 80.200 6497.99 6567.59 17.04 S 622.44 E 5980528.00 N 619552.56 E 5.413 591.84 6765.90 47.630 81.830 6558.71 6628.31 7.41 S 683.50 E 5980538.59 N 619613.45 E 5.062 653.11 6852,27 52.580 81.120 6614.09 6683.69 2.42 N 749.01 E 5980549.46 N 619678.79 E 5.766 718.70 6583,51 ~:-) 0<ìO 81,310 f3632.32 6701,92 6,29 N 774.07 E 5980553.73 N 619703.79 E 10,077 7 tt :un ('(¡1 rl.?R (i~)O gO, aGO riG49.61 G719,21 10.43 N 800.40 E 5980558.28 N 619730.05 E 6,C,Q7 770,25 6047.15 61. 1 ~)O eO.21O 6665.74 6735.34 14.95 N 827.51 E 5980563.24 N 619757.09 E 9,880 797.:>2 r07r~3 G1,P10 nO,870 G679,09 G749,59 19.54 N 855.08 E 5980568.26 N 619784.58 E 11.813 825.26 7"',~<) 0 {,I,O:O GG02,.:13 Ci7G2,03 24.01 N 883.18 E 5980573.18 N 619812.61 E 10,1 SG 853.47 7041,94 71 A ~)O 79.590 6703.65 6773.25 29.12 N 913.08 E 5980578.76 N 619842.43 E 11.589 883.59 7073,91 75A90 79.340 6712.75 6782.35 34.72 N 943.21 E 5980584.84 N 619872.46 E 12.659 914.06 71 OG.46 79,720 76.280 6719.73 6789.33 41.44 N 974.27 E 5980592.05 N 619903.41 E 15.910 945.75 7137.83 84.200 75.030 6724.12 6793.72 49.13 N 1004.36 E 5980600.22 N 619933.37 E 14.816 976.78 7170.06 85,070 72.170 6727.13 6796.73 58.19 N 1035.13 E 5980609.77 N 619964.00 E 9.238 1008.87 7205.66 85,810 68.840 6729.97 6799.57 70.03 N 1068.58 E 5980622.14 N 619997.26 E 9.553 1044.30 ,~ 7236.12 87.780 65.460 6731.67 6801.27 81.84 N 1096.60 E 5980634.39 N 620025.08 E 12.828 1074.53 7269.29 90.7 40 63,720 6732.10 6801.70 96.07 N 1126.56 E 5980649.09 N 620054.81 E 10,351 1107.29 7300.58 92.220 60.700 6731.29 6800.89 110.65 N 1154.22 E 5980664.11 N 620082.24 E 10.745 1137.97 7332.11 95.050 59.250 6729.29 6798.89 126.40 N 1181.47 E 5980680.29 N 620109.23 E 10.081 1168.56 7362.66 95.240 58.730 6726.55 6796.15 142.07 N 1207.54 E 5980696.37 N 620135.06 E 1.806 1198.02 7412.05 95.850 56.470 6721.78 6791.38 168.41 N 1249.05 E 5980723.37 N 620176.14 E 4.719 1245.31 7457.48 95.490 57.650 6717.29 6786.89 192.99 N 1286.99 E 5980748.55 N 620213.68 E 2.703 1288.67 7508.14 91.720 59.240 6714.10 6783.70 219.44 N 1330.06 E 5980775.68 N 620256.33 E 8.074 1337.50 7555.36 95.050 61.890 6711.32 6780:92 242.60 N 1371.10 E 5980799.49 N 620297.00 E 9.006 1383.44 7601.25 95.170 61.660 6707.23 6776.83 264.22 N 1411.38 E 5980821.74 N 620336.92 E 0.564 1428.20 7654.86 95.050 62.160 6702.45 6772.05 289.36 N 1458.48 E 5980847.63 N 620383.63 E 0.956 1480.51 7700.49 93.140 62.850 6699.19 6768.79 310.37 N 1498.86 E 5980869.28 N 620423.66 E 4.449 1525.19 14 August, 2002 - 15:17 Page 4 0'6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for S-112 MWD Your Ref: API 500292309900 Job No. AKMW22107, Surveyed: 1 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7745.29 93.760 61.920 6696.50 6766.10 331.10 N 1538.48 E 5980890.63 N 620462.95 E 2.492 1569.08 7787,91 93.820 62.990 6693.68 6763.28 350.77 N 1576.18 E 5980910.90 N 620500.34 E 2.509 1610.82 7840.45 93.750 63.020 6690.21 6759.81 374.57 N 1622.90 E 5980935.43 N 620546.67 E 0.145 1662.38 7892.28 89.630 62.440 6688.69 6758.29 398.30 N 1668.94 E 5980959.89 N 620592.32 E 8.027 1713.27 7936.65 87.290 62.140 6689.88 6759.48 418.92 N 1708.20 E 5980981.14 N 620631.26 E 5.317 1756.78 7984,95 86.980 62,500 6692.29 6761.89 441.33 N 1750.92 E 5981004.22 N 620673.61 E 0.983 1804.11 8031,91 87,170 63,510 6694.69 6764.29 462.62 N 1792.71 E 5981026.17 N 620715.06 E 2.186 1850.23 3078.70 [7.420 63.840 6696.90 6766.50 483.34 N 1834.60 E 5981047.56 N 620756.62 E 0.884 1800,29 ~' 1 ~>r¡ GO Cdì 1 °0 G? ::~~O G697,96 ô767.56 506.30 N 1880.01 E 5981071.23 N 620801.66 E 6,002 1946.35 8177.67 93,570 60.890 6696.39 6765.99 529.06 N 1922.31 E 5981094.66 N 620843.59 E 7.833 1993.38 P:-'2r. 12 (ii, :-r,(ì 60,71 0 6602.95 6762.55 552.64 N 1964.50 E 5981118.91 N 620885,39 E 2.077 2040,:,tt '3( 1 G :0 59750 f5œO,66 67GO,26 572,98 N 2000.06 E 5981139.81 N 620920,63 E 7,027 2()i\(H 2 (\323,29 ~iO,250 60.730 6689.64 6759.24 600.84 N 2048.78 E 5981168.44 N 620968.90 E 3.327 21 :~5,O5 8371.89 E,S,770 61.120 6690.06 6759.66 624.45 N 2091.25 E 5981192.73 N 621010.99 E 3.149 2182.49 8418.47 91.480 61.050 6689.95 6759.55 646.97 N 2132.02 E 5981215.89 N 621051.40 E 5.820 2227.98 8467.09 91.540 61.120 6688.67 6758.27 670.4 7 N 2174.56 E 5981240.06 N 621093.56 E 0.190 2275.46 8514.36 95.480 62.730 6685.78 6755.38 692.68 N 2216.18E 5981262.92 N 621134.83 E 9.001 2321.67 8574.72 95,800 61 .800 6679.85 6749.45 720.63 N 2269.35 E 5981291.72 N 621187.54 E 1.622 2380.60 ~, 8642.00 95,800 61 .800 6673.05 6742.65 752.26 N 2328.34 E 5981324.28 N 621246.02 E 0.000 2446.15 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-112. Northings and Eastings are relative to 5-112. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 5-112 and calculated along an Azimuth of 73.460° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8642.00ft., The Bottom Hole Displacement is 2446.85ft., in the Direction of 72.095° (True). 14 August, 2002 - 15:17 Page 5 of6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-112 MWD Your Ref: API 500292309900 Job No. AKMW22107, Surveyed: 1 August, 2002 . North Slope Alaska BPXA PBU_WOA S Pad Comments "- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) -, Comment 8642.00 6742.65 752.26 N 2328.34 E Projected 8urvey Survey tool program for 5':112 MWD From To Measured Vertical Measured Vertical Depth Dêpth Dêpth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 688.00 0,00 686.46 688.00 8642.00 686.46 AK-1 BP _HG (8-112 Gyro) 6742.65 MWD Magnetic (8-112 MWD) .-- 14 August, 2002 - 15:17 Page 6 0'6 DrillQuest 2.00.08.005 Schlumbergel' Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well L-103 ~()S, IRq S-112 ~p~.. J~c; S-113 aO~-/l/~ Job# 22367 USIT 22368 USIT 22369 SCMT Log Description Date 08/06/02 08/03/02 07/28/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED AUG 20 2002 Alaska Oii & Gas Cons. Commission Anchorage NO. 2329 8/19/2002 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Color Sepia BL CD 2 2 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Rece~y: ~;;fJbJ~_Qogf4L) I @~@C:-;>"E ~~ Œ\'~ ~@~f!@ æ) ~ LÆ '- 1 ~J Lru ~LÆ æ) ~~~ ATtASIiA. OIL AND GAS CONSERVATION COMMISSION / / / / f / TONY KNOWLES, GOVERNOR Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-112i BP Exploration (Alaska), Inc. Permit No: 202-135 Surface Location: 4331' NSL, 4500' WEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 4996' NSL, 2258' WEL, Sec. 35, T12N, R12E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced service well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be' conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. The blQwout 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 AAC25.412 and 20 AAC 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 may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (1J;h,~.A' ~.~ &~~;-6echsli Taylor Chair BY ORDER OF THE COMMISSION DATED thi~ay of July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA , - AND GAS CONSERVATION COMM ;ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test B Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 69.80' Prudhoe Bay Field I Aurora 6. Property Designation Pool (Undefined) ADL 028257 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-112i 9. Approximate spud date 07/06/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8496' MD /6746' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 980 Maximum surface 2614 psig, At total depth (TVD) 66101 I 3275 psig Setting Depth Top Bottom MD TVD MD TVD 34' 341 114' 114' 34' 34' 2895' 28601 34' 34' 6872' 66801 6722' 6589' 8496' 6746' ALASKA( 1a. Type of work B Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 43311 NSL, 4500' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 4338' NSL, 3710' WEL, SEC. 35, T12N, R12E, UM At total depth 4996' NSL, 2258' WEL, SEC. 35, T12N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028258, 3021' MD 5-213 is 14' away at 484' MD 16. To be completed for deviated wells Kick Off Depth 400' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casinc;J Weight Grade Couolina 20" x 34" 215.5# A53 Welded 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 IBT Hole 48" 12-1/4" 8-3/4" 6-1/8" Length 80' 2861' 6838' 1774' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Perforation depth: measured true vertical W"^- ï if J o~ ,-J7:F "1 / I c:> t..-- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include stage data) ~60 sx Arctic Set (Approx.) 434 sx PF 'L', 201 sx Class 'GI 217 sx Litecrete, 183 sx Class 'G' 112 sx Class IG' Plugs (measured) Junk (measured) Cemented TVD MD RECEIVED JUN 2 7 2002 Alaska Oil & yI)lWíìi;.jgIO¡ AnchoraQe B Filing Fee [] Property Plat 0 BOP Sketch 0 Diverter Sketch B Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Michael riolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1~:~:Y ::~ ;::: the fsr::~~~~;;;~;;~~1;;~!> ...Date. . ""-;n~ ð~ Permit Number, API Number , ~ma~~etJ See cover letter za z- - / .5 5' 50- 02. ? - 2. 30 ;7' '7 ~ 11.?7v. p-- for other requirements Conditions of Approval: Samples Required 0 Yes JiJ No Mud Log Required 0 Yes ŒI No Hydrogen Sulfide Measures 0 Yes IS1 No Directional Survey Required m Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: res:!-- B,O¡? f' to 3500 fiLe:. M t:T <t<.<ß ~~Pr ~¿; 9: t¡le¡ ~~ ':9 ~ Approved By Ú!¡gmaI SIgned By Commissioner the commission Date' Z-1;~F' \ Form 10-401 Rev. 12-01-85 Cammy Oechsli Taytor 0 R \ G \ N A L S b In Tnphcate 20. Attachments ( 1. Well Plan Summary Well Name: S-112i Greater Pruçlþoe Bay Polaris W-203 Permit ( I Type of Well (producer or injector): lUSH Horizontal Injector I Surface Location: 4,3321 FSL, 4,5011 FEL, Sec. 35, T12N, R12E X = 618,929.92 Y = 5,980,535.15 , , 4,338' FSL, 3,7091 FEL, Sec. 35, T12N, R12E X = 619,720.00 Y = 5,980,555.00 Z = 6,610' TVDss 4,996' FSL, 2,2581 FEL, Sec. 35, T12N, R12E X = 621,160.00 Y = 5,981,236.00 Z = 6,676' TVDss S-112i Target Start: S-112i Target End: I AFE Number: I AUD5M0026 I Rig: I Doyon 14 MD 18,496' I I TVDrkb: TD 16,746' I I Max Inc. I 98° I I KBE I I I 69.80' I I Estimated Start Date: I July 6tn 2002 I Operating days to complete: I 22.00 Well Design: USH Grassroots Kuparuk Pre-produced Horizontal Injector. 4-Y2" TCII Gas Lift completion. Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: S-112i 50-029- ???? Development - Aurora Kuparuk Pre-produced Injector New well, 20" X 34" insulated conductor 3,290 psi @ 6,685' TVDss (9.5 ppg EMW). Normal pressure gradient. 165°F @ 6,685' TVDss Estimated Mechanical Condition S-112i: Doyon 14: Conductor: Cellar Box above MSL = 35.8' KB / MSL = 34.0' 20" X 34", 215.5Ib/ft, A53 ERW set at 114' RKB Target Estimates Estimated Reserves: 1 ,680 mstb Expected Initial Rate: 1,200 bopd Expected 6 month avg: 700 bwpd Version #2, 4/29/2002 ( Materials Needed Surface Casing: 3,000' 1 each 1 each 25 each 1 assembly 1 each 1 lot Intermediate Casing: 6,900' 1 each 95 each 2 lots Production Liner: (as contingency) 1,900' 800' 104 each 7" x 4 Y2" 4 Y2" 1 assembly 2 each 2 each (as contingency) (as contingency) L-80 Completion: 7,000' 1 each 1 each 1 each 3 each 2 each 1 each 1 each Drillina Proaram Overview Surface and Anti-Collision Issues Greater Pry,d~oe Bay Auora S-112i Permit ( 9-%", 40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 %" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" TAM Port Collar 9-%" casing pups 5', 10', 20'. 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8 %" Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 4 Y2", 12.6#, L-80, IBT-Mod Slotted Liner 4 Y2", 12.6#, L-80, IBT-Mod Solid Liner 4 Y2" x 5 %" x 8" Straight Blade Centralizers Baker ZXP Liner Top Packer Baker guide shoe with pack off bushing Baker Bonzai with ECP 4 Y2", 12.6#, L-80, IBT-M; 10' Solid Short Joints Halliburton XN-Nipple (3.725" ID) 4 Y2" 12.75Ib/ft, L-80, TCII tubing Baker PRM Packer 7" X 4- Y2" 4-¥2" Halliburton Durasleeve Halliburton XN-Nipple (3.725" ID) Halliburton X-Nipple (3.813" ID) Cameo 4-%" X 1" KBG2 Gas Lift Mandrels 11" X 4- Y2" FMC tubing hanger 4-1/16", 5m Cameron Tree Surface Shut-in Wells: S-216 and S-213 need to be shut-in for the rig move on and off S-112i. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: "::Well,Nàme':' "Ct..~CtrDistance, S-216 15.27 -ft S-213 14.33-ft S-200 PB1 31.10-ft S-41 61.69-ft S-43 70.53-ft S-38 116.37 -ft , ,Reference MD, :" 285.43-ft 483.94-ft 564.07 -ft 1,818,s3-ft 2,911.14-ft 7,447.35-ft , ': Allowable Deviati(jlj 8.17-ft 5.66-ft 21.40-ft 27.49-ft 18.97 -ft 27.70-ft ", ,,'., ::~r~ç~~ti()[1aryComl!lent,;::',:, Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder Use Traveling Cylinder Use Traveling Cylinder 2 Mud Program 12~" Surface Hole Mud Properties: Interval 1 Density (ppg) Funnel vis Initial 8.5 - 8.6 150 - 300 Base Perm 8.6 - 9.6 200 - 300 Interval TO 8.6 - 9.6 200 8 3A" Intermediate Hole Mud Properties: Interval 1 Density (ppg) Funnel vis Initial 9.0 - 9.4 45 - 55 Ugnu / Schrader 9.7 45 - 55 Colville 9.7 45 - 55 HRZ - TO 10.3 40 - 50 YP 50 - 70 30 - 50 25 - 48 YP 21 - 28 21 - 28 20 - 24 20 -24 6 %" Production Hole Mud Properties: Kuparuk Density (ppg) Chlorides YP 9.8 - 10.0 20,000 ppm 22 - 27 Formation Markers }~j!:;:;,~F'::Formåtión\¡ops Base Gubik SV6 Base Permafrost SV5 SV4 SV3 SV2 SV1 UG4 UG4A UG3 UG1 Ma (Top Schrader Bluff) Schrader Buff N-sands Schrader Bluff O-sands OBf (Base Schrader) Top Colville Mudstone CM1 (Colville Shales K-10) THRZ TKUP LCU KUP A5 KUP A5 LCU TKUP CasinglTubing Program 48" 12-%" 8-%" 6 %" Kup Tubing Greater Prydhoe Bay Auora S-112i Permit ( 1¥.:FfT\fDss;¡;: '3~¡i:tjFfMD:::;,:!;~'¿<'Ft TVD'h.t~ ,:>~òre::psi: ':. 335 405 405 1,565 1,658 1,635 1,875 1,976 1,945 2,135 2,240 2,205 2,320 2,425 2,390 2,690 2,795 2,760 2,845 2,950 2,915 3,200 3,305 3,270 3,540 3,645 3,610 3,590 3,695 3,660 3,880 3,985 3,950 4,380 4,485 4,450 4,695 4,800 4,765 4,890 4,995 4,960 4,995 5,100 5,065 5,300 5,405 5,370 5,300 5,405 5,370 6,400 6,556 6,4 70 6,560 6,789 6,630 6,610 6,872 6,680 6,656 6,960 6,726 6,674 7,000 6,744 6,691 7,072 6,761 6,680 7,700 6,750 6,685 7,800 6,755 I Spud - Freshwater Mud (PHPA) Tauo PH API Filtrate >15 8.5 - 9.5 15 - 20 >10 8.5 - 9.5 <10 5 - 8 8.5 - 9.5 <8 Freshwater Mud (PHPA) Tauo PH API Filtrate 3-6 8.5-9.5 <5 3 - 6 8.5 - 9.5 < 5 3-6 8.5-9.5 <4 2 - 5 8.5 - 9.5 < 4 KCL - BaraOril-N Mud MBT PH HTHP @100° <4 8.0 - 8.5 < 10 Welded BTC BTC-M IBT TCII 3 . ' : Le~~~~ 80' 2,861' 6,838' 1,774' 6,683' :; ~~I",?i'~,:,:,~~~t.,.":: :',',", '..Csg I' ",: ,>,i.; '::WtlFt:: 'Grade'" Conn " , .', :::.';:, TbgO ~D ~" ,:':" :'" ,0',;>, "";",,, : ,,;to, 20" X 34" 215.5# A53 9-%" 40# L-80 7" 26# L -80 4 Ÿ2" Slotted 12.6# L-80 4 Ÿ2" GL 12.6# L-80 '<EMW:(ppg)": 0 0 0 0 0 0 0 0 0 8.8 -10.3 0 0 0 9.0- 9.5 0 0 0 0 0 9.5 9.5 9.5 9.5 9.5 9.5 3275 3275 3280 3290 3285 3290 , Top', : MDI TVDrkb : 34' / 34' 34' / 34' 34' / 34' 6,722' / 6,589' 34' / 34' LG Solids N/A < 6.5 MBT <15 <15 <15 <15 LG Solids < 12 ppb ':;HydrQ'carbòns" Pass. Hydrates Pass. Hydrates Pass. Hydrates Pass. Heavy Oil Pass. Heavy Oil Pass. Heavy Oil Pass. Heavy Oil Pass. Heavy Oil Pass. Heavy Oil Pass. Heavy Oil Oil Oil Oil Oil Oil , ::Bòtto:~,': :'MD I TVDrkb 114' / 114' 2,895' /2,860' 6,872' / 6,680' 8,496' /6,746' 6,717' /6,586' ( Greater Pr~dhoe Bay Auora S-112i Permit ( Cement Calculations Casinq Size 19-%-in 40-lblft L-80 BTC - Single Stage Basis 11750/0 excess over gauge hole in permafrost interval, 300/0 excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' as a contingency for cement to surface Wash 10 bbls CW100 Spacer 75 bbls of Viscosified Spacer weighted to 10.20 ppg Lead 343 bbls (434 sks) 10.71b/gal Permafrost L cement - 4.44 cuftlsk Tail 42 bbls 15.8 Class G + adds - 1.17 cuftlsk Temp BHST == 500 F from SOR, BHCT 750 F estimated by Dowell In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. CasinQ Size 17" 26 Ibltt L-80 BTC-M - Single Stage Basis I 300/0 excess - TOC: 450' MD above the Ma sands (planned TUG4: 3,645' MD) => 3,200' MD Total Cement Volume: Wash 30 bbls CW100 Spacer 50 bbls of Viscosified Spacer (Mudpush XL Design) Weighted to 11.0 ppg Lead 93 bbls (217 sks) 12.0 Ib/gal Litecrete Slurry- 2.40 cuftlsk Tail 38 bbls (183 sks) 12.0 Ib/gal Class G Slurry-1.16 cuftlsk Temp I BHST == 1500 F from SOR, BHCT 1700 F estimated by Dowell CasinQ Size 14-%" 12.6 Ib/ft L-80 IBT-M - Bonzai Liner Basis I 50% excess - TOC: 200' MD above the top of the Liner Top Packer Total Cement Volume: Wash 25 bbls CW100 Spacer 25 bbls of Viscosified Spacer (Mudpush XL Design) Weighted to 11.0 ppg Tail 24 bbls (112 sks) 15.8 Ib/gal Class G - 1.17 cuftlsk Temp I BHST == 1520 F from SOR, BHCT 1750 F estimated by Dowell 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers floating in the middle of each joint of casing from the casing shoe up to 1,895' MD (1 ,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar. c) This centralizer program is subject to change pending actual hole conditions. 7" String Centralizer Placement a) Place 2 centralizers rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints (see illustration at the end of the wellplan) . b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 3,200' MD (450' MD above UG4 sand). Zonal isolation with cement is required across the UG4 sands. The centralizer program is subject to change pending modeling and hole conditions. 4 Y2" Slotted Bonzai Liner Centralizer Placement a) Run two straight blade rigid centralizer per joint, one floating on the top half and one floating on the bottom half between a stop collar on the slotted and solid portions of the liner. Do not put any cetralizers in the 7" x 4-%" liner lap. Bit Recommendations BHA Number Surface Interm. Prod. Hole Size and Section 12-%" 8-% 6%" Depths (MD) Bit Type Nozzles K-Revs Hours 0' - 2,895' 2,895' - 6,872' 6,872' - 8,496' TBD TBD TBD 4 ( Greater P~Ydhoe Bay Auora S-112i Permit ( Survey and Logging Program 12-1A" Hole Section: Surface Gyro if needed Open Hole: MWD' GR (Utilize 6-%" tools and collars to save time) Cased hole: None 8-%" Hole Section: MWD , GR , Res I PWD Cased Hole: USIT Bond 6 %" Hole Sections: MWD' GR' Res' PWD' Den' Neu' ABI' ABGR - (ABGR will be run if available) Cased Hole: None Motors and Required Doglegs BHA No. Motor Size and Motor Required Flow Rate RPMs Required Doglegs 1 8" Sperrydrill 6/7, 4 stg Mud Motor, 1.5° adj. with 400 - 650 60-120 1.5°- 2.5°/100' initial build 12" screw on stabilizer gpm 4°/100' final build 2 7" Spe rryd rill 7/8, 6 stg FTC Performanc motor, 500 - 600 60-120 3.5°/100' build with 1.22° adj. with 8.6" concentric sleeve gpm to horizontal 3&4 4 %" Sperrydrill 4/5, 6.3 stg FTC Performance, 250 -275 60-100 Maximum build = 15°/100' 1.5° adj with 5.8" concentric sleeve and ABI gpm Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. /' Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. . Production Section- Maximum anticipated BHP: 2,416 psi @ 4,890' TVDss - Schrader Maximum surface pressure: 1,927 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . . Maximum anticipated BHP: 3,275 psi @ 6,610' TVOss - Kuparuk Maximum surface pressure: 2,614 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . . Planned BOP test pressure: Planned completion fluid: 3,500 psi (the casing will be tested to 3,500 psi) Estimated 8.5 ppg Seawater / 6.8 ppg ~iesel . Planned BOPE Test Pres. 3,500/250 psi Rams & Valves 2,500/250 psi Annular Disposal . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS- 04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 5 ( Greater Prt~dhoe Bay Auora S-112i Permit ( Drill and Complete Procedure Summary Pre-Rig Work: A 20" conductor will be required. 1. Survey the site and set a 20" conductor to 80' below GL. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells on 15' centers for the rig move and simops production. Rig Operations: 1. MIRU Doyon 14. 2. Nipple up diverter spool and function test diverter if required. PU 4" DP as required and stand back in derrick. 3. MU 12-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2,895'. The actual surface hole TO will be +/-100' TVD below the top of the SV3 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port collar or stage tool will be run in the casing string to allow secondary cementing, in the event cement is not circulated to surface during primary cementing operations. 5. NO diverter spool and NU casing / tubing head. NU BOPE and test to 3,500 psi. 6. MU 8-3/4" drilling assembly with MWD/GR/Res/PWD and RIH to float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition mud. 8. Drill new formation to 20' below 9-%" shoe and perform LOT (minimum 11.7 ppg EMW). 9. Drill ahead to the top of Kuparuk formation building to 50°+ inclination. 10. Perform wiper trip and condition the hole for casing. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations and freeze protect the 7" x 9-%" annulus as required. 12. RIH w/ 6-%" directional BHA with triple combo real time LWD. Test the casing to ~psi ~O min. 13. Circulate and condition mud and displace over to 10 ppg BaradrilN fluid~S'oo' \d 14. Drill out the shoe and 20' of new formation. Perform FIT to 2.0 ppg over expected mud weight. Build to horizontal and drill to approximately 8,496' MD. Condition the hole for liner. 15. Run e-line cement evaluation log through the 7" casing for cement evaluation and AOGCC requirements 16. Run and cement a 4-%" solid x slotted liner with an inner string. Release from the liner and circulate well to clean seawater. 17. Run the 4-¥2" 12.6#, L-80 TCII completion assembly. Test the production casing/tubing annulus and tubing to 4,000 psi each. 18. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 19. Freeze protect the well to -2,200' and secure the well. 20. Rig down and move off. / Post-Ria Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the RP shear with a dummy GL V. 6 " ( Greater Prudhoe Bay Auora S-112i Permit ( Job 1: MIRU Hazards and Contingencies ~ S-216 and S-213 will require shutting-in for the S-112i rig move. S-216 is located -15' East from the S-112 conductor and requires well house removal for the move in of Doyon 14. S-200 is located -30' East from the S-112 conductor and requires wellhouse removal for the move in of Doyon 14 but will not require shutting-in. S-213 already has the wellhouse removed, but will require the wellhouse to remain off for the move in of Doyon 14. All surface flowlines and gas lift lines will be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. ~ S Pad is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: S-104 less than 10 ppm S-100 less than 10 ppm Adjacent producers at TD: S-101 less than 10 ppm S-40 70 ppm The maximum level of H2S recently recorded on the pad was -70 ppm from S-40A. The maximum level ever recorded on the pad was -130 ppm from 8-32 back in 3/2001. Both of these wells are Ivishak producers while the above wells and subject well are Kuparuk wells. ..-....:m;;,."JIIUf.';:¡.-- -Nh..;w;..w.,;;;~~;.;.. Job 2: Drill Surface Hole Hazards and Contingencies ~ No fault crossings are expected in the surface interval of S-112i. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines under Major Risk rules for this hole section, however there are several close approach wells which limits allowable well path deviation from the line. See "Close Approach Well List" table above in the Drilling Program Overview section for more detailed information. Review the traveling cylinder for tolerance lines and allowable deviations from the planned S-112i well-path. Also, a single shot gyro will be required in the surface hole due to magnetic interference of the close offset wells. The single shots could be needed as deep as -600' where we finally get -50' of separation from adjacent wells. ~ Minimal hydrate gas has been encountered in the recent Aurora S-Pad development. In the few wells where hydrate gas was reported, it was encountered within a range between the SV3 and SV1 sands. If encountered, hydrates will be minimized by treating the mud system with Driltreat (Lecithin). Additional measures include reduced flow rates and keeping the mud temperature cool «60 degrees if possible). Refer to Baroid mud recommendation. Job 3: Install 9-%" Surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 215% excess cement through the permafrost zone (and 300/0 excess below the permafrost) is planned. As contingency, a port collar will be run in the casing at -1,000' MD to allow circulating cement to surface if the single stage is unsuccessful. 7 (' Greater Prydhoe Bay Auora S-112i Permit (c Job 4: Drill Intermediate Hole Hazards and Contingencies ~ Minor cuttings gas and gas cut mud has been fairly typical within the Ugnu and Schrader intervals. There is a potential for these intervals to be over-pressured in some areas around S-Pad, however S-112i should penetrate this section within an isolated fault block where pressures are expected to be in the 9.0 - 9.5 ppg range. Nevertheless monitor closely for any signs of overpressure. ~ Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and Schrader Sands. Minimize the time the pipe is left stationary. ~ KICK TOLERANCE: Based upon the expected Kuparuk reservoir pressure of 9.5 ppg and a 10.3 ppg mud, a 13.2 ppg leak-off will provide just over 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.7 ppg. Based upon off-set drilling data on S-Pad, a minimum leak-off of 12.5 ppg is expected at the 9-%" shoe and will provide -38 bbls of kick tolerance. It will be more important on this well to conduct extra flow checks until the 7" casing is landed and cemented due to the possible smaller kick tolerance. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. See "Close Approach Well List" table above in the Drilling Program Overview section for more detailed information. Review the traveling cylinder for tolerance lines and allowable deviations from the planned S-112i well-path. "11~'""""".,(-~,~,..,..,..", Job 6: Install 7" Intermediate Casina Hazards and Contingencies ~ Differential sticking is a concern across the long Ugnu and Schrader intervals. Communicate individual responsibilities to all members of rig team and review connection and casing running practices to minimize the time the pipe is left stationary. ).- At this location the Schrader interval is expected to have oil. Therefore, current plans cement 500' MD above the UG4 sand with cement. This will be achieved by pumping a light weight lead cement to meet AOGCC requirements. ).- The well will be underbalanced after displacing the cement with Sea Water. Verify the floats are holding prior to continuing operations. If floats are not holding, hold pressure and wait on cement. ~ Cementing lost returns have been prevelant on longstring cement jobs in this area due to the high MW for the HRZ stabilization. It will be required to stage in the hole with the casing to help break the gels in the mud and roll over the mud prior to reaching TD. This should help to lessen the suge pressures while RIH with the casing and should reduce the suge pressures needed to overcome the full column of dehydrated mud at TD. Once on bottom break circulation slowly to avoid extra surging prior to pumping cement. Follow Dowell's modeled pump rates and volumes to ensure adequate standoff from the formation frac gradients achieve a cement job without losses. Job 7: Drill Production Hole Hazards and Contingencies ).- One fault crossing has been identified in this hole section. As planned, the well will encounter this fault at -7,730' MD I 6,750' TVD (within the Kuparuk Reservoir). The estimated throw of the fault is -35' northwest. This fault has not been crossed in off-set drilling, however based upon similar faults cut in the Kuparuk on S-Pad, lost circulation is considered to be a minor risk. Nevertheless, have LCM products on location to treat any losses encountered. The major risk in crossing this fault is getting lost and or faulting up into the HRZ. The current directional plan has us dropping angle while crossing the fault to mitigate this potential hazard. ).- KICK TOLERANCE: Based upon the expected Kuparuk reservoir pressure of 9.5 ppg and a 10.0 ppg mud, an 12.0 ppg leak-off will provide infinite kick tolerance. Contact Anchorage personnel if FIT is less than 11.0 ppg. Based upon off-set drilling data on S-Pad, a minimum leak-off of 13.5 ppg is expected at the 7" shoe and will provide infinite kick tolerance. ~ The Kuparuk target polygon has been sized to avoid crossing a large fault at the end of the wellbore. Therefore, consider the end of the polygon a hard-line and don't drill beyond it. 8 If" ( Greater P~udhoe Bay Auora S-112i Permit ( Job 9: Run and Cement Production Liner Hazards and Contingencies ~ The major risk to this phase is in getting the liner on depth so that the ECP is on depth. ~ It will be necessary to run 2 centralizers per joint to minimize differential sticking and to provide adequate standoff to facilitate the necessary cement bond across the Bonzai section of the liner. ~ It may be necessary to run an innerstring out to the end of the slotted liner depending on hole conditions. This will be detailed in the wellplan. Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Job 13: ND/NU/Release Rig Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ;.;.;.;.~;..;;'~'f'¡)fIiI'T,.».,.;....<:..-.~:..--¡.,m;;.¡.¡.,-;';;".'4'm'M~;1(~'m''''''''''''M«-1''«'I-'''''''1~~~-;,;,;,,';.;.;.sx:;..,.;.;.;..;;.)t1:;~:;'~~i'M'!'$-:»YX~i«~¡W$ffNtWll":"I..'i.'i'm1I!'m.¡$IliWli<:Wi'i'N11l$i'ii'$:'m1(:;V!1(-ll'm'''''_,*.^~w.-...~M..~m¡.,~~)!.)M~XØ'i.~-.~~m.'i1i'1';S)Wi.»''AA--..'iW:<I-,~~ 9 F \ " 8-112 Proposed Completion 4-112" RA Tags I short 6,900' ~ Joints 7,300' ,d "Q..' Cemented Bonzai ECP ~/-7,4oo1 ......, C Cellar Elevation = 35.8' Doyon 14 RKB = 69.8' ~ 0 TAM Port Collar \1 ,000' \ 9-5/8",40 #/ft, L-80, BTC j \2,895' I [2 . ~ E;:, É3 . r',.~........,.'..........,~ 7",26 #Ift, L80, BTC-Mod 1 6,872' 1 ~ Date 6/26/02 Rev By MikT Proposed Completion TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wi 7" mandrel hanger & packott 11" x 11", 5M, tbg spool wi 11" x 4-1/2" tubing hanger 11" X 4-1/16" Adaptor Flange ~ 20" X 34" 215.5Ib/ft, A53 ERW Insulated 114' 0 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 1 2,200' TVD 1 ~ Camco gas lift mandrel 4-1/2" x 1" KBG2 I 3,800' TVD I With RP Shear Valve in top mandrel 4-1/2", 12.75 Ibltt, L-80, TCII Coupling 00: 4.932" OriftllO: 3.833"/3.958" Camco gas lift mandrel 4-1/2" x 1" KBG2 I 5,600' TVD I Camco gas lift mandrel 4-1/2" x 1" KBG2 I 6,400' TVD I 4-1/2" 'Halliburton Durasleeve with Landing Nipple with 3.813" 10 7-5/8" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go 10. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. ~ l 6,750' I BAKER 5" x 7" Liner Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 4-1/2" 12.6 #/ft, L-80, Slotted I 8,496' I Plug Back Depth I 8,490' I ==1 -r> Comments AURORA WELL: 5-112 API NO: 50-029-???1? BPX Aurora Field õ COMPANY D£TAILS BP Amo.., CaIcubc;oø Method: MiDìmam ~ Enw Sy-.. !SewSA ScmM- TnovCyIhlorNorth W.:= ~~c.q REFERENCE INFORMATION Co«dmIo (NIB) Ref- wen Cam: 8-112, TIIIo Nord1 Vertical (TYD) Ref_: S.!'8d Wel" 70,00 Section (VS) Ref.......: Slot. (O,OON,O.OOE) M~e~-= ~~.OO SURVEY PROGRAM Dopd>Fm Do,IbTo s..rv"yiPlm 70,00 1000,00 PIomod: 8-m wp06 VI 1000.00 849S.75 PIomod: 8-m wp06 VI Tool Cø.GYRO-SS MWDHFR+MS Plan: 8.112 wp()6 (8oII2IP1an 80112) Oeakd By: Ken Allen Date: 112312002 OIeclced: Reviewed: Date: Date: WElL DETAILS NmIe +N/oS +11I.W ~ ~ L81iIudo ~ Slot 8-112 .335A3 1005.01 S980535.00 618930,00 70"21'19,7031'1 149"02'02,96SW NtA I fA i 0 1-Pì-¡ ! I I ----+--i--~ Start Dir 1.5/100': 300' MD, 3oo'TVD i i ::--1 Base Gubik ! I rJl Start Dir 2/100' : 566.67' MD, 566.45'TVD i J ---î-'--;--- ---t ¡ ! go 1 ----;.---+--- '-~ ¡ I End Dir : 1034.56' MD, 1028.59' TVD ---r---+---=--t"- ¡ 11 ()()(I ! 1200 : i í 'I I --~--+----- 4l? ¡! ',1 I - =::::t:_c:'l:::c:::=:4 SV6 - ---1---1-----+ -_L Base Permafrost - :'==t'=4:==--==-j~, Start Dir 3/100': 1981.17' MD, 1950'TVD i I 2oo? ' ! It.! SV5 . f 2400 ~ I' .~ SV4 _._-~-+-- ----t--~- End Dir : 2422.84' MD, 2387.74' TVD I ~~~~.~~~: i ~=l~~=~~~~~~~t~~ SVl ~ 3600 ¡; ¡ . i UG4 i ---r- ! -t~ UG4A ~ ~ ~~:~t~t~~----~t.I-_- UG3 ¡... ì i 4000 I ~-lt~-=+f 001 480" ,--.-L--+-..u_--_u+.....L.. Ma (fop Shrader Bluff) v i I I i - -------L=f:=---I,~ WS2 (N sands) --'+---~---5OOõ-r- WSl (0 sands) ---L-i-----L --t- ii' I --F:~-r-::..-=c:~-i--T Obfbase / T. Collvil1e -----t--+-------+- -~-- - ---+-~---- --+~ Start Dir 6/100' : 5898' MD, 5862.9'TVD ; ¡ ì~o 6000 -_J.__L_~~_~"~6:¡- - -.1-1...-- -ç~-- '. ~~ -- End Dir ; 6783.92' MD, 6627.\' TVD --'---+--' --r ~ i 7" ! ',;. I I ¡ -=-r-+-- -i!t~ ,-- u-:.t---_u-t----+---:---+I---¡------ Total Depth: 8495.75' MD, 6746'TVD ----t--¡---=,:.'-=b"';'- ~---J::t::-- j ; ì I I 1-4---- -- ----t--_ar -" --_mlT19fëb~I+~--~t---~oöq~jT-L-r~\~_a ----t-"i---- --¡--- t"'l- -- ¡-¡--- - -oo-r---1---t--t-'-r-----4 1/2" 7200 : I 1 J ,I i I Ii, -- ---.l---L----..-_l-_-J.-_l___l_-L-----~----¡--J----j--~--.--- I ¡ ! ¡ I r ! . i : ¡ ! : N- lVD TARGET DETAILS +WoS +11I-W Nort!q Eaot8r& Slape 619838.03 POlysoo 620770.93 PoiŒ 620309.97 PoiŒ tI20943.92 PoÎrJI 621159,91 Poin! 620011.99 PoinI 619720,00 Poin! ~:m l>ì~ :~g:~ 'm~ I=:~ ~mm; S'1I2C2 6741,00 238.26 1384,04 5980795.19 S-1I2 E2 6770,00 S56.27 2023.18 S98I123.27 S-1I2 f2 6746,00 665.87 2201(1,95 5981236.30 8-112 B2 6776,00 87.96 1083.61 598064O.1~ S-1I2 A2 6680,00 756 790.28 S980SSS.1I Sec MD Inc Azi TVD +N/-S +EI-W DLeg TFace vSec Target 1 70.00 0.00 0.00 70.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 566.61 4.00 90.00 566.45 0.00 9.30 1.50 90.00 8.91 ..-,., 4 822.06 9.00 100.00 820.13 -3.47 37.90 2.00 17.77 35.34 5 1034.56 13.25 100.00 1028.59 -10.59 78.27 2.00 360.00 72.01 6 1981.17 13.25 100.00 1950.00 -48.26 291.94 0.00 0.00 266.10 7 2422.84 0.00 0.00 2387.74 -57.09 342.01 3.00 180.00 311.58 8 5898.00 0.00 0.00 5862.90 -57.09 342.01 0.00 0.00 311.58 9 6783.92 53.16 81.19 6627.10 -2.52 720.40 6.00 81. 79 689.84 10 6872.15 53.16 81.79 6680.00 7.56 790.28 0.00 0.00 759.70 8-112 A2 11 7197.87 92.01 68.98 6776.00 87.96 1083.61 /2.48 -19.90 1063.78 8-112 B2 12 7267.12 97.58 62.78 6770.20 116.12 1146.55 12.00 -47.69 1132.13 13 7426.21 97.58 62.78 6749.21 188.24 1286.78 0.00 0.00 1287.10 14 7535.94 91.00 62.78 6741.00 238.26 1384.04 6.00 -179.96 1394.57 8-112 C2 15 7613.72 86.42 63.67 6742.75 273.29 1453.44 6.00 169.07 1471.08 16 8029.25 86.42 63.67 6768.71 457.26 1825./1 0.00 0.00 1879.75 17 8055.68 88.00 63.55 6770.00 469.00 1848.77 6.00 -4.17 1905.78 8-/12Dl 18 8089.09 90.00 63.42 6770.58 483.91 /878.65 6.00 -3.82 1938.67 19 8217.32 90.00 63.42 6770.58 541.29 1993.33 0.00 0.00 2064.94 20 8250.72 92.00 63.29 6770.00 556.27 2023.18 6.00 .3.62 2097.82 8-112 E2 21 8321.24 96.23 63.29 6764.94 587.88 2085.99 6.00 -0.07 2167.Q3 22 8495.75 96.23 63.29 6746.00 665.87 2240.95 0.00 0.00 2337.79 8-112 F2 FORMA TlON TOP DETAILS No. TVDPath MDPath Fonnation 1 405.00 405.01 Base Gubik 2 1635.00 1657.56 SV6 3 1945,00 1976.04 Base permafrost 4 2205.00 2239.82 SV5 5 2390.00 2425.10 SV4 6 2760.00 2795.10 SV3 7 2915.00 2950.10 SV2 8 3270.00 3305.10 SVl 9 3610.00 3645.10 UG4 10 3660.00 3695.10 UG4A 11 3950.00 3985.10 003 12 4450.00 4485.10 001 13 4765.00 4800.10 Ma (Top Shrader BIufi) 14 4960.00 4995.10 WS2 (N sands) 15 5065.00 5100.10 WSl (0 sands) 16 5370.00 5405.10 Obfbase / T. Collville 17 6470.00 6555.93 CMI 18 6630.00 6788.76 THRZ 19 6680.00 6872.15 TKUP 20 6726.00 6959.87 LCU CASING DETAILS All TVD depths are ssTVD plus 70' for RKBE. 0 I 3600 1200 2400 Vertical Section at 73.45° [l2ooMn] 0 II I I ¡; I ¡I 1fP ,I ..?q¡o /~ ~", #§> t'Ç ~<& P "'/°00 SECTION DETAILS No. TVD MD Næœ Size 2860.00 2895.10 95/8" 6680.00 6812.14 7« 6746.00 8495.74 4 1/2" 9.625 7.000 4.500 Ò COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: S-112 wp06 (S-II2/Plan S-112) BP Amoco Co-crdiaIIo (NII!) R.C.......: W.D Cemo: 8-112, T.... N<>dh DopIh Pm DopIh T. SInoyil'loD Tool OeaIed By: Ken Allen Dale: 112312002 VOIticaI (1VD) Jtc¡'.....,.: S-PIod w.u. 70.00 C8IcuIoIioD Method: Minimum c.u........ Soc:tioD (VS) R.- Slot. (O.ooN,O.ooE) 70,00 1000.00 PIamod: 8-m wp06 VI CB-OYR0.8S Clceked: Date: =~= ~~~t-NoI1h M.-d~.~: ~~,oo 1000,00 8495.75 PIamod: 8-112 wp06 VI MWD+IFR+MS W..;= ~~c.mg Reviewed: Date: SECfION DETAILS FORMATION TOP DETAILS WElL DETAILS NImo +NI-S +FJ-W NootDns Eut8>& LIIiIude lon&itudc Slot See MD ItIC Azi TVD +N/-S +FJ-W DLeg TFace vSee Target No. TVDPath MDPath Formation 8-112 .335.43 1005,01 S980535,OO 618930.00 70"2I'19,703N 149"02'Q2,965W NIA 1 70.00 0.00 0.00 70.00 0.00 0.00 0.00 0.00 0.00 1 405.00 4'-'~.01 Base Gubik TAROET DETAILS 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 2 1635.00 1 f>~7.56 SV6 3 566.67 4.00 90.00 566.45 0.00 9.30 1.50 90.00 8.92 3 1945.00 1'.7".04 Base Permafrost N.... 1VD +N/-S +FJ.W Ncd>ing E8IIDIg Sbopo 4 822.06 9.00 100.00 820.13 -3.47 37.90 2.00 17.77 35.35 4 2205.00 .2~N.82 SV5 8-112 A2 6680,00 7,$6 790.28 5980'55.11 619720,00 Point 5 1034.56 13.25 100.00 1028.59 -10.59 78.27 2.00 0.00 72.02 5 2390.00 .24~~.10 SV4 S.112 C2 6741,00 238.26 1384.04 5980795.19 620309,97 Point 6 1981.17 13.25 100.00 1950.00 -48.26 291.94 0.00 0.00 266.10 6 2760.00 ~7°~.10 SV3 S.112 F2 67046.00 66S,87 22>10.95 598123630 621159.91 Point tm~1y 6770.00 -178.06 827,37 S980370.11 619760.02 POIySOD 7 2422.84 0.00 0.00 2387.74 -57.09 342.01 3.00 180.00 311.58 7 2915.00 ~'~II.l 0 SV2 6770,00 556.27 2023.18 598112327 620943,92 Point 8 5898.00 0.00 0.00 5862.90 -57.09 342.01 0.00 0.00 311.58 8 3270.00 ¡ 1I1~.10 SVl 8-m DI 6770,00 469.00 1848.77 598103325 62077D.93 Point 9 6783.92 53.16 81.79 6627.10 -2.52 720.40 6.00 81.79 689.85 9 3610.00 ¡M~.1O UG4 8-112 B2 6776,00 87.96 1083.61 5980640.15 620011,99 Point 10 6872.15 53.16 81.79 6680.00 7.56 790.28 0.00 0.00 759.70 S-112 A2 10 3660.00 ¡Io.0~.10 UG4A 11 7197.87 92.01 68.98 6776.00 87.96 1083.61 12.48 -19.90 1063.78 S-112 B2 11 3950.00 ¡"K'.IO UG3 CASING DETAILS 12 7267.12 97.58 62.78 6770.20 116.12 1146.55 12.00 -47.69 1132.13 12 4450.00 4JK~.10 UGl Size 13 7426.21 97.58 62.78 6749.21 188.24 1286.78 0.00 0.00 1287.10 13 4765.00 1!1'H'.10 Ma (fop Shrader BlufJ) No. TVD MD Name 14 7535.94 91.00 62.78 6741.00 238.26 1384.04 6.00 -179.96 1394.57 S-112 C2 14 4960.00 4'N~.10 WS2 (N sands) 9.625 15 7613.72 86.42 63.67 6742.75 273.29 1453.44 6.00 169.07 1471.08 15 5065.00 'I'H'.10 WSl (0 sands) 1 2860.00 2895.10 9 5/8" 16 8029.25 86.42 63.67 6768.71 457.26 1825.11 0.00 0.00 1879.76 16 5370.00 ~JII~.10 Obfbase I T. Collville 2 6680.00 6872.15 7" 7.000 17 8055.68 88.00 63.55 6770.00 469.00 1848.77 6.00 -4.17 1905.77 8-112 Dl 17 6470.00 "5 ~ ~.93 CMl 3 6746.00 8495.74 4 1/2" 4.500 18 8089.09 90.00 63.42 6770.58 483.91 1878.65 6.00 -3.82 1938.67 18 6630.00 Io.7!1(.76 THRZ 19 8217.32 90.00 63.42 6770.58 541.29 1993.33 0.00 0.00 2064.94 19 6680.00 Ms7~.15 TKUP 20 8250.72 92.00 63.29 6770.00 556.27 2023.18 6.00 -3.62 2097.82 S-112 E2 20 6726.00 "'~').87 LCU 21 8321.24 96.23 63.29 6764.94 587.88 2085.99 6.00 -0.07 2167.03 All TVD depths are 22 8495.75 96.23 63.29 6746.00 665.87 2240.95 0.00 0.00 2337.78 S-112 F2 90()- ssTVD plus 70' for RKBE. '¡;¡' ~ 8 !:1 +' f ~ ~ ::s rZ /\, //'/- \\ , i Je'" f ~-, . ¡ " 'i'" I.. . 4' \..'" /, '¡' , -- ---r--1 "",',' -- ,,- - --¡-----r-i----r------r--r---r-t-----¡---"-'-rEni-Dnj~i~i~'-wD;-6¡r64;r4'-~--r'rs-ïî2~¡¡ ':', T~taI Depth: 8495.75' MD, 6746' TVD -.-+--, , , ' " , -'-1--+---+--~-------!-------t---b-Lnt,.~OO'~-fl2H'~2'~Ð--611Q.5&ivD~A---L _'tn- -,...t--",- ..: " . Ii! ¡ I ! I! i i I ! I I:! ¡¡I I I Ii! ! I ¡-rOO j I r , . i I >r i :, I'. \ --¡--+--I------+-. --t---+---+--~---+--t--'+-~---j--- --+-~--i---r---+--i--I--+-1---L_----L-.1---iEndtÐjr.h-ßo39~'-MÐ.-617{}.mqVÐ- - y -1- +---Ì- --' - - --l..--- ,,-:"\;S-112 F2 I I, , I I I, I I ! 'i' ," I I 1 I ' ,I ,": J" , 7~; I I I ,,'. 600 I ,! 'I' I I , ! i i 1 ¡ i II I! I I 1 'II I I I ~tartpir~/l00':8029.~5'MD.d168f'I~)--/ 1 i I Iii ;41J.z~ Ii! ¡ I [ I, I! ! ¡:! ¡ I I I I ! ¡ ill I! I 1 ,.-r, ih: ! ' , ! i )/1 -- --t--'T- i----- +---+-+-~-+-- --I---t-+--+-- --i--1--t-'-t---r----+-+---t---+---t---+_-L_-+-+-_J_----+--+-"'fî---¡ -- ,. " 1---- -- j;--,;V--! I !; i I I !' I I I ! [ : ¡ I ~! ¡I! ~ ¡ ! I i ¡! k.-f'! I [ , ¡ IS-1.2_~~v ¡ : . ~=ftL-l1JìT~11lT~=jTILf~=++if~jif~L~~ftj~Ettr~=ri~! ! I i I I I I ¡ 1 ¡ ¡ i! ! i ¡ I i I!! I J,/ ! ! ! Î 1 : i I i Y' ! i ! i I 300 - _.J_m~n_-f-_..__.J,-,J--L-~, -,,--t-,-- ,_.,._--~_._-j-"---~---~-,,,---¡----,,---l-,--[,,--~~~~~J,' ~~~:_~~2~~~r~~._~?~~~I_~__I.._-.!--j-~ -J --~--------L-J~l:i~:--t--- ----~. - uL_, 1-- !--J ~' ". " I ! J' ! I I ! ¡ i I i ¡ I ! ¡EndlDirj': 72¡¡7.1~' MD, 6),10.2' ¡ ! ¡ I! I .......r! i' I ¡ ¡ ii, \' ---1'--+-- '------"'''-"l--T--¡Stá--:Dí--d487hw¡-~T~MU~,' ..-- ,---J-------t-L-i---+- , - +----..+ - -+---tS;;1-t2",' e-t--¥-+--+--t-..-¡-- ---.-,-- +----:-- f " ' . ! I! I: i J I rt r ¡' i , : ..~ , ¡ i ~I I ! ....// I : ! Ii; I ! ! ¡ // L, ¡ Iii I ! !: .< . "; --~--+-r---t..--I-+-' -t---+'--+---I---¡-+---I-,-+-----.J--~--t-,---+---- ,-- --'-~--~--r---.,.,.---- -+---t-+""'---T,,--+----t---i" ,', ' :,' , I ! ¡ S~ o¡~ q/l()Q' : 300' YD, jOO'1]VD : ¡ ¡ i i ! Y ! i il': ! ¡ ! A/ I i I I I ¡ I! I ¡ I ' , ,:, ---r---r--¡---- .-SUrtDir2ttOO'-t-;~~7LMJ.}!-566t4fflÐi,,---_..t---- --'--~----+, ---i --+---~, --..- -..-..-¡----t----'" --, -'-+. ------'-t--_-J.'-'-JL. ---r---t- -------r--+--I, ---i. --...-t,-."-- ----1- ---'," -+., ---j-- --~- ,I" ' . ¡. J 1 ! l! too ~ir j 1O~.56 M~ 1028.59' rVD ! I ,\ i! i:" SLI12 B2 i /I/! ¡ i j i ¡ ¡ ¡!!:' .J " --¡--¡--L--¡, -- irri--PT, --S~D¡nT1OO':r9stj7'-M~î95Õ~\tin_--t T=--j-- I'!-----/rl¡-l-r---,-+¡---¡-:---r-r-;u-r-'''-: ':, 0 ! i : Ii! i ¡ ¡ :"! Iii: :. ! ;:: I i/ : : ! :! I I Ii! ¡::! f , - --_..~--+----t-___~99..~..wdo-n-L,', --~j,-----~- t -~b' 9 5f8__~___-¡,-'-+;5j(J--L--#!- _-1,)t-~, l2-A21 ..j----~~~-~, S~~lt, }~~.'QQ:t?_!t', --:~~'-~!?!_!i_~~!t~~---j,-----~,' _m-----l..- ). ----1-- -t,'.----io .I ,,' , . ,,'~' ','," ',- '.' i ! i ! j I 1~00 'I' 2000~ 6006 i i! i if !\ ! ;ifi I /1J I ! i ! i! i I ! I ¡ ! ¡ ! ¡: A " /' ". '. "'" _ni-f-ni- ----'-r---i-t---- ----, f---+--,---+----"-r-..l. --,-+~-L- _un' ---+- ---¡------+--f----L--i---I---, ---+--+--+-+------ ---,--.- --+--1- -.1 , ~. I I ". 4! ,¡ '23 \ ¡¡I: Ii! ! I! ¡! I! Ii!! ¡Ii i i i:! ¡ [ " ': " - -+~dJ¡)ir._.2! ~MlMnL ~.JY)- ---L.-I--+---,------+--- -L---, +:7"----L-+-,-L---~--+-- --t---j--,---~_.-t--_.~---'--!---f-"'+----;'--+--'-'---'-- ,- , I StþrtQir6l100'~ 58~'~D, 5862f7\D i ! i i! i:! ¡ -¥,S-: 12~oly i ! i i ! i ¡ i! i [ ! 1 ¡ i: ¡ ¡ i ; - --¡--1-+-- -t---¡--,---\--- -'." =-n:.--;_L-.~~,. I' l'VUlj---+--T-t-------.---+---..-..L-+---_,__+_L_+-.l--_--+--t- -+---+--t-- --'+-' -L-----t-,J., . .' - I I, I" u 1u 1.J'lr . (f/1S1''-- tVIU,UU,," . ¡ I I I I' I I I I' I I I I ,,' Iii, I ¿ " ..,," - -t----t-.-'t-----i----r-'i---'+-'+----'1---+-.-:,,---t--.,, +--+--T+..-+--__+n+_+_~_+ -,_._-t--+,--+--t._--t'---'--i-'-+'--~----t,_.-+'-'---t'--t'---¡.-t,'-'-J- ". ~ '.,' ", ,. /. ~ -300 I I Ii, ¡ ¡Ii i 'I i i I I 1 I ! i I I i I I I i I Iii I ¡ i il#'.&> ' Q ~~~ Iii i! I Iii i ! I I ! I ¡ I ! ¡ i ' : I I I ¡ ¡ i i I Ii: -v - --+--+--T----_.+---+---+---~---+------t-_._~--t--t-î------+-+-+---'-r----~--+-r-----i--_n'-+_--4-+----t-+---~-r----r+--+---i---- --LI -- +-+--+-+ #' .&> '/tq, I' ¡ I I I ¡ I : ¡ I I' ! I, ¡I!: I ! I I I I I I ; I! ,1,1 i ~ : :, !", ,I ¡ ': I:' I, l::: : I I Ii: ;; i;:', I I I I 0 300 600 900 1200 1500 1800 2100 2400 2700 West(-)Æast(+) [300ft/in] ,,- BP Amoco Planning Report - Geographic Company: BP Amoco Field: Prudhoe Bay Site: PB S Pad Well: 8-112 Wellpatb: Plan 8-112 Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: PB S Pad TR-12-12 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5980854.54 ft 617919.92 ft 8-112 slot ss-02 Surface Position: +N/-S -335.43 ft +FJ-W 1005.01 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S -335.43 ft +FJ-W 1005.01 ft Well: Nortbing: 5980535.00 ft Easting: 618930.00 ft Nortbing: 5980535.00 ft Easting: 618930.00 ft Measured Deptb: 34.10 ft Vertical Deptb: 34.10 ft Date: 1/23/2002 Time: 11:15:29 Co..ordinate(NE) Reference: Well: 8-112, True North Vertical (TVD)Reference: 8-Pad Wells 70.0 Section (VS) Reference: Well (0.00N,0.OOE.73.45Azi) Plan: 8-112 wp06 Page: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 Latitude: 70 21 23.002 N Longitude: 149 2 32.343 W Nortb Reference: True Grid Convergence: 0.90 deg Slot Name: Latitude: 70 21 19.703 N Longitude: 149 2 2.965 W Latitude: 70 21 19.703 N Longitude: 149 2 2.965 W Inclination: 0.00 deg Azimutb : 0.00 deg Wellpatb: Plan S-112 Drilled From: Well Ref. Point Tie-on Deptb: 34.10 ft Current Datum: S-Pad Wells Heigbt 70.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/29/2001 Declination: 26.51 deg Field Strengtb: 57477 nT Mag Dip Angle: 80.79 deg Vertical Section: Deptb From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.10 0.00 0.00 73.45 Plan: 8-112 wp06 Date Composed: 1/22/2002 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information MD Incl Azim TVD +N/-S +FJ-W DLS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/100ft deg/100ft deg 70.00 0.00 0.00 70.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 566.67 4.00 90.00 566.45 0.00 9.30 1.50 1.50 0.00 90.00 822.06 9.00 100.00 820.13 -3.47 37.90 2.00 1.96 3.92 17.77 1034.56 13.25 100.00 1028.59 -10.59 78.27 2.00 2.00 0.00 0.00 1981.17 13.25 100.00 1950.00 -48.26 291.94 0.00 0.00 0.00 0.00 2422.84 0.00 0.00 2387.74 -57.09 342.01 3.00 -3.00 -22.64 180.00 5898.00 0.00 0.00 5862.90 -57.09 342.01 0.00 0.00 0.00 0.00 6783.92 53.16 81.79 6627.10 -2.52 720.40 6.00 6.00 9.23 81.79 6872.15 53.16 81.79 6680.00 7.56 790.28 0.00 0.00 0.00 0.00 8-112 A2 7197.87 92.01 68.98 6776.00 87.96 1083.61 12.48 11.93 -3.94 -19.90 S-112 B2 7267.12 97.58 62.78 6770.20 116.12 1146.55 12.00 8.04 -8.94 -47.69 7426.21 97.58 62.78 6749.21 188.24 1286.78 0.00 0.00 0.00 0.00 7535.94 91.00 62.78 6741.00 238.26 1384.04 6.00 -6.00 0.00 -179.96 S-112 C2 7613.72 86.42 63.67 6742.75 273.29 1453.44 6.00 -5.89 1.14 169.07 8029.25 86.42 63.67 6768.71 457.26 1825.11 0.00 0.00 0.00 0.00 8055.68 88.00 63.55 6770.00 469.00 1848.77 6.00 5.98 -0.44 -4.17 8-11201 8089.09 90.00 63.42 6770.58 483.91 1878.65 6.00 5.99 -0.40 -3.82 8217.32 90.00 63.42 6770.58 541.29 1993.33 0.00 0.00 0.00 0.00 8250.72 92.00 63.29 6770.00 556.27 2023.18 6.00 5.99 -0.38 -3.62 S-112 E2 8321.24 96.23 63.29 6764.94 587.88 2085.99 6.00 6.00 -0.01 -0.07 8495.75 96.23 63.29 6746.00 665.87 2240.95 0.00 0.00 0.00 0.00 8-112 F2 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 1/2312002 Time: 11:15:29 Page: 2 Field: PrudhOe Bay C~ordhtatØ)R.efettoce: Well: &-112, True North Site: PB S Pad Vertkal,(fVD).Reference: &-Pad Wells 70.0 Well: &-112 Section (VS) Refel'ence: Well (0.00N,0.OOE,73.45Azi) Wellpath: Plan&-112 Plan: &-112 wp06 Section 1: Start Hold MD Incl Azim +N/-S +FJ-W VS DLS Build Turn TFO ft deg deg ft ft ft døgl1QOff degl100ft deg/100ft deg 70.00 0.00 0.00 70.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 .0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Section 2: Start Build 1.50 ft ft ft ft deg/10OO degl1000 deg/10Off deg 400.00 1.50 399.99 0.00 1.31 1.25 1.50 1.50 0.00 0.00 500.00 3.00 499.91 0.00 5.23 5.02 1.50 1.50 0.00 0.00 566.67 4.00 566.45 0.00 9.30 8.92 1.50 1.50 0.00 0.00 Section 3: Start DLS 2.00 TFO 17.77 MD loci Azim ' TV» +N/-S +Fj..W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl100ft degl1000 deg/100ft deg 600.00 4.64 92.52 599.69 -0.06 11.81 11.31 2.00 1.92 7.55 17.77 700.00 6.59 97.11 699.20 -0.95 21.55 20.39 2.00 1.95 4.59 15.26 800.00 8.56 99.60 798.33 -2.90 34.59 32.33 2.00 1.97 2.49 10.69 822.06 9.00 100.00 820.13 -3.47 37.90 35.35 2.00 1.98 1.83 8.22 Section 4: Start Build 2.00 MD loci ADm TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft , degl1000 deg/100ft deg/10Off deg 900.00 10.56 100.00 896.93 -5.77 50.94 47.19 2.00 2.00 0.00 0.00 1000.00 12.56 100.00 994.90 -9.25 70.67 65.11 2.00 2.00 '0.00 0.00 1034.56 13.25 100.00 1028.59 -10.59 78.27 72.02 2.00 2.00 0.00 0.00 Section 5: Start Hold MD Incl Azim TVD +N/-S +Fl-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl100ft deg/100ft deg/100ft deg 1100.00 13.25 100.00 1092.29 -13.19 93.04 85.43 0.00 0.00 0.00 0.00 1200.00 13.25 100.00 1189.62 -17.17 115.62 105.94 0.00 0.00 0.00 0.00 1300.00 13.25 100.00 1286.96 -21.15 138.19 126.44 0.00 0.00 0.00 0.00 1400.00 13.25 100.00 1384.30 -25.13 160.76 146.94 0.00 0.00 0.00 0.00 1500.00 13.25 100.00 1481.64 -29.11 183.33 167.45 0.00 0.00 0.00 0.00 1600.00 13.25 100.00 1578.97 -33.09 205.90 187.95 0.00 0.00 0.00 0.00 1700.00 13.25 100.00 1676.31 -37.07 228.48 208.45 0.00 0.00 0.00 0.00 1800.00 13.25 100.00 1773.65 -41.05 251.05 228.96 0.00 0.00 0.00 0.00 1900.00 13.25 100.00 1870.99 -45.03 273.62 249.46 0.00 0.00 0.00 0.00 1981.17 13.25 100.00 1950.00 -48.26 291.94 266.10 0.00 0.00 0.00 0.00 Section 6: Start DLS 3.00 TFO 180.00 MD loci ADm TVD +N/-S +FJ-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl100ft degl100ft deg/100ft deg 2000.00 12.69 100.00 1968.35 -49.00 296.10 269.88 3.00 -3.00 0.00 180.00 2100.00 9.69 100.00 2066.44 -52.37 315.20 287.23 3.00 -3.00 0.00 180.00 2200.00 6.69 100.00 2165.41 -54.84 329.22 299.97 3.00 -3.00 0.00 180.00 2300.00 3.69 100.00 2264.99 -56.41 338.12 308.05 3.00 -3.00 0.00 180.00 2400.00 0.69 100.00 2364.90 -57.07 341.88 311.46 3.00 -3.00 0.00 180.00 2422.84 0.00 0.00 2387.74 -57.09 342.01 311.58 3.00 -3.00 0.00 -180.00 Section 7: Start Hold MD loci Azim TVD +N/-S +Fl-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl1000 deg/100ft deg/10Off deg 2500.00 0.00 0.00 2464.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 2600.00 0.00 0.00 2564.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 2700.00 0.00 0.00 2664.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 2800.00 0.00 0.00 2764.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 BP Amoco Planning Report - G~ographic . Company: BP Amoco Date: 1/2312002 Time: 11:15:29 Page: 3 Field: PrudhOe Bay Co-ord1ute(NE) Reference: Well: S-112, True North Site: PB SPåd Vertical (fVD)Rèference: 5-Pad Wells 70.0 WeU: 5-112 SeCtion (VS) Reference: Well (O.OON,O.OOE. 73.45Azi) WeUpath: Plan 5-112 Plan: 5-112 wp06 Section 7: Start Hold MD IncI ÁZim TVD +N/-S +FJ-W VS DLS Build Turn TFO ,ff deg' dég ft ft ft ft døgl1000 døgl1 OOftdeg/1 OOft deg 2900.00 0.00 0.00 2864.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3000.00 0.00 0.00 2964.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3100.00 0.00 0.00 3064.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3200.00 0.00 0.00 3164.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3300.00 0.00 0.00 3264.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3400.00 0.00 0.00 3364.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3500.00 0.00 0.00 3464.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3600.00 0.00 0.00 3564.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3700.00 0.00 0.00 3664.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3800.00 0.00 0.00 3764.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 3900.00 0.00 0.00 3864.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4000.00 0.00 0.00 3964.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4100.00 0.00 0.00 4064.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4200.00 0.00 0.00 4164.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4300.00 0.00 0.00 4264.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4400.00 0.00 0.00 4364.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4500.00 0.00 0.00 4464.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4600.00 0.00 0.00 4564.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4700.00 0.00 0.00 4664.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4800.00 0.00 0.00 4764.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 4900.00 0.00 0.00 4864.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5000.00 0.00 0.00 4964.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5100.00 0.00 0.00 5064.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5200.00 0.00 0.00 5164.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5300.00 0.00 0.00 5264.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5400.00 0.00 0.00 5364.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5500.00 0.00 0.00 5464.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5600.00 0.00 0.00 5564.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5700.00 0.00 0.00 5664.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5800.00 0.00 0.00 5764.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 5898.00 0.00 0.00 5862.90 -57.09 342.01 311.58 0.00 0.00 0.00 0.00 Section 8: Start DLS 6.00 TFO 81.79 " +N/-S MD Incl Azim TVD +FJ-W VS DLS Build Turn TFO ft deg deg ft ft ft ft d~100ft d~100ft deg/1000 deg 5900.00 0.12 81.79 5864.90 -57.09 342.01 311.59 6.00 6.00 0.00 0.00 5950.00 3.12 81.79 5914.88 -56.89 343.41 312.98 6.00 6.00 0.00 0.00 6000.00 6.12 81.79 5964.71 -56.32 347.40 316.97 6.00 6.00 0.00 0.00 6050.00 9.12 81.79 6014.26 -55.37 353.96 323.53 6.00 6.00 0.00 0.00 6100.00 12.12 81.79 6063.40 -54.05 363.08 332.64 6.00 6.00 0.00 0.00 6150.00 15.12 81.79 6111.99 -52.37 374.73 344.29 6.00 6.00 0.00 0.00 6200.00 18.12 81.79 6159.89 -50.33 388.88 358.44 6.00 6.00 0.00 0.00 6250.00 21.12 81.79 6206.98 -47.94 405.50 375.05 6.00 6.00 0.00 0.00 6300.00 24.12 81.79 6253.13 -45.19 424.53 394.08 6.00 6.00 0.00 0.00 6350.00 27.12 81.79 6298.21 -42.11 445.93 415.46 6.00 6.00 0.00 0.00 6400.00 30.12 81.79 6342.10 -38.69 469.63 439.16 6.00 6.00 0.00 0.00 6450.00 33.12 81.79 6384.67 -34.94 495.57 465.09 6.00 6.00 0.00 0.00 6500.00 36.12 81.79 6425.81 -30.89 523.68 493.19 6.00 6.00 0.00 0.00 6550.00 39.12 81.79 6465.41 -26.53 553.89 523.39 6.00 6.00 0.00 0.00 6600.00 42.12 81.79 6503.36 -21.89 586.10 555.59 6.00 6.00 0.00 0.00 6650.00 45.12 81.79 6539.55 -16.96 620.24 589.72 6.00 6.00 0.00 0.00 6700.00 48.12 81.79 6573.89 -11.78 656.21 625.67 6.00 6.00 0.00 0.00 6750.00 51.12 81.79 6606.28 -6.34 693.90 663.35 6.00 6.00 0.00 0.00 6783.92 53.16 81.79 6627.10 -2.52 720.40 689.85 6.00 6.00 0.00 0.00 Section 9: Start Hold MD Incl Azim TVD +N/-S +FJ-W VS DLS Bund Turn TFO ft deg deg ft ft ft ft d~100ft d~100ft deg/10Oft deg 6800.00 53.16 81.79 6636.74 -0.68 733.14 702.58 0.00 0.00 0.00 0.00 6872.15 53.16 81.79 6680.00 7.56 790.28 759.70 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date:> 112312002 Time: 11:15:29 Page: 4 Field: Prudhoe Bay Cø..ol"dina.fe.{NE) Reference: WeD:' S-112, True North Site: PB S Pad V~I'titaI{tVD)R~erenc:e: S-Pad Wells 70.0 Well: &-112 Sec:tion(VS) Reference: Well (0.00~,0.OOE,73.45Azj) W ellpatb: Plan &-112 Plan: S-112wp06 Section 10: Start DLS 12.48 TFO -19.90 MD Incl Azim TVD +N/-S DLS Build Turn TFO ft deg deg ft ft . deg¡10Oftdeg¡10Qftdeg/100ft deg 6875.00 53.49 81.64 6681.70 7.89 792.55 761.97 12.48 11.74 -5.28 -19.90 6900.00 56.43 80.37 6696.06 11.09 812.76 782.26 12.48 11.77 -5.07 -19.81 6925.00 59.39 79.19 6709.34 14.86 833.60 803.31 12.48 11.81 -4.74 -19.08 6950.00 62.35 78.07 6721.51 19.16 855.01 825.05 12.48 11.86 -4.46 -18.45 6975.00 65.32 77.02 6732.53 24.00 876.92 847.43 12.48 11.89 -4.22 -17.91 7000.00 68.30 76.01 6742.37 29.36 899.26 870.38 12.48 11.92 -4.02 -17.44 7025.00 71.29 75.05 6751.01 35.23 921.97 893.82 12.48 11.94 -3.86 -17.05 7050.00 74.28 74.12 6758.41 41.57 944.99 917.69 12.48 11.96 -3.73 -16.71 7075.00 77.27 73.21 6764.55 48.39 968.24 941.92 12.48 11.97 -3.62 -16.44 7100.00 80.27 72.33 6769.42 55.65 991.66 966.44 12.48 11.99 -3.53 -16.22 7125.00 83.27 71.46 6773.00 63.34 1015.17 991.17 12.48 12.00 -3.47 -16.04 7150.00 86.27 70.60 6775.28 71.43 1038.71 1016.04 12.48 12.00 -3.43 -15.92 7175.00 89.27 69.75 6776.26 79.90 1062.21 1040.97 12.48 12.01 -3.40 -15.84 7197.87 92.01 68.98 6776.00 87.96 1083.61 1063.78 12.48 12.01 -3.40 -15.81 Section 11 : Start DLS 12.00 TFO -47.69 MD Incl Azim TV» +N/-S +FJ-W VS DLS, Build Turn TFO ft deg deg ft ft ft ft degl100ft deg/100ft deg/100ft deg 7200.00 92.18 68.79 6775.92 88.73 1085.60 1065.90 12.00 8.08 -8.88 -47.69 7225.00 94.20 66.56 6774.53 98.21 1108.68 1090.74 12.00 8.07 -8.90 -47.70 7250.00 96.21 64.33 6772.26 108.56 1131.33 1115.39 12.00 8.04 -8.94 -47.82 7267.12 97.58 62.78 6770.20 116.12 1146.55 1132.13 12.00 8.01 -9.00 -48.03 Section 12: Start Hold MD Inel Azim TVD +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/10OO degl100ft degl100ft deg 7300.00 97.58 62.78 6765.86 131.03 1175.53 1164.16 0.00 0.00 0.00 0.00 7400.00 97.58 62.78 6752.67 176.36 1263.68 1261.57 0.00 0.00 0.00 0.00 7426.21 97.58 62.78 6749.21 188.24 1286.78 1287.10 0.00 0.00 0.00 0.00 Section 13: Start DLS 6.00 TFO -179.96 MD Inel Azim TVD +N/-S +FJ-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/10Oft degl100ft deg/10OO deg 7450.00 96.16 62.78 6746.36 199.05 1307.79 1310.31 6.00 -6.00 0.00 -179.96 7500.00 93.16 62.78 6742.30 221.84 1352.10 1359.28 6.00 -6.00 0.00 -179.96 7535.94 91.00 62.78 6741.00 238.26 1384.04 1394.57 6.00 -6.00 0.00 -179.96 Section 14: Start DLS 6.00 TFO 169.07 MD Incl Azim TVD +NI-S +EI-W VS DLS Build Turn TfQ ft deg deg ft ft ft ft degl100ft deg/100ft deg/10OO deg 7550.00 90.17 62.94 6740.86 244.68 1396.55 1408.39 6.00 -5.89 1.14 169.07 7600.00 87.23 63.51 6741.99 267.19 1441.17 1457.58 6.00 -5.89 1.14 169.07 7613.72 86.42 63.67 6742.75 273.29 1453.44 1471.08 6.00 -5.89 1.14 169.06 Section 15: Start Hold MD Incl Azim TVD +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 7700.00 86.42 63.67 6748.14 311.49 1530.61 1555.94 0.00 0.00 0.00 0.00 7800.00 86.42 63.67 6754.39 355.76 1620.06 1654.29 0.00 0.00 0.00 0.00 7900.00 86.42 63.67 6760.64 400.04 1709.51 1752.64 0.00 0.00 0.00 0.00 8000.00 86.42 63.67 6766.89 444.31 1798.95 1850.99 0.00 0.00 0.00 0.00 8029.25 86.42 63.67 6768.71 457.26 1825.11 1879.76 0.00 0.00 0.00 0.00 Section 16: Start DLS 6.00 TFO -4.17 MD Inel Azim TVD +N/-S +FJ-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl100ft deg/100ft deg/10OO deg 8050.00 87.66 63.57 6769.78 466.47 1843.68 1900.18 6.00 5.98 -0.44 -4.17 8055.68 88.00 63.55 6770.00 469.00 1848.77 1905.77 6.00 5.98 -0.44 -4.17 BP Amoco Planning Report - Geographic Com.pany: BP Amoco Field: ÞrodhOeBay Site: PB S Päd , Well: 8-112 WelJpatb: Plan S-112 Section 16: Start DLS 6.00 TFO -4.17 Aiim. TVD Date: 1/2312002 Time: 11 :15:29 CèHrdinate(NE) Reference: Wen: 8-112, True North Vertical (rVU) Reference: 8-Pad Wells 70.0 Section (VS)Reference: Well (0.00N,0.OOE.73.45Azi) Plan: 8-112 wp06 Page: s +N/-S +F1-W VS DLS Build Turn TFO Section 17 : Start DLS 6.00 TFO -3.82 8089.09 90.00 63.42 6770.58 483.91 1878.65 1938.67 6.00 5.99 -0.40 -3.82 Section 18: Start Hold MD Incl Azim TVD +N/-S +F1-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl1000 degl1000 deg/1000 deg 8100.00 90.00 63.42 6770.58 488.79 1888.41 1949.41 0.00 0.00 0.00 0.00 8200.00 90.00 63.42 6770.58 533.54 1977.84 2047.88 0.00 0.00 0.00 0.00 8217 .32 90.00 63.42 6770.58 541.29 1993.33 2064.94 0.00 0.00 0.00 0.00 Section 19: Start DLS 6.00 TFO -3.62 I MD Incl Azim TVD +N/-S +FJ-W VS DLS Build Turn TFO I ¡ ft deg deg ft ft ft ft degl100ft degl100ft deg/100ft deg I 8250.72 92.00 63.29 6770.00 556.27 2023.18 2097.82 6.00 5.99 -0.38 -3.62 Section 20 : Start DLS 6.00 TFO -0.07 MD Incl Azim TVD +N/-S +FJ-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degl100ft deg/1ooft deg/1000 deg 8300.00 94.96 63.29 6767.01 578.38 2067.11 2146.22 6.00 6.00 -0.01 -0.07 8321.24 96.23 63.29 6764.94 587.88 2085.99 2167.03 6.00 6.00 -0.01 -0.07 Section 21 : Start Hold MD Incl 'Azim TVD +N/-S +E/-W VS' DLS Build Turn TFO ft deg deg ft ft ft ft degl1000 degl1 OOft deg/1 000 deg 8400.00 96.23 63.29 6756.39 623.08 2155.93 2244.10 0.00 0.00 0.00 0.00 8495.75 96.23 63.29 6746.00 665.87 2240.95 2337.78 0.00 0.00 0.00 0.00 Survey I Map Map <--' Latitude ---> <- Longitude --> I I MD Incl Azim TVD +N/-S +FJ-W Northing Easting Deg Min Sec Deg Min See: ft deg deg ft ft ft ft ft 70.00 0.00 0.00 70.00 0.00 0.00 5980535.00 618930.00 70 21 19.703 N 149 2 2.965 W 100.00 0.00 0.00 100.00 0.00 0.00 5980535.00 618930.00 70 21 19.703 N 149 2 2.965 W 200.00 0.00 0.00 200.00 0.00 0.00 5980535.00 618930.00 70 21 19.703 N 149 2 2.965 W 300.00 0.00 0.00 300.00 0.00 0.00 5980535.00 618930.00 70 21 19.703 N 149 2 2.965 W 400.00 1.50 90.00 399.99 0.00 1.31 5980535.02 618931.31 70 21 19.703 N 149 2 2.927 W 500.00 3.00 90.00 499.91 0.00 5.23 5980535.08 618935.23 70 21 19.703 N 149 2 2.812 W 566.67 4.00 90.00 566.45 0.00 9.30 5980535.15 618939.30 70 21 19.703 N 149 2 2.693 W 600.00 4.64 92.52 599.69 -0.06 11.81 5980535.13 618941.81 70 21 19.702 N 149 2 2.620 W 700.00 6.59 97.11 699.20 -0.95 21.55 5980534.40 618951.56 70 21 19.694 N 149 2 2.335 W 800.00 8.56 99.60 798.33 -2.90 34.59 5980532.65 618964.62 70 21 19.674 N 149 2 1.954 W 822.06 9.00 100.00 820.13 -3.47 37.90 5980532.13 618967.95 70 21 19.669 N 149 2 1.857 W 900.00 10.56 100.00 896.93 -5.77 50.94 5980530.04 618981.02 70 21 19.646 N 149 2 1.476 W 1000.00 12.56 100.00 994.90 -9.25 70.67 5980526.87 619000.81 70 21 19.612 N 149 2 0.899 W 1034.56 13.25 100.00 1028.59 -10.59 78.27 5980525.66 619008.43 70 21 19.599 N 149 2 0.677 W 1100.00 13.25 100.00 1092.29 -13.19 93.04 5980523.29 619023.23 70 21 19.573 N 149 2 0.245 W 1200.00 13.25 100.00 1189.62 -17.17 115.62 5980519.66 619045.87 70 21 19.534 N 149 1 59.585 W 1300.00 13.25 100.00 1286.96 -21.15 138.19 5980516.04 619068.50 70 21 19.495 N 149 1 58.926 W 1400.00 13.25 100.00 1384.30 -25.13 160.76 5980512.42 619091.13 70 21 19.456 N 149 1 58.266 W 1500.00 13.25 100.00 1481.64 -29.11 183.33 5980508.80 619113.76 70 21 19.417 N 149 1 57.606 W 1600.00 13.25 100.00 1578.97 -33.09 205.90 5980505.18 619136.39 70 21 19.377 N 149 1 56.946 W ( BP Amoco Planning Report - Geographic Company: BP Amoco Date:, 112312002 TUne: 11:15:29 Page: 6 Field: Prudhoe Bay CfH)rdiü~($)Referènœ: Well: S.112, True North Site: PB S Pad Vertkal(fVÌ)RefereJ1~e: 5-PadWells70.0 WeD: 5-112. Section, (VS)¡{eference: Well (0.OQN,0.OOE,73.45Azi) Wellpath: Plan 5-112 Plan: 5-112 wp06 Survey Map Map ~Latitude -> <- Longitude..-f>' MD Inel AzÎm TVD +N/-S +F1-W .. !li91'thÎDg ~ting 'þegMillSec Deg Min.. ,See ' ft deg deg ft ft ft ft .,' ft 1700.00 13.25 100.00 1676.31 -37.07 228.48 5980501.56 619159.02 70 21 19.338 N 149 1 56.286 W 1800.00 13.25 100.00 1773.65 -41.05 251.05 5980497.94 619181.65 70 21 19.299 N 149 1 55.626 W 1900.00 13.25 100.00 1870.99 -45.03 273.62 5980494.32 619204.28 70 21 19.260 N 149 1 54.967 W 1981.17 13.25 100.00 1950.00 -48.26 291.94 5980491.38 619222.65 70 21 19.228 N 149 1 54.431 W 2000.00 12.69 100.00 1968.35 -49.00 296.10 5980490.71 619226.82 70 21 19.221 N 149 1 54.309 W 2100.00 9.69 100.00 2066.44 -52.37 315.20 5980487.65 619245.97 70 21 19.188 N 149 1 53.751 W 2200.00 6.69 100.00 2165.41 -54.84 329.22 5980485.40 619260.02 70 21 19.164 N 149 1 53.341 W 2300.00 3.69 100.00 2264.99 -56.41 338.12 5980483.97 619268.95 70 21 19.148 N 149 1 53.081 W 2400.00 0.69 100.00 2364.90 -57.07 341.88 5980483.37 619272.71 70 21 19.142 N 149 1 52.971 W 2422.84 0.00 0.00 2387.74 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 2500.00 0.00 0.00 2464.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 2600.00 0.00 0.00 2564.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 2700.00 0.00 0.00 2664.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 2800.00 0.00 0.00 2764.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 2900.00 0.00 0.00 2864.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3000.00 0.00 0.00 2964.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3100.00 0.00 0.00 3064.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3200.00 0.00 0.00 3164.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3300.00 0.00 0.00 3264.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3400.00 0.00 0.00 3364.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3500.00 0.00 0.00 3464.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3600.00 0.00 0.00 3564.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3700.00 0.00 0.00 3664.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3800.00 0.00 0.00 3764.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 3900.00 0.00 0.00 3864.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4000.00 0.00 0.00 3964.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4100.00 0.00 0.00 4064.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4200.00 0.00 0.00 4164.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4300.00 0.00 0.00 4264.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4400.00 0.00 0.00 4364.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4500.00 0.00 0.00 4464.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4600.00 0.00 0.00 4564.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4700.00 0.00 0.00 4664.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4800.00 0.00 0.00 4764.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 4900.00 0.00 0.00 4864.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5000.00 0.00 0.00 4964.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5100.00 0.00 0.00 5064.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5200.00 0.00 0.00 5164.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5300.00 0.00 0.00 5264.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5400.00 0.00 0.00 5364.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5500.00 0.00 0.00 5464.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5600.00 0.00 0.00 5564.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5700.00 0.00 0.00 5664.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5800.00 0.00 0.00 5764.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5898.00 0.00 0.00 5862.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5900.00 0.12 81.79 5864.90 -57.09 342.01 5980483.35 619272.85 70 21 19.141 N 149 1 52.967 W 5950.00 3.12 81.79 5914.88 -56.89 343.41 5980483.57 619274.24 70 21 19.143 N 149 1 52.927 W 6000.00 6.12 81.79 5964.71 -56.32 347.40 5980484.21 619278.22 70 21 19.149 N 149 1 52.810 W 6050.00 9.12 81.79 6014.26 -55.37 353.96 5980485.26 619284.76 70 21 19.158 N 149 1 52.618 W 6100.00 12.12 81.79 6063.40 -54.05 363.08 5980486.72 619293.86 70 21 19.171 N 149 1 52.352 W 6150.00 15.12 81.79 6111.99 -52.37 374.73 5980488.59 619305.48 70 21 19.188 N 149 1 52.011 W 6200.00 18.12 81.79 6159.89 -50.33 388.88 5980490.85 619319.60 70 21 19.208 N 149 1 51.597 W - .. ) BP Amoco Planning Report - Geographic Company: BP Amoco Date: 1/2312002 Time: 11:15:29 Page: 7 Field: ' Prudhoe Bay' . CfH)rdiua~(NE) Reference: Weft: 8-112, True North Site: PB S Pad' Vertita) (tVD) Reference: S-Pad Wells 70.0 Well: S-112. Section (VS) Reference: Well (0.00N,0.OOE,73.45Azi) W~lp~th: PlanS-112 Plan: 8-112wp06 Survey Afap M,.p <-- Latitude -> <- Longitu.de -> +NI..S +FI-W NøJ:tlU~ ' EastÎng ))eg Min See Deg MinSèe ft ft ft ft 6250.00 21.12 81.79 6206.98 -47.94 405.50 5980493.51 619336.18 70 21 19.231 N 149 1 51.112 W 6300.00 24.12 81.79 6253.13 -45.19 424.53 5980496.56 619355.16 70 21 19.258 N 149 1 50.555 W 6350.00 27.12 81.79 6298.21 -42.11 445.93 5980499.98 619376.50 70 21 19.289 N 149 1 49.930 W 6400.00 30.12 81.79 6342.10 -38.69 469.63 5980503.78 619400.14 70 21 19.322 N 149 1 49.237 W 6450.00 33.12 81.79 6384.67 -34.94 495.57 5980507.93 619426.02 70 21 19.359 N 149 1 48.479 W 6500.00 36.12 81.79 6425.81 -30.89 523.68 5980512.43 619454.06 70 21 19.399 N 149 1 47.657 W 6550.00 39.12 81.79 6465.41 -26.53 553.89 5980517.26 619484.19 70 21 19.442 N 149 1 46.774 W 6600.00 42.12 81.79 6503.36 -21.89 586.10 5980522.42 619516.33 70 21 19.487 N 149 1 45.832 W 6650.00 45.12 81.79 6539.55 -16.96 620.24 5980527.89 619550.38 70 21 19.536 N 149 1 44.834 W 6700.00 48.12 81.79 6573.89 -11.78 656.21 5980533.64 619586.25 70 21 19.587 N 149 1 43.783 W 6750.00 51.12 81.79 6606.28 -6.34 693.90 5980539.68 619623.85 70 21 19.640 N 149 1 42.681 W 6783.92 53.16 81.79 6627.10 -2.52 720.40 5980543.92 619650.29 70 21 19.678 N 149 1 41.906 W 6800.00 53.16 81.79 6636.74 -0.68 733.14 5980545.96 619663.00 70 21 19.696 N 149 1 41.534 W 6872.15 53.16 81.79 6680.00 7.56 790.28 5980555.11 619720.00 70 21 19.777 N 149 1 39.863 W 6875.00 53.49 81.64 6681.70 7.89 792.55 5980555.47 619722.26 70 21 19.780 N 149 1 39.797 W 6900.00 56.43 80.37 6696.06 11.09 812.76 5980558.99 619742.42 70 21 19.812 N 149 1 39.206 W 6925.00 59.39 79.19 6709.34 14.86 833.60 5980563.09 619763.19 70 21 19.849 N 149 1 38.597 W 6950.00 62.35 78.07 6721.51 19.16 855.01 5980567.73 619784.53 70 21 19.891 N 149 1 37.971 W 6975.00 65.32 77.02 6732.53 24.00 876.92 5980572.92 619806.35 70 21 19.938 N 149 1 37.331 W 7000.00 68.30 76.01 6742.37 29.36 899.26 5980578.63 619828.60 70 21 19.991 N 149 1 36.678 W 7025.00 71.29 75.05 6751.01 35.23 921.97 5980584.85 619851.22 70 21 20.049 N 149 1 36.014 W 7050.00 74.28 74.12 6758.41 41.57 944.99 5980591.57 619874.13 70 21 20.111 N 149 1 35.341 W 7075.00 77.27 73.21 6764.55 48.39 968.24 5980598.75 619897.27 70 21 20.178 N 149 1 34.661 W 7100.00 80.27 72.33 . 6769.42 55.65 991.66 5980606.38 619920.57 70 21 20.250 N 149 1 33.977 W 7125.00 83.27 71.46 6773.00 63.34 1015.17 5980614.44 619943.95 70 21 20.325 N 149 1 33.289 W 7150.00 86.27 70.60 6775.28 71.43 1038.71 5980622.91 619967.36 70 21 20.405 N 149 1 32.601 W 7175.00 89.27 69.75 6776.26 79.90 1062.21 5980631.75 619990.72 70 21 20.488 N 149 1 31.914 W 7197.87 92.01 68.98 6776.00 87.96 1083.61 5980640.15 620011.99 70 21 20.567 N 149 1 31.289 W 7200.00 92.18 68.79 6775.92 88.73 1085.60 5980640.94 620013.96 70 21 20.575 N 149 1 31.231 W 7225.00 94.20 66.56 6774.53 98.21 1108.68 5980650.79 620036.89 70 21 20.668 N 149 1 30.556 W 7250.00 96.21 64.33 6772.26 108.56 1131.33 5980661.49 620059.37 70 21 20.770 N 149 1 29.894 W 7267.12 97.58 62.78 6770.20 116.12 1146.55 5980669.30 620074.46 70 21 20.844 N 149 1 29.449 W 7300.00 97.58 62.78 6765.86 131.03 1175.53 5980684.66 620103.20 70 21 20.991 N 149 1 28.601 W 7400.00 97.58 62.78 6752.67 176.36 1263.68 5980731.39 620190.62 70 21 21.436 N 149 1 26.024 W 7426.21 97.58 62.78 6749.21 188.24 1286.78 5980743.63 620213.52 70 21 21.553 N 149 1 25.349 W 7450.00 96.16 62.78 6746.36 199.05 1307.79 5980754.76 620234.35 70 21 21.659 N 149 1 24.735 W 7500.00 93.16 62.78 6742.30 221.84 1352.10 5980778.25 620278.29 70 21 21.883 N 149 1 23.439 W 7535.94 91.00 62.78 6741.00 238.26 1384.04 5980795.19 620309.97 70 21 22.045 N 149 1 22.506 W 7550.00 90.17 62.94 6740.86 244.68 1396.55 5980801.80 620322.37 70 21 22.108 N 149 1 22.140 W 7600.00 87.23 63.51 6741.99 267.19 1441.17 5980825.02 620366.63 70 21 22.329 N 149 1 20.835 W 7613.72 86.42 63.67 6742.75 273.29 1453.44 5980831.30 620378.80 70 21 22.389 N 149 1 20.477 W 7700.00 86.42 63.67 6748.14 311.49 1530.61 5980870.72 620455.35 70 21 22.765 N 149 1 18.220 W 7800.00 86.42 63.67 6754.39 355.76 1620.06 5980916.40 620544.07 70 21 23.200 N 149 1 15.605 W 7900.00 86.42 63.67 6760.64 400.04 1709.51 5980962.09 620632.80 70 21 23.635 N 149 1 12.990 W 8000.00 86.42 63.67 6766.89 444.31 1798.95 5981007.78 620721.52 70 21 24.071 N 149 1 10.375 W 8029.25 86.42 63.67 6768.71 457.26 1825.11 5981021.14 620747.47 70 21 24.198 N 149 1 9.610 W 8050.00 87.66 63.57 6769.78 466.47 1843.68 5981030.64 620765.89 70 21 24.288 N 149 1 9.067 W 8055.68 88.00 63.55 6770.00 469.00 1848.77 5981033.25 620770.93 70 21 24.313 N 149 1 8.919 W 8089.09 90.00 63.42 6770.58 483.91 1878.65 5981048.63 620800.58 70 21 24.460 N 149 1 8.045 W 8100.00 90.00 63.42 6770.58 488.79 1888.41 5981053.67 620810.25 70 21 24.508 N 149 1 7.759 W 8200.00 90.00 63.42 6770.58 533.54 1977.84 5981099.83 620898.95 70 21 24.948 N 149 1 5.145 W 8217.32 90.00 63.42 6770.58 541.29 1993.33 5981107.82 620914.32 70 21 25.024 N 149 1 4.692 W 8250.72 92.00 63.29 6770.00 556.27 2023.18 5981123.27 620943.92 70 21 25.171 N 149 1 3.819 W ,. Company: BP Amooo Field: Prudhoe Bay Site: PB S Pad Well: &.112 WeUpath: Plan 5-112 Survey MD Ind ADm ft deg ,(jag 8300.00 94.96 63.29 8321.24 96.23 63.29 8400.00 96.23 63.29 8495.75 96.23 63.29 6767.01 6764.94 6756.39 6746.00 BP Amoco Planning Report - Geographic Date: 1123/2002 Time: 11:15:29 Co-ordinate(NE) Reference: Well:, &.112, True North Vertical (fVD) Referente: &.Pad Wells 70.0 Section (VS) Reference: WeD (0:00N,O.ooE.73.45Azi) Plan: &.112 wp06 Page: 8 TVD +NI~S ft Map Nõrthiatg ft ' Map Easting ft <-Latitude -> <.i.LøDgitu@---> ~ MinSec Deg'MiDS« " +Fl-W ft 578.38 2067.11 5981146.07 620987.49 70 21 25.388 N 149 1 2.535 W 587.88 2085.99 5981155.87 621006.22 70 21 25.482 N 149 1 1.983 W 623.08 2155.93 5981192.17 621075.58 70 21 25.828 N 149 0 59.938 W 665.87 2240.95 5981236.30 621159.91 70 21 26.248 N 149 0 57.452 W H 206928 DATE INVOICE I CREDIT MEMO OS/23..02 CK052302K THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 ~. PAY DESCRIPTION Permit To Drill Fee GROSS PIs call Terrie Hubble X4628 TOTAL ~ B f) tf~.. ..,... . ". .. £J..f.. TO THE ORDER OF Alaska Oil & Gas Conservation Commission 333 W 7th Ave, ste 100 Anchorage, AK 99501 S~\\'~ DATE CHECK NO. OS/28/02 H206928 VENDOR DISCOUNT NET $100.00 H RECEIVED JU\l ? 7 í)01'\2 I. Î.-' L j, Alaska Oil & Gas Carm. CommisSlm; Anchorage $100..00 No. H 208928 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 "..~; .f".. ,oy::-q UJU" CONSOLIDATED COMMERCIAL ACCOUNT DATE ****May 28, 2002** II. 2 0 b g 2 8 II. I: 0 t. . 2 0 3 8 g 5 I: 008 t. L. . g II. AMOUNT *****$100..00****** NOT VALID AFTER 120 DAYS CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORA TION INJECTI~ELL INJECTION WELL REDRILL Rev: 5/6/02 C\j ody\temp lates TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME$Ú IS"-/J7_J~ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well ----' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-) SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY b)! WELL NAME fJ1f~-I ~ ,,/12/ PROGRAM: Exp - Dev --- Redrll- Se~ k Well bore seg - Ann. disposal para req - . . FIELD & POOL CYOI ¿C? INIT CLASS .-" . - 1~w.I.v¡¡; GEOL AREA '? 7' n UNIT# 1)65<:\ ON/OFF SHORE oN ADMI NISTRA TION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . r y'\ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. " . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N APPR - D~ 1)= 12. Permit can be issued without administrative approval.. . . . . Y N ;f/'Þ- 7//1 ú Z- 13. Can permit be approved before 15-day wait.. . . . . . . . . . 0 N J ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 0 N -; cJ iI >t 't-V it rP II r.¡ 15. Surface casing protects all known USDWs. . . . . . . . . . . @N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . lfí2 N- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y 6J 18. CMT will cover all known productive horizons. . . . . . . . . . 11 19. Casing designs adequate for C: T,B& permafrost. . . . . . . N Ì\ ../ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N /,) O--v] M-, I'-t-. 21. If are-drill,' has a 10-403 for abandonment been approved. . . .- Ai I A 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . j N 23. If diverter required, does it meet regulations. . . . . . . . . . . N 24, Drilling fluid program schematic & equip list adequate. . . . . '" N 25. BOPEs, do they meet regulation. . . . ~ . . . . . . . . . . . IN:; .' ~ /- t 26. BOPE press rating appropriate; test to $$~OO psig. . N ¡USr 'lvr,! fSt . !h¡¿l CS'j {ß~ .~~OO jI'{A A., 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 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. . . . . @N 31. Data presented on potential overpressure zones. . . . . .. )YN A / ,/) 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / {./ (/7 u ~R D~ TF 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ~ ¿ 7/J /t:$;? 34. Contact name/phone for weekly progress reports [exploratory on'- Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. " Y to surface; (C) will not impair mechanical integrity of the well used for disposal' (D) will not damage producing formation or impair recovery from pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: C MMISSION: RP~é JDH ~ # WGA VJG/t- AæA- ~~I~~ APPR DATE /þ 7j¡:s7 Commentsllnstructions: COT , DTS Q "7f1 ?-/ (1 <- G:\geology\permits \checklist.doc (' 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. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 11 10:16:16 2003 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/02/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS ( Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................03/02/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Aurora MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22107 C.A. DEMOSKI A. MADSEN # SURFACE LOC1\TION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.750 6.125 # REMARKS: S-112i 500292309900 BP Exploration Sperry Sun 10-FEB-03 MWD RUN 2 AK-MW-22107 C.A. DEMOSKI L. VAUGHN / 35 12N 12E 4332 4501 .00 69.60 35.80 CASING SIZE (IN) 20.000 9.625 7.000 (Alaska) Inc. MWD RUN 3 AK-MW-22107 T. MCGUIRE L. VAUGHN DRILLERS DEPTH (FT) 110.0 2915.0 6825.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL WITH NATURAL GAMMA PROBE ó?bd-J 35 115/7 ( ( (NGP) UTILIZING SCINTILLATION DETECTORS. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), h~D ELECTROMAGNETIC WAVE RESISTIVITY PHÞ.SE-4 (EWR-4) . 5. MWD RUN 3 WAS DIRECTIONAL WITH DGR, EWR-4, AND AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 6. DEPTH SHIFTING WAS WAIVED, PER THE 9/4/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-3 REPRESENT WELL S-112 WITH API # 50-029-23099-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8642' MD 1 6742.6' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY - SCINTILLATION DETECTORS SGRC = SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS= SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) PARAMETERS USED IN NEUTRON 1 POROSITY LOG CALCULATIONS: HOLE SIZE: 6.125" MUD WEIGHT: 9.3 - 9.8 PPG MUD FILTRATE SALINITY: 450 - 39000 PPM CHLORIDE FORMATION WATER SALINITY: 22000 PPM CHLORIDE FLUID DENSITY: 1.0 G/ec ~~TRIX DENSITY: 2.65 Glee LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.OO1 Service Sub Level Name... Version Number......... ..1. 0.0 Date of Generation.......03/02/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM 1 clipped curves; all bit runs merged. .5000 START DEPTH 515.5 515.5 2880.5 2880.5 2880.5 STOP DEPTH 8587.5 8641.5 8594.5 8594.5 8594.5 (' RPD FET NPHI FCNT PEF RHOB NCNT DRHO ROBB ROBL ROBR ROBU $ 2880.5 2880.5 6745.5 6800.5 6800.5 6800.5 6800.5 6800.5 6835.0 6835.0 6835.0 6835.0 8594.5 8594.5 8549.0 8549.0 8560.0 8560.0 8549.0 8560.0 8560.0 8560.0 8560.0 8560.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA PBU TOOL MWD MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 1 515.5 2 2925.5 3 6834.5 MERGE BASE 2925.0 6834.0 8641. 5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record............, . Undefined Absent value.............. ... . . . . . -999 Depth Units....... . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS JVíWD OHJV1M 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 RHOB MWD G/CC 4 1 68 32 9 DRHO MWD G/CC 4 1 68 36 10 PEF MWD B/E 4 1 68 40 11 NPHI MWD PU 4 1 68 44 12 NCNT MWD CP30 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 ROBB MWD G/CC 4 1 68 56 15 ROBL MWD G/eC 4 1 68 60 16 ROBR MWD Glee 4 1 68 64 17 ROBU MWD Glee 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 515.5 8641. 5 4578.5 16253 515.5 8641.5 ROP MWD FPH 0 1072.52 205.86 16253 515.5 8641.5 GR MWD API 10.54 342.83 81. 8483 16145 515.5 8587.5 RPX MWD OHMM 0.17 2000 9.85805 11429 2880.5 8594.5 RPS MWD OHMM 0.2 2000 10.2935 11429 2880.5 8594.5 RPM MWD OHMM 0.16 2000 19.8148 11429 2880.5 8594.5 RPD MWD OHMM 0.07 2000 33.2682 11429 2880.5 8594.5 FET MWD HR 0.07 67. 97 L 56053 11429 2880.5 8594.5 RHOB MWD G/CC 0.4798 3.1692 2.3888 3520 6800.5 8560 DRHO MWD G/CC -2.751 1. 028 0.0674659 3520 PEF MWD B/E 1.16 13.08 2.96547 3520 NPHI MWD PU 22.2 67.41 30.4661 3608 NCNT MWD CP30 13191. 9 29897.2 23442.1 3498 FCNT IvlWD CP30 108 610.1 392.074 3498 ROBB MWD G/CC 0.57 3.19 2.39056 3315 ROBL MWD Glee 1. 66 3.07 2.38402 3366 ROBR MWD G/ce 1. 38 3.14 2.39881 3349 ROBU MWD G/ec 0.28 3.37 2.40234 3361 First Reading For Entire File..........515.5 Last Reading For Entire File...........8641.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/02/11 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO2 Physical EOF File Header Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/02/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 515.5 515.5 STOP DEPTH 2859.5 2925.0 # 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: 24-JUL-02 Insite 6.02 Hemory 2925.0 582.0 2925.0 1.1 14 .2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ TOOL NUMBER TLG013 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 .0 # BOREHOLE CONDITIONS 6800.5 6800.5 6745.5 6800.5 6800.5 6835 6835 6835 6835 8560 8560 8549 8549 8549 8560 8560 8560 8560 ( MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHM}1) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Spud Mud 9.60 300.0 9.5 350 13.2 .000 .000 .000 .000 .0 91.1 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacìng............_........60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 515.5 2925 1720.25 4820 515.5 2925 ROP MWD010 FT/H 0 779.77 170.601 4820 515.5 2925 GR MWDOIO API 24.36 125.39 66.0964 4689 515.5 2859.5 First Reading For Entire File..........515.5 Last Reading For Entire File...........2925 File Trailer Service name.............STSLTB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/02/11 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number........... 1. 0.0 Date of Generation.......03/02/11 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 ( Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPM RPS ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2860.0 2880.5 2880.5 2880.5 2880.5 2880.5 2925.5 STOP DEPTH 6796.5 6789.0 6789.0 6789.0 6789.0 6789.0 6834.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINH1ill1 ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined 28-JUL-02 Insite 6.02 Memory 6834.0 2925.0 6834.0 .3 47.6 TOOL NUMBER 155789 136749 8.750 2915.0 LSND 9.70 47.0 10.0 450 4.6 2.800 1. 680 2.300 2.800 78.0 134.6 78.0 78.0 Absent value......................-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service DEPT ROP GR RPX RPS RPM RPD E'ET Order Size Nsam 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 MWD020 Units FT FT/H .i\PI OHMM OHMM OHMM OHMM HR Rep Code 68 68 68 68 68 68 68 68 Offset 0 4 8 12 16 20 24 28 Channel 1 ~, 3 4 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2860 6834 4847 7949 2860 6834 ROP MWD020 FT/H 0 1072.52 279.908 7818 2925.5 6834 GR MWD020 API 10.54 228.83 85.0177 7874 2860 6796. 5 RPX MWD020 OHMM 0.68 2000 8.27977 7818 2880.5 6789 RPS MWD020 OHMM 0.34 2000 8.76979 7818 2880.5 6789 RPM MWD020 OHMM 0.16 2000 12.2855 7818 2880.5 6789 RPD MWD020 OHMM 0.07 2000 27.7264 7818 2880.5 6789 FET MWD020 HR 0.0656 67.9687 1. 21209 7818 2880.5 6789 First Reading For Entire File..........2860 Last Reading For Entire File...........6834 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/02/11 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/02/11 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OO3 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FET RPX RPS RPM RPD GR FCNT NCNT DRHO RHOB 4 header data for each bit run in separate files. 3 .5000 START DEPTH 6745.5 6789.5 6789.5 6789.5 6789.5 6789.5 6797.0 6800.5 6800.5 6800.5 6800.5 STOP DEPTH 8549.0 8594.5 8594.5 8594.5 8594.5 8594.5 8587.5 8549.0 8549.0 8560.0 8560.0 PEF ROP ROBU ROBB ROBL ROBR $ 6800.5 6834.5 6835.0 6835.0 6835.0 6835.0 8560.0 8641. 5 8560.0 8560.0 8560.0 8560.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN ASLD EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP 'THERMAL NEUTRON Azimuthal Litho-Den Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT ME,ASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 01-AUG-02 Insite 6.02 Memory 8642.0 6834.0 8642.0 52.6 95.9 TOOL NUMBER 65041 113413 173051 148574 6.125 6825.0 Water 9.80 49.0 8.8 39000 8.0 Based .070 .039 .080 .400 72.0 134.6 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 FET MWD030 HR 4 1 68 28 8 RHOB MWD030 G/CC 4 1 68 32 9 DRHO MWD030 G/CC 4 1 68 36 10 PEF MWD030 B/E 4 1 68 40 11 NPHI MWD030 PU 4 1 68 44 12 NCNT MWD030 CP30 4 1 68 48 13 FCNT MWD030 CP30 4 1 68 52 14 ROBB MWD030 G/CC 4 1 68 56 15 ROBL MWD030 G/CC 4 1 68 60 16 ROBR MWD030 G/CC 4 1 68 64 lí ROBU MWD030 G/CC 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6745.5 8641.5 7693.5 3793 6745.5 8641.5 ROP MWD030 FT/H 0 369.7 92.7313 3615 6834.5 8641.5 GR MWD030 API 54.33 342.83 95.5011 3582 6797 8587.5 RPX MWD030 OHMM 0.17 1541.42 13.2751 3611 6789.5 8594.5 RPS MWD030 OHMM 0.2 598.61 13.5926 3611 6789.5 8594.5 RPM MWD030 OHMM 0.6 2000 36.1162 3611 6789.5 8594.5 RPD MWD030 OHMM 1. 72 2000 45.2663 3611 6789.5 8594.5 FET MWD030 HR 0.32 50.12 2.31489 3611 6789.5 8594.5 RHOB MWD030 G/CC 0.48 3.1692 2.3888 3520 6800.5 8560 DRHO MWD030 G/CC -2.751 1. 028 0.0674659 3520 6800.5 8560 PEF MWD030 B/E 1.16 13.08 2.96547 3520 6800.5 8560 NPHI MWD030 PU 22.2 67.41 30.4661 3608 6745.5 8549 NCNT MWD030 CP30 13191. 9 29897.2 23442.1 3498 6800.5 8549 FCNT MWD030 CP30 108 610.1 392.074 3498 6800.5 8549 ROBB MWD030 G/CC 0.57 3.19 2.39056 3315 6835 8560 ROBL M'WD030 G/CC 1. 66 3.07 2.38402 3366 6835 8560 ROBRMWD030 G/CC 1. 38 3.14 2.39881 3349 6835 8560 ROBU M'WD030 GICC 0.28 3.37 2.40234 3361 6835 8560 First Reading For Entire Fi1e..........6745.5 Last Reading For Entire File...........8641.5 File Trailer Service name............ .STSLIB.OO4 Service SubLevel Name... Version Number...........l.0.0 Date of Generation.......03/02/11 Maximum Physical Record..65535 Fi I e Type................ LO Next File Name...........STSLIB.OO5 Physical EOr Tape Trailer Service name.............LISTPE Date.....................03/02/11 Origin...................STS Tape Name................ UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/02/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOv~ Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File